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209-146
New Plugback Esets 6/26/2024 Well Name API Number PTD Number ESet Number Date 2L-320 PB1 50-103-20627-70-00 210-166 T39025 3-8-2011 2L-320 PB2 50-103-20627-71-00 210-166 T39026 3-8-2011 CD4-23 PB1 50-103-20621-70-00 210-067 T39027 8-30-2010 CD4-23 PB2 50-103-20621-71-00 210-067 T39028 8-30-2010 ODSK-13 PB1 50-703-20607-70-00 209-146 T39029 11-18-2011 ODSK-13 PB2 50-703-20607-71-00 209-146 T39030 11-18-2011 ODSK-14 PB1 50-703-20610-70-00 209-155 T39031 3-24-2010 ODSK-14 PB2 50-703-20610-71-00 209-155 T39032 3-24-2010 OP05-06 PB1 50-029-23427-70-00 210-080 T39033 10-28-2010 OP05-06 PB2 50-029-23427-71-00 210-080 T39034 10-28-2010 P2-22A PB1 50-029-22850-71-00 209-161 T39035 6-4-2010 P2-22A PB2 50-029-22850-72-00 209-161 T39036 6-4-2010 S-129 PB1 50-029-23433-70-00 210-132 T39037 5-12-2011 S-129 PB2 50-029-23433-71-00 210-132 T39038 5-12-2011 W-219 PB1 50-029-23429-70-00 210-105 T39039 1-27-2011 W-219 PB2 50-029-23429-71-00 210-105 T39040 1-27-2011 W-220 PB1 50-029-23432-70-00 210-126 T39041 3-27-2013 W-220 PB2 50-029-23432-71-00 210-126 T39042 3-27-2013 ODSK-13 PB1 50-703-20607-70-00 209-146 T39029 11-18-2011 ODSK-13 PB2 50-703-20607-71-00 209-146 T39030 11-18-2011 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, December 05, 2013 8:36 AM To: 'Hart, David'; Kralick,Jack Cc: Jasser, Rami; Ross, Gary; Renfro, Erin;OoogurukProdSuper, Bond,Andy;Tirpack, Robert Subject: RE K-13 temporary injection test(PTD 209-146) David, Thanks for the documentation for the temporary piping to initiate an injection test on the well ODSK-13. You have approval to proceed with the proposed short term test under sundry 313-588 and ultimate final conversion to an injector pending the results. Guy Schwartz Senior Petroleum Engineer WED AOGCC 907-301-4533 cell 907-793-1226 office From: Hart, David [mailto David_Hart pxd.com] Sent: Wednesday, December 04, 2013 4:02 PM To: Schwartz, Guy L(DOA); Kralick, Jack Cc: Jasser, Rami; Ross, Gary; Renfro, Erin; OoogurukProdSuper; Bond, Andy; Tirpack, Robert; Hart, David Subject: RE: K-13 temporary injection test Guy, Thank you for your prompt response to our K13 injection test request. Please find attached the following MOCPHA documentation: 1. MOC-13-OGK-041 Temporary MOC to hook up K13 to injection 2. Marked up P&ID's showing the temporary change 3. PHA for K13 injection test 4. Photo of K13 wellhead with temporary piping hookup 5. Injection test operational procedures 6. Step rate test, rates and durations 7. DCS screen for temporary control system 8. Safety matrix changes for temporary injection 9. K13 Pre Startup Safety Review, Temporary Injection MOC We plan to commence our temporary injection step rate test as soon as this evening. Please let me know if you have any questions or concerns. David Hart Operations Manager Pioneer Natural Resources 244-1722 cell 1 From: Hart, David Sent: Wednesday, November 27, 2013 10:55 AM To: Schwartz, Guy L(DOA); Kralick, Jack Cc: Jasser, Rami; Hart, David; Ross, Gary; Renfro, Erin; OoogurukProdSuper; Bond,Andy; Tirpack, Robert Subject: RE: K-13 temporary injection test Thanks Guy. We just performed the PHA today. We have some outstanding action items, and are awaiting arrival of the wellhead check valve in the next 1-2 weeks. We will close out all action items and send you final PHA, MOC and P&ID's for review prior to kicking off injection. This is a temporary install, nominally a 2-4 week test. I will be in touch soon. Thank you for your cooperation.Dave From: Schwartz, Guy L(DOA) [mailto:guy.schwartz .a_laska.gov] Sent: Wednesday, November 27, 2013 9:43 AM To: Kralick,Jack Cc: Hart, David; Jasser, Rami Subject: RE: K-13 temporary injection test Jack, The temporary injection (step rate test ) was approved in the sundry for K-13 conversion to an Injector. Please forward the completed PHA/ MOC document to me once completed and I will file it with the approved sundry. It is expected that this piping arrangement is temporary only. You have approval to proceed as proposed below... if successful the well will need to have a witnessed MIT after it is stabilized and has permanent piping in place. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Kralick, Jack [mailto:Jack.KralickLpxd.com] Sent: Wednesday, November 27, 2013 8:59 AM To: Schwartz, Guy L(DOA) Cc: Hart, David; Jasser, Rami Subject: K-13 temporary injection test Hello Guy, I left a message to call but thought I'd follow with an email question. Operations is planning a two week injection test into the Kuparuk via the K-13 well. They have temporary piping rigged from one injector(K-38)to the K-13 wellhead. Automation is installed to shut the surface safety valve on the K-38 well and the subsurface safety valves on both wells. A check valve will be installed at the K-13 well to prevent back flow in case of a line break. A PHA will be performed today and an MOC written to cover this temporary test. What does the Commission need further from Pioneer in order to perform this test? Thanks, Jack 2 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 3 Hart, David From: Hart, David Sent: Monday, December 02,2013 1:26 PM To: Hart, David Subject: RE: K13 Injection Test Fro z-4l - / Ye Begin forwarded message: p�Sk /3 From: "Morgan, Mike"<Mike.Morganepxd.com> Date:November 27,2013, 11:08:53 AM AKST To: "Tredway,Tom"<Torn.Tredway @pxd.com>, "Kralick,Jack"<Jack.Kralick( xd.corn>, "Jasser, Rami" <Rarni.JasserfL)pxd.co rn> Cc:"Bond,Andy"<Andy.Bond @pxd.com>, "Sanders,Greg"<Greg.Sanders(cDpxd_com>, "Hart, David" <David.Hart 22xd.corn>, "Williams,Theresa"<Theresa.Williams xd.c.:orn> Subject: K13 Injection Test The objective of the K13 injection test is to assess area reservoir potential through a 14 day injection and pressure fall off analysis. It is recommended to start with a diesel spear volume(2X tubing volume?—Tom,Jack, Rami your call)to establish injection and then move to seawater. Initial wellhead injection pressures are expected to be above 2,000 psi so we may need to pressure up the IA prior to starting(Jack and Rami's call). As the near well formation area cools and injection pressures exceed formation parting pressures injectivity should increase and pressures should stabilize. Prior to the coil work in October the ROC gauge BHP(6,158'ND)showed a static pressure of 3,459 psi with an associated WHP of 618 psi. Subsequent efforts to initiate flow from the well reduced the BHP to as low as 593 psi;currently the BHP is at 2330 psi and building at approximately 25 psi per day. Recommended iniection step rates and duration*. • 500 bwpd for 2 days • 750 bwpd for 1 day • 1,000 bwpd for 1 day • 1250 bwpd for 1 day • 1,500 bwpd for 1 day • 2,000 bwpd or max 5,000 bwpd rate for cumulative 14 days. • After 14 cumulative injection days shut-in and freeze protect immediately and monitor pressure falloff. *Well performance and operations may necessitate changes to this plan. Let me know your thoughts on this proposal and if you need anything else. Have a nice Thanksgiving. Mike 1 1. Temporary MOC and PHA in place. 2. Shut in K-38i and freeze protect. 3. LOTO master valve on K-38i. 4. Isolate K-38i at W/I DBB and bleed water pressure to zero. 5. Get A Single block Variance for K-38i. 6. Install 2" 1502 connection on K-38i flow cross. 7. Install 2" plug valve on K-38i 1502 flow cross connection. 8. Install 2" hard line "T" 9. Rig up 2' hardline to K-13. 10. LOTO K-13 SSV and 4" DBB at test and production headers. 11. LOTO K-13 Lift Gas, Casing Gas DBB header valves 12. LOTO Methanol Injection 13. LOTO K-13 I.A (lift gas) SSV 14. Pressure test Hard Line 15. Make automation changes (flow meter designation, etc.) 16. FCO SIS for K-38i SSV and K-13 SSSV. 17. FCO Historian for K-13 injection rate. 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Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster ..,,// Chair, Commissioner DATED this 21 day of November, 2013. Encl. STATE OF ALASKA • 001%J ‘VPV ALASKA OIL AND GAS CONSERVATION COMMISSION i n APPLICATION FOR SUNDRY APPROVALS i �� 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well❑ Ahddpskoved Program ❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing❑ 1e Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other Convert to Injector 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Pioneer Natural Resources Alaska,Inc. Exploratory ❑ Development Q • 209-146 ' 3.Address: 700 G Street,Suite 600 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99501 50-703-20607-00-00 , 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ODSK-13. Will planned perforations require a spacing exception? Yes L I QILib No ri 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036/ADL 389958 Oooguruk-Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 14,513'• 6251' ' 14,495' • 6250' I N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 110' 16" 158' 158' N/A N/A Surface 3475' 11-3/4" 3513' 2949' 5830 psi 3180 psi Intermediate 1 5816' 9-5/8" 3282'-9098' 2847'-5423' 5750 psi 3090 psi Tie-Back 2478' 7" 8961' 5350' 7240 psi 5410 psi Intermediate 2 11,389' 7" 8950'-11,428' 5344'-6182' 7240 psi 5410 psi Liner 3228' 4-1/2" 11,283'-14,511' 6173'-6251' 8430 psi 7500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment,pg.2 i See Attachment,pg.2 3-1/2",9.2# L-80,TCII 11,276' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): . TRSV; Retry Pkr; NTH Liner Top Pkr 1995'MD/1919'TVD; 10,516'MD/6047'TVD; 11,299'MD/6175'ND 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program f , BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 12 - 14.Estimated Date for 15.Well Status after proposed work: 11/15/2013 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ Ei 11 GINJ ❑ WAG ] Abandoned ❑ Commission Representative: tl�tKl GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jack Kralick,343-2185 Email jack.kralick(ac Dxd.com Printed Name Jack Kralick` Title Well Work Supervisor Prepared By:Kathy Campoamor,343-2183 Signatur ajert_________ Phone Date 343-2185 11/7/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: S V2›,* 4546 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test [✓� Location Clearance ❑ RBDMS NOV 2 2 Other: k //f f i Mt,./�t- ettx,.' i D7, !h 4r C.ov i) Lit' A/a 33 14_ W r:�Gt e 5541 1 T— �� n 57L4.6.-6-z-440 �is+.1 . ,// G.er r1 C,,,e— /�/' �'!� Zj ' A4e. 25: `{I Z U) Spacing Exception Reqii ? Yes ❑ No 2 Subsequent Form Required: `D—t-fb y APPROVED BY Approved by: f �.e_e_!`r COMMISSIONER THE COMMISSION Date: /(, 2.1 —43 ?M Submit Form and Form 10-403(Revised 10/2012) A Appro p ti v f° l onths from the date of approval. ti II/lib Attachments in Duplicate C C•(Z6,3 � � /-'� /i1,101' 3 • Pioneer•ural Resources Alaska Inc. ODSK-13 Page 2 AOGCC Form 10-403, Application For Sundry Approvals Present Well Condition Summary — Box #11 Perforation Depth (MD/TVD) - Attachment 4-W, 12.6#, L-80 IBT-M Slotted Liner : MD TVD 11,306' - 11,763' 6175' — 6198' 11,963' — 14,495' 6203' — 6250' Perforated Intervals: MD TVD 13,490' — 13,520' 6225' — 6226' ✓ 13,520' — 13,550' 6226' — 6227' 13,650' — 13,680' 6228' —6229' 13,695' — 13,725' 6230' —6231' 14,060' — 14,090' 6240' — 6241' 14,125' — 14,155' 6242' — 6243' 14,270' — 14,300' 6244' — 6245' 14,320' — 14,350' 6246' — 6246' Blank Pipe Interval : MD TVD 11,763' — 11,963' 6198' — 6203' • • ODSK-13 Oooguruk- Kuparuk Downhole Conversion Procedure from Producer to Iniector Prepared: Date: •Il 1 jZ t 11, Jack Kralick Wells Group Approved: /11,11 Date: j /� 12/ 13 Rarpi Jasser Staff Completion Engineer GOALS/OBJECTIVES: The goals of any Pioneer Natural Resources project are the following: 1. No Harm to People 2. No Accidents 3. No Harm to the Environment The objective is the convert ODSK-13 production well to a WAG injection well by changing the gas lift string to dummy's and completing an MITIA and a MITT to ensure mechanical integrity. During the workover the packer setting depth was moved down to place the packer below competent cement in preparation to turn the well into an injector. An injectivity test will be completed prior swapping the well to injection. LAST ACTIVITY TO WELL A workover was completed in September 2013 and a new upper completion was run. Slickline ran a Gas Lift Orifice Valve to attempt to produce the well in gas lift mandrel @ 8866'. Attempts to keep the well flowing were unsuccessful. Well is currently set up for production. PERSONNEL Name Title Phone Jamey Bowman/Chad Gueco Wellwork Supervisor 907-670-6602 Rob Tirpack Drilling Ops Manager 907-903-9454 Vern Johnson Drilling Manager 907-575-9430 Joe Polya/ Drilling Supervisor 907-670-6606 Rodney Klepzig Nick Mumma/ NS Travel/Security 907-670-6700 Greg Smith Control Room Operations 907-670-6642 Well Condition • Well set up for production service • The well has flowed very little oil to the surface • %"Orifice Valve @ 8866' • Xylene treatment with coiled tubing did not change the production rate • Preparation ***REVIEW PREVIOUS WELL WORK REPORTS*** • Complete communications with the operations staff and the Drilling wellsite leader about upcoming work. • Communicate with the logistics staff about transportation and the camp staff about billeting on the island. • Rig up secondary swab valve. • Monitor IA and OA throughout the job • Inform AOGCC inspectors at least 48 hours prior to job of upcoming conversion and request to witness annulus testing • All work to be initiated by a HSE walkthrough by all personnel led by the Wells Supervisor. • A pre job meeting should follow walkthrough with all personnel on the project. • Management of Change: Any deviation in procedure will be in writing from town and initiated by a meeting with all personnel to prior to making the change Basic Procedure • MIRU HES slickline • P/T BOP and Lub to 3000 psi • RIH w/gauge ring drift to bottom • RIH w/XX plug to 9922' • RIH to pull OV @ 8866' • Circulate a casing and tubing volume of filtered SW down IA and up tbg minus the freeze protect volume in the IA to 2000'TVD. Follow with the annulus freeze protect using diesel • Set DV at 8866' • MITIA to 3500 psi—charted and witnessed (or waived) by AOGCC—Monitor tubing pressure • Bleed Annulus to 500 psi • MITT to 3500 psi—charted and witnessed (or waived) by AOGCC—Monitor tubing pressure • RIH to pull XX plug @ 9922' • RDMO HES • • Injectivity test down tubing—rig up from a nearby water injector from flow cross to flow 5.09 9 cross. Injectivity rate to be determined by pressure. Max pressure is 3800 psi on the tubing. Step rate test well in 500 bbl increments after breakdown occurs: 500 BWPD, 1000 BWPD, 1500 BWPD, 2000 BWPD. • Record rates and pressures and call town with results and futher instructions • RDMO pumps and hard lines • Complete handover form and give copy to operations and put one in the well work folder as well as send a copy to Kathy Campoemor. Send schematic to Kathy for update in Wellview. Mir- 1A- PIONEER • Current Schematic - State • Well Name: ODSK-13 NATURAL RESOURCES Sidetrack 2, 11/7/2013 2:17:32 PM Well Attributes Vertical schematic(actual) API/UWI Field Name Well Status Total Depth(ftKB) 50-703-20607-00-00 Oooguruk Unit DRILLED 14,513.0 Casing Strings Conductor,158.0ftKB Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Depth...Grade Top Thread Wt/Len(I... Conductor 16 14.670 47.7 158.0 158.0 H40 Welded 109.00 ti Conductor Casing Components Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 22-3 - 1-1 Conductor Shoe 47.7 47.7 16 14.670 33-1 Surface,3,512.6ftKB Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Depth...Grade Top Thread Wt/Len(I_. 15-11 • ' Surface 11 3/4 10.772 37.7 3,512.6 2,949.2 L-80 HYD521 60.00 Casing Components Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Coin I 2-1 VG Landing Jt. 37.7 37.7 14 5/8 10.772 2-2 VG Hgr-LS=1.24 37.7 37.7 11 3/4 10.772 ® �iljtil 2-3 Pup Joint 38.9 38.9 11 3/4 10.772 n 2-4 Casing Joints 41.9 41.9 11 3/4 10.772 ® 2-5 HES Float Collar 3,427.2 2,911.3 11.95 10.772 5-4 I 2-6 Csg Joint 2-7 11 3/4"Surface Shoe 3,428.9 2,912.0 11 3/4 10.772 3,510.7 2,948.3 11.95 10.772 HES Float Shoe 5-5 1 Intermediate2 Tie-back 10/2/2011,8,962.2ftKB 11 • 13_2 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ft_. Set Depth...Grade Top Thread Wt/Len(I... Intermediate2 Tie- 7 6.276 39.4 8,962.2 7,573.5 L-80 BTC-M 26.00 I 5-6 back 10/2/2011 Casing Components 7- Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 15-71 •-41-11 3-1 Vetco 7"Casing Hanger& 39.4 39.4 7 6.276 pup 3-2 Casing 41.5 41.5 7 6.276 /`_ 3-3 Casing Pup Joint(estimated 82.5 82.5 7 6.276 length) 15-8 2 4 3-4 Casing 104.6 104.6 7 6.276 ," Ji iT 15-91 3-5 Casing 8,901.8 7,540.1 7 6.276 V- _ 3-6 Casing Pup Joint 8,940.6 7,561.6 7 6.276 15-101 I 3-7 XO pup-VAM TOP pin X 8,943.7 7,563.3 7 6.276 q BTC-M box j tl 5-11 I 3-8 WFT"Hold Down"sub w/ 8,945.4 7,564.2 7 6.276 `(.� VAM Top pin 15-12 I 3-9 XO-7"26#IBT pin X VAM 8,949.5 7,566.5 7 6.276 1 TOP box 14-11 3-10 Locator sub 8,951.4 7,567.6 8.29 6.276 4-2 3-11 WFT seals w/ind.muleshoe 8,952.3 7,568.0 7 6.276 total length 20.32 4-3 Intermediate/ Drilling Liner,9,098.0ftKB 14-41 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Depth...Grade Top Thread WVLen(I... Intermediate) 9 5/8 8.835 3,282.0 9,098.0 5,310.5 L-80 Hyd 521 40.00 Drilling Liner Casing Components I 12_51 Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 4-1 WFT"PBR"Tie back sleeve 3,282.0 2,726.1 9 5/8 8.835 12-61 5-13 4-2 WFT 9 5/8 x 11 3/4"TSP4R" 3,303.7 2,737.1 9 5/8 8.835 Liner top pkr 4-3 WET 9 5/8 x 11 3/4"PHS" 3,305.8 2,738.2 9 5/8 8.835 Liner hng 1 2-7 4-4 XO 9 5/8 GBB box X HYD 3,310.8 2,740.6 9 5/8 8.835 5-14 521 pin 4-5 Casing 3,312.3 2,741.4 9 5/8 8.835 15-151 4-6 Ldg Collar 8,976.1 5,245.3 9 5/8 8.835 3-4 4-7 Casing 8,977.0 5,245.8 9 5/8 8.835 15-161- i 4-5 Page 1/3 Report Printed: 11/7/2013 PI O N E E R , Current Schematic - State 0 Well Name: ODSK-13 NATURAL RESOURCES Sidetrack 2, 11/7/2013 2:17:32 PM Casing Components Vertical schematic(actual) Top # Item Des Top(ftKB) (TVD) ) (ftKB) OD(in) ID(in) Corn 15-161 3-4, ,. 4-8 Ldg Collar 9,015.9 5,266.6 9 5/8 8.835 44=5 4-9 Casing 9,017.3 5,267.3 9 5/8 8.835 4-10 Float shoe 9,096.2 5,309.5 9 5/8 8.835 15-171 s Intermediate2 9/6/2011,11,428.0ftKB -- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Depth...Grade Top Thread Wt/Len(I... • 15-181 ■ a Intermediate2 7 6.276 8,949.6 11,428.0 8,406.2 L-80 Hyd 511 26.00 9/6/2011 Casing Components 15-191 1 Top(TVD) , Item# _ Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 5-1 Polish Bore Receptacle 8,949.6 7,566.6 7 6.276 5-2 WFT TSP5 Liner Top Pkr 8,970.5 7,578.1 7 6.276 5-3 Vam Top Collar box X box 8,974.4 7,580.2 7 6.276 • 13-51 5-4 PHR Liner Hanger 8,975.4 7,580.7 7 6.276 5-5 X-O Vam Top box X Hyd 8,981.4 7,584.0 7 6.276 511 pin • 3-6 5-6 7"Casing 8,983.6 7,585.2 7 6.276 5-7 WFTLanding Collar 11,305.7 8,399.3 7 6.276 ' 13-71 5-8 7"Casing 11,306.9 8,399.4 7 6.276 5-9 Float Collar 11,346.1 8,401.7 7 6.276 15-201 1 ■ 13-81 5-10 7"Casing 11,347.7 8,401.8 7 6.276 5-11 Halliburton Shoe 11,426.0 8,406.2 7 6.276 3-9 Production Liner,14,511.0ftKB Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ft_. Set Depth...Grade Top Thread Wt/Len Q_. I Production Liner 4 1/2 3.958 11,283.3 14,511.0 8,478.0 L-80 12.60 13-101 Casing Components Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn .- __111 6-1 Polish Bore Receptacle 11,283.3 8,397.9 4 1/2 3.958 5-1 6-2 NTH Liner Packer 11,298.7 8,398.8 4 1/2 3.958 6-3 Collar 11,301.2 8,399.0 41/2 3.958 6-4 PHR Liner Hanger 11,302.0 8,399.1 4 1/2 3.958 1 1521 6-5 XO 4.5"Hyd 521 p x 5"New 11,307.3 8,399.4 4 1/2 3.958 Vamb 6-6 4.5"12.6#L-80 Hyd 521 pup 11,308.1 8,399.4 4 1/2 3.958 15-31 jt 6-7 XO 4.5"IBT-M p x 4.5"Hyd 11,317.8 8,400.0 4 1/2 3.958 521 b 6-8 Slotted Liner 11,319.0 8,400.1 4 1/2 3.958 l6-9 XO Hydril 521 by IBT-M 11,776.3 8,423.9 4 1/2 3.958 4-6 6-10 Solid Liner 11,778.4 8,424.1 4 1/2 3.958 5 4 6-11 XO IBT-M by Hydril 521 11,974.9 8,426.7 4 1/2 3.958 6-12 Slotted Liner 11,976.5 8,426.7 4 1/2 3.958 6-13 XO IBT-M by Hydril 521 14,507.6 8,477.9 4 1/2 3.958 5-5 11 6-14 Shoe 14,509.7 8,477.9 41/2 3.958 Tubing Strings Tubing Description Stnng M... ID(in) Top(ftKB) Set Depth(f...Set Dept...Wt(lb/ft) Grade Top Thread . Tubing-Production _ 3 1/2 2.992 32.1 11,295.0 8,398.6 9.20 L-80 TC-II Tubing Components 15-211 Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn ' 14-71 5-1 RKB correction for CUDD 32.1 32.1 3 1/2 2.992 5-2 VG Tubing Hanger 51.1 51.1 3 1/2 2.992 5-3 P x P X-O Pup 52.6 52.6 3 1/2 2.992 g 5-4 X-O Pup Joint TC-II box X 56.6 56.6 3 1/2 2.992 ' 4_' IBT-M pin 5-5 X-O Pup Joint IBT-M box X 58.5 58.5 3 1/2 2.992 14-91 TC-II pin 5-6 3.5"Tubing Joint 60.5 60.5 3 1/2 2.992 • 14-10 5-7 Space Out Pup 92.9 92.9 3 1/2 2.992 5-8 3.5"Tubing Joint 116.1 116.1 3 1/2 2.992 15-221 4 t 15-61 5-9 Pup Joint 1,980.7 1,965.0 3 1/2 2.992 I Page 2/3 Report Printed: 11/7/2013 PIONEER • Current Schematic - State 0 Well Name: ODSK-13 NATURAL RESOURCES Sidetrack 2, 11/7/2013 2:17:33 PM Tubing Components Vertical schematic(actual) ftKB Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 15-221 5-10 HES TRSSSV w/2.813""X" 1,995.4 1,979.4 3 1/2 2.992 11 profile 15-23 5-11 Pup Joint 2,000.3 1,984.2 3 1/2 2.992 15-241 1 5-12 3.5"Tubing Joint 2,015.1 1,998.6 3 1/2 2.992 15-251 5-13 Pup Joint 3,494.6 3,408.8 3 1/2 2.992 5-14 HES 3.5"x 1.5"GLM 9.2# 3,509.4 3,422.5 3 1/2 2.992 5-26 s TCII BxP w/dummy 15.271 5-15 Pup Joint 3,518.2 3,430.7 3 1/2 2.992 15-281 5-6 5-16 3.5"Tubing Joint 3,533.0 3,444.3 3 1/2 2.992 5-17 Pup Joint 8,861.7 7,517.7 3 1/2 2.992 5 9 5-18 HES 3.5"x 1.5"GLM 9.2# 8,876.5 7,526.0 3 1/2 2.992 15-301 •� I oSIS TCII BxP w/1/4"OV 5-19 Pup Joint 8,885.4 7,530.9 31/2 2.992 15-311 a 5-20 3.5"Tubing Joint 8,900.2 7,539.2 3 1/2 2.992 ® 1 5-21 X-O Pup Joint TC-II box X 8,994.7 7,591.3 3 1/2 2.992 15-331 I IBT-M pin 5-22 3.5"Tubing Joint 8,996.7 7,592.4 3 1/2 2.992 15341 5-23 X-O Pup Joint IBT-M box X 9,892.2 8,039.1 3 1/2 2.992 as 5-351 TC-II pin 5-24 3.5"Tubing Joint 9,894.3 8,040.1 3 1/2 2.992 5-36 5-25 Pup Joint 9,926.7 8,054.2 3 1/2 2.992 15-371 5-26 HES"X"Nipple w/2.813" 9,941.4 8,060.7 3 1/2 2.992 -_---- bore 5-38 ' 5-27 Pup Joint 9,942.7 8,061.3 3 1/2 2.992 15-391 1 5-28 3.5"Tubing Joint 9,957.4 8,067.7 3 1/2 2.992 15-401 5-29 Pup Joint 10,505.6 8,268.1 3 1/2 2.992 5-30 BHI 3.5"x 7"Premier Feed 10,515.7 8,271.0 3 1/2 2.992 Thru Retrievable pkr 5-41 5-31 Pup Joint 10,523.0 8,273.0 3 1/2 2.992 m. 5-42 - 6-1 5-32 3.5"Tubing Joint 10,533.1 8,275.8 3 1/2 2.992 1 5-33 Pup Joint 10,597.4 8,293.1 3 1/2 2.992 5-34 HES"XN"Nipple with 2.750" 10,612.1 8,296.9 3 1/2 2.992 i 16-21 No-Go 5-35 Pup Joint 10,613.5 8,297.2 3 1/2 2.992 1 6-31 5-36 3.5"Tubing Joint 10,628.3 8,301.0 3 1/2 2.992 6-4 5-37 Pup Joint 11,107.7 8,383.3 3 1/2 2.992 1 15 71 5-38 ROC Gauge Mandrel 11,115.4 8,384.1 3 1/2 2.992 I 11 5-39 Pup Joint 11,120.0 8,384.6 3 1/2 2.992 5-40 3.5"Tubing Joint 11,125.7 8,385.2 3 1/2 2.992 16-51 5-41 Locator Collar w/5" 11,286.4 8,398.1 5 1/2 2.992 LTC8RD Box x 3-1/2 TC-II 16-61 Box 16-71 5-42 5.2 18#L-80 Seal Stem(w/o 11,288.2 8,398.2 5.2 2.960 15 81 seals)w/Index Mules •• 5-9 I 15-101 D 15-111 • 6-8 6-9 16-101 16-111 • 16-121 ' t16-131 16-141 Page 3/3 Report Printed: 11/7/2013 x .0 « ❑ (1n 1 1 . ■ \\-- ... li . \ f 1 4,t Re 11 vo ,I kii / / cif i Lti t >K;:v ,_ ill // --__ 19 It, , j, \ gli '/,' r y I \ a / . / ''//f \ ' / , 0 \ D 3 4 1 8 w a P 3 a• ?-33 3, 3 Q Q o 0 xo o"5.^mm ° m nmpp 9°np'N z'. 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Upper Completion 1‘.112 I 1)Tubing Hanger 34' 34' 1 , 16"Conductor 2)3-'/" 9.2#/ft TC-II Tubing 3)3-"A"Halliburton NE TRSV w/2.813""X"profile with single1/4"x 0.049"SS Control Line to surface.Cannon I Packer Fluid mix: Cross-coupling clamps on every joint 1,976' 1902' I Inhibited Kill weight 4)3-'%" 9.2#/ft TC-II Tubing Brine 5)3-''A"x 1.5"GLM 9.2#TC-ll BxP w/DCK2 3,490' 2939' 6)3-'/z" 9.2#/ft TC-II Tubing with 2000'TVD 7)3-'A"x 1.5"GLM 9.2#TC-II BxP w/DV 8,858' 5295' 7".". i diesel Cap 8)3-W 9.2#/ft TC-II Tubing 9)2.813""X"Nipple 9 Cr w/3-'A"9.2#/ft TC-ll BxP 9,922' 5828' 1 to surface Ar 1 11-3/4"60 ppf L 80 Hydril 521 10)3-W 9.2#/ft TC-II Tubing pp y 11)3-'A"x 7"Baker Premier Retrievable Feed Thru Packer 10,497' 6041' Surface Casing 12)3-W 9.2#/ft TC-Il Tubing 5 I @ 3513' MD/2949' TVD 13) HES"XN"2.813"(2.75"NoGo)-with RHC Plug Set at 68 deg angle MAX 10,593' 6068' GL J cemented to surface 14)3-W 9.2#/ft TC-II Tubing(2 Joints) 1 15)3-W Halliburton'ROC'Gauge Carrier with single I-wire 11,096' 6158' 1 16)3-%"9.2#/ft Hydril 521 Tubing 1 7" 26 ppf L-80 Hydril 521 17)Ratcheting Mule Shoe 11,269' 6203' ,A? Intermediate 2 Casing End of Assembly: 11,276' 6173' Tie-Back Sleeve Lower Completion 1 D_ i @ 8961' MD/5350'TVD 18)Weatherford 15'Tie Back Sleeve 11,283' 6,174' 19)Weatherford"NTH"Liner Top Packer 11,299' 6,175' 20)Weatherford"PHR"Rotating Hydraulic Set Liner Hanger 11,302' 6,175' I 21)4-%"12.6#/ft L-80 IBT-Mod Slotted Liner w/Torque Rings i 22)4-'h"Hydril 521 Eccentric Shoe 14,510' 6,251' 9 5/8"40 ppf L 80 Hydril 521 End of Assembly: 14,511' 6,251' 1 Intermediate 1 Casing O GL @ 9098' MD/5423'TVD fX i G " 3" ,µa O I -()a I ii ii 3-1/2" 9.3 ppf L-80 TC-IlTubing fggi (0 q17 ' MD 11) Ell .411 Il ._._._. 664 e ' r'ib 0 ::,: TOC Estimated 500'above top of Kuparuk \ 4 Perforated Intervals(MD ft):CD 13490 13520 14060—14090 is * 13520—13550 14125—14155 13650—13680 14270—14300 7"26 ppf L-80 \--, 13695—13725 14320—14350 BTC-Mod , -..,�- ^ ^ ^ Hydril 511 ^����� Il_I-Jl1_L-LI-LI Intermediate 2 ��:- Casing @11428' MD/ -„„, 6182'TVD 4'/i' 12.6#/ft L- V VVU V\I- 6-1/8" Hole TD at 80 IBT-Mod at 14,513' MD/ Slotted Liner 6,251'TVD w/Torque Rings a • Schwartz, Guy L (DOA) From: Schulze, Benjamin <Benjamin.Schulze @halliburton.com> Sent: Wednesday, November 20, 2013 11:59 AM To: Vaughan,Alex; Pollock, Gareth Cc: Talarovich,Jeremy;Jasser, Rami; Kralick,Jack;Tirpack, Robert; Hartwig, Dennis;Shawn Polak;Shearer, Eric;Wedman, Mark Subject: RE:ODSK-13 7"Cement Job info Hi Guys, Here's my quick interpretation since this was logged prior to my coming into the office,The section from 9050'—9380' was logged for free pipe ring determination.The casing appears to be coming in at 250-300psecs,the amplitude of the waveform arriving"'250psecs is very high indicating ringing casing. We didn't start logging for cement until we hit "'10,380'MD. From 10,380—10,765'there appears to be a very strong physical connection with the formation suggesting that there is cement.This is identified by the presence of a strong compressional wave, as well as the casing arrival "250psecs, having a very low amplitude.At 10,765' there appears to be a "20ft that has a very weak physical connection with the formation.This is identified by the disappearance of the compressional wave, and the high amplitude of the casing arrival @ ^'250psecs. From "10,785'MD to "'11,170'MD There appears to be a very strong physical connection. From '11,170—11,240' there appears to be a physical connection with the formation, however it is not as strong as the higher section. This suggests a potential partial cement bond. From 11,240 to 11,330 there appears to be a physical connection because there is a compressional wave, but the casing amplitude is very high. Since the presence of a compressional wave suggests a physical connection, but the casing amplitude suggests free pipe it is likely that there is some channeling over this interval. From 11,330 to the end of the log it appears that there is a weak physical connection with the formation suggesting that there is a partial bond. Please let me know if you have any further questions. 1 • • Thank You and Regards, Benjamin Schulze LWD Technical Advisor/Log Analyst SPERRY DRILLING/HALUBUR1ON ' 50,Hr tiff t-Ili,J '1o. t:tur, 5; Ott 5 907 s:36 mail: Beejam n.t ht I ' ,H0harton corn From: Vaughan,Alex [r?ialltn:Alex.Vaughan aipxd.com] Sent: Wednesday, November 20, 2013 11:11 AM To: Benjamin Schulze; Gareth Pollock Cc: Jeremy Talarovich; Jasser, Rami; Kralick,Jack; Tirpack, Robert; Hartwig, Dennis Subject: ODSK-13 7"Cement Job info Gents, Rami and Jack have been requested by the AOGCC to provide an estimation of the ODSK-13 intermediate two (7") cement top. Attached you will find the BAT log and 7" post job report. Please complete the following tasks today as Rami and Jack are on a time crunch to respond to the AOGCC. If you have questions or need help give me a call on my cell. Ben, Please dig up the estimation of the ODSK-13 7"cement top based on the BAT log and forward to everyone. Gareth, Please provide a volumetric and lift based estimation of the 7"cement top and forward to everyone. Alex Vaughan Senior Drilling Engineer PIONEER NATURAL RESOURCES 907 343 2186 (office) 907.748.5478 (mobile) Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error,please notify the sender by reply e-mail and delete the message and any attachments. This e-mail, including any attached files, may contain confidential and privileged information for the sole use of the intended recipient. Any review,use, distribution, or disclosure by others is strictly prohibited. If you are not the intended recipient(or authorized to receive information for the intended recipient),please contact the sender by reply e-mail and delete all copies of this message. -4 Z • • IIIII BAT DTC BAT DTC m;crosec per ft microsec per ft 240 40 240 40 CASING CASING CASING CASING Energy per microsec er ft rn crosec per ft microsec pe ft p p HF Waveform BAT DTC MD BAT Energy c 255 microsec per ft BAT H F STC BAT H B STC 240 40 f` 240 40 240 40 200 1200 1 : 1200 microseconds !-_ _ GOC____ ----- ---- 9.625"SHOE @ 9098'MD 9050 mor16.1Pummalm s 1111111111111111 a ---r– — --- - CSG _ -- -- 9150 e. ----- -- _"��„ 'R i .... -- if.._= 9200 �,''(i li...:.; 4 ..v. , a■c....... ...... - 71 I I.' ; .� Possible TOC with ■ -4— 9250 '�– >_ - . . . '� - ,� w Channelling First ---- -- .„ " It i - .a. Change in • . waveform. but • —N—Y 9300 _ . . _ - I _--- ____-- , ! fir doubtful � i ii,,,„ 9350 -----r ---9400 -rOl---_ 9 SEE ?_r:lARK#TE 9450 ------- 9500 ----?� -- Free Pipe Ring 9550 I 2 . • 0 Amplitude of the casinr --------- 10200 I diminished indicating ------- not ringing. amplitude ---------_ Strong Compressional Waves wave increases later ii 1 or indicate a strong physical that the wave has tray --------- ,ioattr.tr,,:.._,, connection/4 irl, n, wilt:the. formation casing and into the k ------- _ ----- returnin --------- 103CC _____—— -------- \ I )4 --------- vl --------- ..... ■i■ 110°43:C° - .) . ......... --- -- ., ---- -- ._...7,— --- --- 134E c —— --— -- . , --:— — — .... .—.. 10500 i pl ............ , . ----i— -- I I _ __ __ ___ _— 10550 ‘ ------- . ... .._ .., . ...._ . .., .„. _ , _ _ . .. _ _.... lo60,c . . ' Looks like -20ft 1,...1 _ -. — . , .. ., ----- -AL .7"" Compressional it .141P-- , ., # 0r. ------ -- , ' ‘ wave .. ___-- -- •••■• 10650 ,,4- --;*, . , -...., ------ —— , :. disappears and ------ —: - I casing 5 . arrivals orget -- -- ,,,,,,,, • # strong .....— ....., 10150 : fr— ::.,•ii. . :, _.. ___. . Ir .............. - ------ -- ------1,--- __________ _----, —' ---- . ,,.,7 -- I ■■. . . .1444 . 10800 t r r"') •■•••"••••• 108C 5 .. . . , — — —----t-- ______ ... - . r. , - -.....-. - ' _1111111111111111111111 i c c- ).1.. ■•••■- ■•■•■www■PRONI:.4 1 0 El 00 ■iwn■ •■■■ .! t :■■■■■ ■■ ■■■■■■ ■■ ■■ ■ ■■■■■ ■■ %.t -- — . - ----. , — - 44 --. ,"-'-e . - - ' - ' ,-- * : ■ moon 11000 ,........ 11050 . . . , ; . ., .. • - . iE - ------- . — . :. ,., ‘• 4 r '' ..II NiMe■NM OEM i ., e ' 3 . • Roby, David S (DOA) From: Kralick,Jack <Jack.Kralick @pxd.com> Sent: Thursday, November 14, 2013 10:44 AM To: Roby, David S (DOA) Subject: RE: Sundry application to convert ODSK-13 to an injector Hi Dave, The mystery continues on this well, The most likely theory on this is that some of the products in the mud system had congealed to form an immoveable emulsion. We attempted to perf with no luck, The workover that allowed us to gas lift recently still did not bring fluid to the surface, We did a xylene treatment with coiled tubing with no luck. We've rocked the well with lift gas down the tubing an actually did burp up a couple bbls of 21 degree gravity crude. Bottom hole pressure builds very slowly over time but still no sustainable fluid to the surface. Frustrating in a Kuparuk zone. Thanks, Jack From: Roby, David S (DOA) [mailto:dave.roby0alaska.gov] Sent: Thursday, November 14, 2013 10:34 AM To: Kralick,Jack Subject: RE: Sundry application to convert ODSK-13 to an injector Thanks Jack, One further question,why has this well never produced? Thanks, Dave Roby (907) 793-1232 From: Kralick,Jack[mailto:Jack.Kralick@ pxd.com] Sent: Thursday, November 14, 2013 10:32 AM To: Roby, David S (DOA) Subject: RE: Sundry application to convert ODSK-13 to an injector Hi Dave, Converting this producer to injection will support a future Kuparuk producer on that side of the fault block, The location and timing for that future well is still being evaluated. So mainly this conversion will save drilling an additional injector that would be required to support a well in a slightly different location in the reservoir. Let me know if you need more info. Thanks, Jack 343-2185 From: Roby, David S (DOA) [mailto:dave.roby( alaska.gov] Sent: Thursday, November 14, 2013 10:15 AM To: Kralick,Jack Subject: Sundry application to convert ODSK-13 to an injector 1 • • Jack, I am reviewing the reference sundry application and I was curious why the subject well has never produced and why you think converting it to an injector will provide benefit. Thanks in advamce, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 2 • Bettis, Patricia K (DOA) From: Kralick, Jack[Jack.Kralick @pxd.comj Sent: Thursday, November 14, 2013 6:46 AM To: Bettis, Patricia K(DOA) Subject: RE: ODSK-13: Application for Sundry Approval Our mistake Patricia—could you please change that to WINJ in box 15? — need to do something further. Thanks very much please let me know if we g Jack From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, November 13, 2013 4:16 PM To: Kralick, Jack Subject: ODSK-13: Application for Sundry Approval Good afternoon Jack, On Form 10-403, Box 15-Well Status After Proposed Work, the WAG box is checked. In reviewing the Area Injection Orders for Oooguruk, Kuparuk Oil Pool, authorized injection fluid is water. Is Pioneer requesting to convert the well to a water injector, "WINJ" in Box 15? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. i • Schwartz, Guy L (DOA) From: Schwartz,Guy l(DOA) Sent: Thursday, November 14, 2013 1:34 PM To: Kralick,Jack Subject: ODSK-13 (PTD 209-146) Jack, I need an AOR(Area of Review)for conversion to injection. This is the standard%mile review of the wells in the injection area. Also verify the cement in ODSK-13 was placed properly in the intermediate 2 casing. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 1 • • Schwartz, Guy L (DOA) From: Nelson, Galen <Galen.Nelson @pxd.com> Sent: Monday, November 18, 2013 10:32 AM To: Jasser, Rami; Morgan, Mike; Bond,Andy; Kralick,Jack; Kralick,Jack Subject K-13 area of review Attachments: K13 AOR overview.pdf; K13 AOR vs N4.pdf; K13 AOR vs N4_Distance.pdf; K13 AOR vs N27.pdf; K13 AOR vs N27_distance.pdf; K13 AOR vs N29.pdf; K13 AOR vs N29_Map view.pdf All-I performed a global scan of all actual wells at the Oooguruk Drill site. I created a''/,mile(1320') Polygon encompassing K-13 along the lateral. The attached PDf's are a visual representation of the following. -ODSN-04 was the only well that fell within the'4 mile plain.Where it penetrates is—600'away from K13 at 6251'TVD rkb(12,046'79' MD for ODSN-04) -The TVD depth I chose was the TD of K-13 based on surveys. -ODSN-27 is close but just outside of the polygon, it is 1350'away from K-13 -ODSN-29 is in the Nuiqsut along it's lateral and never penetrates the polygon at the kuparuk. If there are any questions let me know,also please verify depths they are a close estimate and not"exact"due to the programs measuring tool. Galen Nelson TVO Tech Prof-Well Design,Sr G,v'' � r, Sperry Drilling • �,>P I M D 700 G st Suite 600 /0411 03 Anchorage,Alaska 99501 /�� j I 907.343.2119 Office �a tom+ /�'`' 907.223.3394 Work Cell 907.301.6686 Home Cell �i,,,r 1,4 IcrieD weli /_ __- {6 4'1- 6•441--- !4I zero AA d) - 1 FLI•11.11 w/ if list/ STATE OF ALASKA • AIWA OIL AND GAS CONSERVATION COMION NOV 12 2013 REPORT OF SUNDRY WELL OPERR11ONS AOGCC 1.Operations Abandon ( ] Repair Well Li Plug Perforations U Perforate Li per Completion Performed: Alter Casing ❑ Pull Tubing© Stimulate-Frac L] Waiver El Time Il'teriSPo'$ `'" . •I' Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well g 2.Operator 4.Well Class Before Work: 5.Permit to Drill/45103 Name: Pioneer Natural Resources Alaska, Inc Development © Exploratory❑ 6 'ii, 3.Address: 700 G Street,Suite 600 Stratigraphic❑ Service ❑ 6.API Ntl / Anchorage,AK 99501 50-703-20607-00-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 355036/ADL 389958 ODSK-13 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Oooguruk-Kuparuk Oil Pool 11.Present Well Condition Summary: Total Depth measured 14,513 feet Plugs measured N/A feet true vertical 6251 feet Junk measured N/A feet Effective Depth measured 14,495 feet Packer measured See Below feet true vertical 6250 feet true vertical feet Casing Length Size MD TVD Burst Collapse Conductor 110' 16" 158' 158' N/A N/A Surface 3475' 11-3/4" 3513' 2949' 5830 psi 3180 psi Intermediate 1 5816' 9-5/8" 3282'-9098' 2847'-5423' 5750 psi 3090 psi Tie-Back 2478' 7" 8961' 5350' 7240 psi 5410 psi Intermediate 2 11,389' 7" 8950'-11,428' 5344'-6182' 7240 psi 5410 psi Liner 3228' 4-1/2" 11,283'-14,511' 6173'-6251' 8430 psi 7500 psi Perforation depth Measured depth See Attachment,pg 2 feet True Vertical depth feet Tubing(size,grade,measured and true vertical depth) 3-1/2",9.2# L-80,TCII 11,295'MD 6174'MD TRSV @ 1995' Retry Pkr @ 10,516' N i H Liner T op F kr Packers and SSSV(type,measured and true vertical depth) MD/1919'ND MD/6047'TVD @ 11,299'MD/6175' TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED ';Q 13. Representative Daily Average Production or Inlec tbn Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 534 581 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development© N Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil L] • Gas ❑ WDSPL Li GSTOR ❑ WINJ ❑ WAG ❑ GINJ El SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-391 Prepared By:Kathy Campoamor,343-2183 Contact Tim Crumrine,343-2184 Email tim.crumrine oxd.com Printed Name Dennis artwig Title Sr.Staff Drilling Engineer Signature ) y ' 4 o+; Phone 343-2174 Date 10/21/2013 Form 10-404 Revised 10/201• t// °13 Submit Original Only 1;710111e (04, RBEIMS NOV 19 Zn • Pioneer Aral Resources Alaska Inc. ODSK-13 Page 2 AOGCC Form 10-404, Report of Sundry Well Operations Present Well Condition Summary - Box #11 Perforation Depth (MD/TVD) - Attachment 4-W, 12.6#, L-80 IBT-M Slotted Liner : MD ND 11,306' — 11,763' 6175' —6198' 11,963' — 14,495' 6203' —6250' Perforated Intervals: MD ND 13,490' — 13,520' 6225' — 6226' 13,520' — 13,550' 6226' — 6227' 13,650' — 13,680' 6228' — 6229' 13,695' — 13,725' 6230' — 6231' 14,060' — 14,090' 6240' — 6241' 14,125' — 14,155' 6242' — 6243' 14,270' — 14,300' 6244' — 6245' 14,320' — 14,350' 6246' —6246' Blank Pipe Interval : MD ND 11,763' — 11,963' 6198' — 6203' Perations Summary Repo - State Well Name: ODSK-13• NATURAL RESOURCES Well Name: Job Category: Start Date: End Date: Job Category RECOMPLETION Start Depth End Depth Start Date End Date (ftKB) (ftKB) Summary 7/22/2013 7/23/2013 14,513.0 14,513.0 Pre Snubbing Hydraulic Unit Logistics 7/23/2013 7/24/2013 14,513.0 14,513.0 Coordinate with Cudd,Weatherford,CH2Mhill,RSC, ASRC,SLB and Total Safety for upcoming Hydraulic Workover activities. 7/24/2013 7/25/2013 14,513.0 14,513.0 Coordinate with Cudd,Weatherford,CH2Mhill,RSC, ASRC,SLB and Total Safety for upcoming Hydraulic Workover activities. 7/25/2013 7/26/2013 14,513.0 14,513.0 Coordinate with Cudd,Weatherford,CH2Mhill,RSC, ASRC,SLB and Total Safety for upcoming Hydraulic Workover activities. 7/26/2013 7/27/2013 14,513.0 14,513.0 Coordinate with Cudd,Weatherford,CH2Mhill,RSC, ASRC,SLB and Total Safety for upcoming Hydraulic Workover activities. 7/27/2013 7/28/2013 14,513.0 14,513.0 Coordinate with Cudd,Weatherford,CH2Mhill,RSC, ASRC,SLB and Total Safety for upcoming Hydraulic Workover activities. 7/28/2013 7/29/2013 14,513.0 14,513.0 Coordinate with Cudd,Weatherford,CH2Mhill,RSC, ASRC,SLB and Total Safety for upcoming Hydraulic Workover activities. 7/29/2013 7/30/2013 14,513.0 14,513.0 Coordinate with Cudd,Weatherford,CH2Mhill,RSC, ASRC,SLB and Total Safety for upcoming Hydraulic Workover activities. 7/30/2013 7/31/2013 14,513.0 14,513.0 Coordinate with Cudd,Weatherford,CH2Mhill,RSC, ASRC,SLB and Total Safety for upcoming Hydraulic Workover activities. 7/31/2013 8/1/2013 14,513.0 14,513.0 Coordinate with Cudd,Weatherford,CH2Mhill,RSC, ASRC,SLB and Total Safety for upcoming Hydraulic Workover activities. 8/1/2013 8/2/2013 14,513.0 14,513.0 Coordinate with Cudd,Weatherford,CH2Mhill,RSC, ASRC,SLB and Total Safety for upcoming Hydraulic Workover activities. 8/2/2013 8/3/2013 14,513.0 14,513.0 Coordinate with Cudd,Weatherford,CH2Mhill,RSC, ASRC,SLB and Total Safety for upcoming Hydraulic Workover activities. Note:Notified AOGCC of BOPE test in 48 hrs at 0900 hrs on 08/02/13. 8/3/2013 8/4/2013 14,513.0 14,513.0 Coordinate with Cudd,Weatherford,CH2Mhill,RSC, ASRC,SLB and Total Safety for upcoming Hydraulic Workover activities. 8/4/2013 8/5/2013 14,513.0 14,513.0 Coordinate with Cudd,Weatherford,CH2Mhill,RSC, ASRC,SLB and Total Safety for upcoming Hydraulic Workover activities. 8/5/2013 8/6/2013 14,513.0 14,513.0 CUDD Pressure Control conduct BOP test of Premium equipment using LRS hot oil equipment.RU Expro flowback equipment.MD Totco measurement equipment. 8/6/2013 8/7/2013 14,513.0 14,513.0 Standby for 4-1/2"EUE box X 3-1/2 TC II pin crossover being re-worked at the BOT Machine Shop.RU HES slickline to remove 2.79"OD WRP plug.MU CUDD equipment.Attempt to pull tubing hanger© 140,000#. Landing equipment parted and the blind shears were closed to control the well.Attempt to pump kill weight fluid with very limited success. Page 1/5 Report Printed: 10/18/2013 pioNEER Operations Summary Report -State Well Name: ODSK-13 •NATURAL RESOURCES Jobs Job Category RECOMPLETION Start Depth End Depth Start Date End Date (ttKB) (rgce);,I Summary 8/7/2013 8/8/2013 14,513.0 14,513.0 Attempt to pump down tubing via CUDD tri-plex pump unit from 00:00 to 07:30. Pressure up 1500 psi low/2500 psi high. Only able to get 3 BBL total into tubing.Bleed tubing to zero and monitor. RU line to IA from Expro.PT to 2500 psi, bleed down.Open IA to Expro and bleed down IA to zero. Pump down IA via CUDD Tri-Plex pump.Start pumping at 0.50 BPM and work rate to 1.50 BPM at 1932 psi.Pump total of 480 BBL.Shut down pump IA 1078 psi tubing at zero psi. Measure,drift,check,MU threads and MU donut to bottom of stand pipe.PU stand pipevia CUDD gib line and go to well.Tag donut on Premium BOP's blind shear rams via CUDD gib line.PU off Blind Shears and shut pipe rams on stand pipe.Attach FOSV to stand pipe along with Kelly Hose.Open Blind Shears and attempt to pump down tubing.Pump only 2.5 BBLs before reaching 2000 psi.Made three attempts with no success. Bleed down both IA and Tubing to zero and monitor for 6 hours as per town instructions. 8/8/2013 8/9/2013 14,513.0 14,513.0 Monitor well until fishing equipment and personnel on location.Make several attempts to pull sheared landing joint.Each attempt make alterations to fish overshot.Sheared landing joint fished out of well. Attempt to pump into well with NO success.Set BPV,then set dart into hanger to secure well. 8/9/2013 8/10/2013 14,513.0 14,513.0 Clean up in the containment are including the top of wellbay#2.Drop kelly hose into stack and circulate to insure all groundlines and CUDD equipment are free of blockage.Set 5"drillpipe into CUDD jack and scope in Gin Pole.Move equipment around the north and south sides of the wellbays for the upcoming drill rig move.Begin safety stand down at midnight. 8/10/2013 8/11/2013 14,513.0 14,513.0 RD beaver slid from Naborsl9AC utilizing Lattice crane.Once Lattice crane completed work scope on 19AC,picked up 5"elevators and latched up to 5"drillpipe in Cudd 136 HWO jack and pulled 47K. Rigged back guide wires from Cudd 136 HWO to deadmen on the southside of the well bays.Standby while Naborsl9AC continues to move. 8/11/2013 8/12/2013 14,513.0 14,513.0 Set deadman anchors and MU guy wires from Cudd 136 HWO unit.Release and LD 5"drillpipe and elevator from 136 HWO units jack. Conduct safety meeting with both the day and night shifts of Cudd,Expro,ACS,PNR safety,PNR Operations and Well Work Supervisors. 8/12/2013 8/13/2013 14,513.0 14,513.0 State witnessed 11"Premium BOP shear ram installation and pressure test.Hold safety stop meeting with day and night shift with the Cudd personnel.Continue with the Premium 11"BOP test. 8/13/2013 8/14/2013 14,513.0 14,513.0 RU the landing joint and crossovers as per VG and Cudd.Town hall meeting with all crews with Anch management.MIRU HES slickline,IA 12 psi TBG unknown.Cut 120'slickline off the spool,26 turn twist test,MU string BHA-rope socket-female quick connect-male quick connect-roller stem-knuckle joint-roller stem-female quick connect-male quick connect-oil jars-female quick connect-male quick connect-knuckle joint-long stroke spang-female quick connect.Tool BHA-male quick connect -crossover-stem-sample bailer.Have a pre job on picking up the lubricator,with Cudd and HES.MU same onto landing joint and test to 2500 psi.TIH t/1,992'MD(1,963'SLM) tagging up on the flapper flipper.PU 195 S/O 125.POOH into the lubricator and attempt to pump down the tubing. Shut the pumps down at 2500 psi. Took.3 bbls.Bleed pressure to 0 psi,and break down slickline tool string to the rope socket.Wait on orders.Reconfigure tool BHA w/2-5'stem 1 -3'stem and bull nose.Test lubricator to 2500 psi(flapper flipper 10').TIH at 1,957'SLM tagging up,POOH to inspect tools. Could not see any indication on the tool,BHA of where the string was hitting.Shut down for the night. 8/14/2013 8/15/2013 14,513.0 14,513.0 Slickline crew is houred out and are expected to arrive back at ODS around 09:00.Continue slickline work with support from the Cudd 136 HWO unit and personnel.HES crew on location at 10:00,start rigging up to troubleshoot the ScSSV and flapper flipper 8/15/2013 8/16/2013 14,513.0 14,513.0 RDMO slickline so they can move and set SSSV on ODSN-25.Move the combo slickline/E-line unit Der and spot up on ODSK-13. Standby for E-line crew to arrive on ODS. 8/16/2013 8/17/2013 14,513.0 14,513.0 Waiting on wind to die down.RU HES E-line.Standby for HES E-line to fix computer issues. 8/17/2013 8/18/2013 14,513.0 14,513.0 Set WRP with HES E-line and RDMO. Change out landing joint and RU HES slickline to pull WRP and flapper flipper. 8/18/2013 8/19/2013 14,513.0 14,513.0 Continue troubleshooting SSSV. Page 2/5 Report Printed: 10/18/2013 PIONEER • Operations Summary Report -State • Well Name: ODSK-13 NATURAL RESOURCES Start Depth End Depth Start Date End Date (ftKB) (ftKB) Summary 8/19/2013 8/20/2013 14,513.0 14,513.0 Continue troubleshooting SSSV. Make several pump bailer attempts to clean out TRSV. Broke down obstruction able to pump and kill well with 180 bbls.Bleed tubing off and monitor until well is stagnant with no returns. 8/20/2013 8/21/2013 14,513.0 14,513.0 Continue to monitor well until there are no returns coming back.Pump 103 bbls of 10.5 ppg brine. 8/21/2013 8/22/2013 14,513.0 14,513.0 Continue to monitor well until there are no returns set WRP and conduct a BOP test. 8/22/2013 8/23/2013 14,513.0 14,513.0 Finish BOP test. RU slickline and pull the WRP.Pump 85 bbls of 11.1 ppg kill weight brine down the tubing. Monitor well by timing 3 separate 4 gallon"Bucket Tests"every 2 hours. 8/23/2013 8/24/2013 14,513.0 14,513.0 Continue to monitor the well for returns. Perform 3 separate 4 gallon"Bucket Tests"every 2 hours. Change and test the 0-ring on the MCA connection of the landing joint. Prepare all operations and tools to be ready to pull 3.5"completion string. 8/24/2013 8/25/2013 14,513.0 14,513.0 Continue to monitor the well for returns. Perform 3 separate 4 gallon"Bucket Tests"every 2 hours. Get all equipment ready to unseat packer and pull 3.5"completion string. Unseat the the tubing hanger and pull completion up 30'so that the tubing hanger is in the work window. Reverse circulate 325 bb4f 10.7 ppg brine,getting 1 for 1 returns from the tubing and monitor well. 0 1 8/25/2013 8/26/2013 14,513.0 14,513.0 Well still flowing,HES,Baroid built 20 bbls of10.9 ppg brine. Pump 20 bbls of 10.9 ppg brine down the tubing. Bleed pressure back to Expro and monitor the well until there is no-flow. LD tubing hanger and landing joint and intall a TC-Il joint to begin pulling the tubing. 8/26/2013 8/27/2013 14,513.0 14,513.0 2 loads of 10.7 ppg brine from Mi Swaco on barge. Fill all uprights and begin filling the IA and bleeding off the tubing. Record all pressures and volumes for the lubricate and bleed process. 8/27/2013 8/28/2013 14,513.0 14,513.0 Continue to bleed and lubricate down the IA and up the tubing. Incorporate dye additive in the fluid pumped into the IA and begin seeing the dyed fluid in the tubing returns after 12 bbls are pumped down the IA. Hole in the tubing is at approximately 500'. Consult with the Anch team on the string pp Y 9 communication and decide to bullhead 800 bbls down the IA and tubing simultaneously. Begin prepping and cleaning the RSC pits to build the 800 bbls of 10.7 ppg brine. Start sling loading 17 pallets of NaBr with the helicopter.The product will be 17 loads in all at 1 pallet per load. 8/28/2013 8/29/2013 14,513.0 14,513.0 Monitor the well and confirm that there are zero returns coming from the well. Consult with the Anch team to begin pulling the 3.5"completion string. Pull 5 joints and monitor the well. Continue pulling 3.5" completion until joint#60,break circulation both ways to confirm that the ScSSV flapper is open and there is no trapped pressure. Consult with the Anch team and LD the ScSSV. 8/29/2013 8/30/2013 14,513.0 14,513.0 Finish laying down the 3.5"completion string. 8/30/2013 8/31/2013 14,513.0 14,513.0 Finish POOH and LD all 3 1/2"tubing. RU testing equipment and test BOPS. Test 1-Top pipe rams,7 block valves,manual kill,and IBOP. Test 2-Top pipe rams,4 block valves,kill HCR,and FOSV. Test 3 -Top pipe rams,check valve,manual choke,2nd FOSV. All tests charted and held 5 min each-good tests. AOGCC Rep John Crisp waived witness of test 08/28/13 at 1300 hrs. Monitor well at casing valve—slight drizzle. Attempt to test lower pipe rams(test#4)-unsuccessful. LD test joint and test blind rams to 250 psi low/3500 psi high. Also tested 1 block valve,choke HCR,and 2 3/8"IBOP. RD test equipment and prep to run kill string. 8/31/2013 9/1/2013 14,513.0 14,513.0 MU mule shoe and TIH picking up 2 3/8"tubing t/4,761'. Inspect heavy slip dies and change out traveler slip dies.TIH with 2 3/8"tubing f/4,761' t/6,753'. Install TIW valve and monitor well on trip tank --static. Unload trailer of 2 3/8", remove protectors and SLM tubing. TIH with 2 3/8"tubing f/6,753' t/7,061'. Winds and waves unmanageable for crew boat to run. Install TIW valve,close same,and close annular. TIH with 2 3/8"tubing f/7,061' t/9,067'. Page 3/5 Report Printed: 10/18/2013 PI ONEEROperations Summary Report - State Well Name: ODSK-13 NATURAL RESOURCES Start Depth End Depth Start Date End Date (ftKB) (ftKB) Summary 9/1/2013 9/2/2013 14,513.0 14,513.0 TIH with 2 3/8"tubing f/9,067' t/10,022'. MU X-O sub on 2 3/8"tubing to go to hanger pup.Change out traveler dies to run 3 1/2".Land 2 3/8"tubing with hand slips in the window. Land hanger at 10,228' and VG confirm landed.Test upper and lower hanger seals to 5000 psi held 10 min on chart--Good test. Open up bottom pipe ram doors,inspect ram packers.Change out both 2 3/8"x 3 1/2" flex packer elements.Test BOPE to 250 psi low/3500 psi high as per AOGCC approved Sundry:Test 6-Bottom pipe rams with 3 1/2"test joint.Test 7-Bottom pipe rams with 2 3/8"test joint and IBOP.Test 8-Top pipe rams with 2 3/8"test joint and 2 3/8"TIW valve.Test 9-Annular with 2 3/8"test joint and 2 3/8"TIW #2.Pull test joint and test blind rams for test 10.All tests charted and held 5 min each--Good tests. AOGCC Rep John Crisp waived witness of test 08/28/13 at 1300 hrs.Remove test joint and pull test dart and BPV. MU 3 1/2"landing joint into hanger.With IA static—BOLDS and pull hanger to surface.LD hanger and pull tubing to work basket.Establish circulation with 10.7 ppg brine and then pump 20 bbl hi- vis sweep. 9/2/2013 9/3/2013 14,513.0 14,513.0 Circulate 10.7 ppg brine surface to surface taking returns to Expro.POOH with 2 3/8"tubing f/10,022' t/ surface and LD mule shoe. 9/3/2013 9/4/2013 14,513.0 14,513.0 Assemble BHA and torque up same on Nabors 19AC.Winds blowing in excess of 50 mph.Monitor well on trip tank while waiting on weather--static.PU 1 joint of 2 3/8" tubing to assess handling pipe safely. Attempt to set wear bushing in wellhead—unsuccessful.Could not get wear ring past annular element. MU magnet/scraper BHA and TIH t/4,961'. 9/4/2013 9/5/2013 14,513.0 14,513.0 Continue TIH with 2 3/8"tubing f/4,961' 1/11,276'. Connect hydraulic hoses to enable rotary while reciprocating pipe.Establish rotary and tag top of PBR x2 while rotating—confirm tag depth of 11,276'. POOH f/11,276' 1/4,151'. 9/5/2013 9/6/2013 14,513.0 14,513.0 Complete POOH with scaper/magnet run.Break down BHA and MU Champ Packer BHA to test 7" casing and begin to RIH.Champ Packer BHA @ 3,619'at midnight. 9/6/2013 9/7/2013 14,513.0 14,513.0 RIH with Champ packer f/5,144' 1/9,868'. Set packer and test casing to 3500 psi—good test. l eV. Continue TIH f/9,868' 1/11,164'. Test 7"casing to 3500 psi,held 30-min on chart—good test.POOH (/11,164' 1/6,512'. 9/7/2013 9/8/2013 14,513.0 14,513.0 POOH with 2 3/8"tubing f/5,424' to the BHA.RU testing equipment and test BOPE with 3 1/2"test joint to 250 psi low/3500 psi high.Test 1-Annular,8 block valves,and IBOP. Test 2-Top pipe rams,4 block valves,Kill HCR,and FOSV.Test 3-Top pipe rams,manual Kill,Choke HCR,and FOSV#2.Test 4- Bottom P J i P e rams with 3 1/2"testjoint.Test 5-Blind rams,manual Choke,and 1 block valve.All tests charted and held 5 min each--good tests.AOGCC Rep Jeff Turkington waived witness 08/28/13 at 1300 hrs.Closing system psi=3000,after closure 1700,initial 200 psi=:34 full recovery 1:49.Monitor well at casing valve—static. Crane unable to remove tubing from pipe rack due to 40 mph winds. 9/8/2013 9/9/2013 14,513.0 14,513.0 Monitor well on trip tank while shut down due to high winds.Once wind broke,begin bringing in 3 1/2" tubing.Set tubing and begin drifting and measuring for tally as well as confirming lengths of all jewelry. C 9/9/2013 9/10/2013 14,513.0 14,513.0 Run 3-1/2"tubing while monitoring well continually through out the day.RIH with ratcheting mule shoe with No-Go,HES ROC gauge,XN nipple with RHCm,BOT 3.5"x 7"Retrievalbe Packer,X nipple and 3.5"x 1.45"GLM with DGLV installed. 9/10/2013 9/11/2013 14,513.0 14,513.0 Continue to run 3 1/2"tubing while monitoring well continually throughout the day.RIH with SSSV and MU control line.Tag up tubing to lower completion.Verify tag multiple times. 9/11/2013 9/12/2013 14,513.0 14,513.0 Lower tubing hanger 4'below hanger.Tubing setting depth a 11,295'. Pump 90 bbls corrosion inhibitor followed by 80 bbls 10.7 ppg clean brine down tubing.Orient and land hanger and close lock down pins and test hanger.Test good.inn hall and rod and pump into XN nipple and set BOT retrievable packer. Pressure tested and recorded IA and tubing—test ood.Shear out valve in upper GLM test. 7 (&i.4 44 - 9/12/2013 9/13/2013 14,513.0 14,513.0 Continue to RD Cudd Hydraulic Workover equipment as well as Expro flow back equipment and MD Quadco monitoring equipment.All equipment except for Expro will be leaving the island. Page 4/5 Report Printed: 10/18/2013 PIONEER •Operations Summary Report - State Well Name: ODSK-13 NATURAL RESOURCES . Start Depth End Depth Start Date End Date (ftKB) (ftKB) Summary 9/13/2013 9/14/2013 14,513.0 14,513.0 Continue to RD Cudd Hydraulic Workover Unit and all Expro flow back equipment.MD Quadco monitoring equipment and Total Safety equipment has been completely rigged down.All equipment except for Expro will be leaving the island. 9/14/2013 9/15/2013 14,513.0 14,513.0 Continue RD,load out and cleanup for Cudd Hydraulic Workover Unit and all associated equipment. 9/15/2013 9/16/2013 14,513.0 14,513.0 Continue rigging down,load out and cleanup for Cudd Hydraulic Workover Unit and all associated equipment. Page 5/5 Report Printed: 10/18/2013 PIONEER • Operations Summary Report -State Well Name: ODSK-13 •NATURAL RESOURCES Well Name: Job Category: Start Date: End Date: Job Category RECOMPLETION Start Depth End Depth Start Date End Date (ftKB) (ftKB), Summary 9/30/2013 10/1/2013 14,513.0 14,513.0 Perform post HWO slickline work.Pulled the ball and rod,swapped out the valves and pulled the RHC- M.Once the wind subsides,will unstab the lubricator and release the well to Operations for flow test. 10/1/2013 10/2/2013 14,513.0 14,513.0 Set DMY gas lift valve in station#2 and pull the RHC-M that was set in the XN nipple.RDMO HES slickline. 10/2/2013 10/3/2013 14,513.0 14,513.0 RU all surface lines from the well head,flare stack,and the unit 10/3/2013 10/4/2013 14,513.0 14,513.0 Continue RU for the ODSK-13 coil cleanout. 10/4/2013 10/5/2013 14,513.0 14,513.0 RU to perform the Xylene stimulation and coil cleanout on ODSK-13. 10/5/2013 10/6/2013 14,513.0 14,513.0 MIRU CTU#1 to ODSK-13 and MU all associated equipment to begin the cleanout/Xylene treatment job scope. 10/6/2013 10/7/2013 14,513.0 14,513.0 RIH with the Venturi junk basket run to attempt to retrieve the WFT ultra-pak slip die from the HWO completion pull. 10/7/2013 10/8/2013 14,513.0 14,513.0 Begin treating the formation with the diesel/Xylene(16%Xylene)solution across the lateral and attempt to bring the well online. 10/8/2013 10/9/2013 14,513.0 14,513.0 Injected gas into the IA until all diesel was evacuated and started to get gas to surface through the TBG. Laid 50 BBLs of the diesel/Xylene(16%Xylene)mixture across the lateral to treatthe formation. Squeeze and displace the solution with 100 BBLs of diesel and let it soak. 10/9/2013 10/10/2013 14,513.0 14,513.0 Bring the well online and monitor the returns through Expro. 10/10/2013 10/11/2013 14,513.0 14,513.0 Attempt to flow the well through Expro with coil tubing in the hole while injection diesel and nitrogen through the coil. Page 1 Report Printed: 10/18/2013 PI ONEER • Current Schematic - State 0 Well Name: ODSK-13 NATURAL RESOURCES Sidetrack 2, 10/21/2013 5:18:51 PM Well Attributes Vertical schematic(actual) API/UW Field Name Well Status Total Depth(ftKB) 50-703-20607-00-00 Oooguruk Unit DRILLED 14,513.0 Casing Strings Conductor,158.0ftKB Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Depth...Grade Top Thread Wt/Len(I... i Conductor 16 14.670 47.7 158.0 158.0 H40 Welded 109.00 if-F-71 Casing Components Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 2-3 1-1 Conductor Shoe 47.7 47.7 16 14.670 a • i 3-1 Surface,3,512.6ftKB uuu Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Depth...Grade Top Thread WVLen(I_. 15-11 . Surface 11 3/4 10.772 37.7 3,512.6 2,949.2 L-80 HYD521 60.00 Casing Components Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 2-1 VG Landing Jt. 37.7 37.7 14 5/8 10.772 f 2-2 VG Hgr-LS=1.24 37.7 37.7 11 3/4 10.772 ® - MITI 2-3 Pup Joint 38.9 38.9 11 3/4 10.772 1 I 2-4 Casing Joints 41.9 41.9 11 3/4 10.772 5-3 2-5 HES Float Collar 3,427.2 2,911.3 11.95 10.772 5-4 2-6 Csg Joint 3,428.9 2,912.0 11 3/4 10.772 2-7 11 3/4"Surface Shoe 3,510.7 2,948.3 11.95 10.772 HES Float Shoe ® I Intermediate2 Tie-back 10/2/2011,8,962.2ftKB IT--2-1 Casing Description OD(in) ID(in) Top MKS) Set Depth(ft... Set Depth...Grade Top Thread WVLen(I_. Intermediate2 Tie- 7 6.276 39.4 8,962.2 7,573.5 L-80 BTC-M 26.00 IT-T1 back 10/2/2011 I. Casing Components • 3-3 Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn I5-71 •-I1-1 3-1 Vetco 7"Casing Hanger& 39.4 39.4 7 6.276 pup 3-2 Casing 41.5 41.5 7 6.276 3-3 Casing Pup Joint(estimated 82.5 82.5 7 6.276 ■ I ■ length) �� 15-81 2-4 3-4 Casing 104.6 104.6 7 6.276 • - 1T- 1 3-5 Casing 8,901.8 7,540.1 7 6.27 , 3-6 Casing Pup Joint 8,940.6 7,561.6 7 - •.276 °01 1 5-10 f 3-7 XO pup-VAM TOP pin X 8,943.7 7 -•- 3 - , 7 6.276 BTC-M box 15-111- 3-8 WFT"Hold Down"sub w/ 8,94-.4 7,564 7 6.276 .."„....°7 VAM Top pin 5-12 3-9 XO-7"26#IBT pin X VAM 8,949. ,566.5 7 6.276 f__1411 TOP box - 3-10 Locator sub 8,951.4 7,567.6 8.29 6.276 • 14-21 3-11 WFT seals w/ind.muleshoe 8,952.3 7,568.0 7 6.276 total length 20.32 14-31 Intermediate) Drilling Liner,9,098.0ftKB • 14-41 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Depth...Grade Top Thread Wt/Len(I... Intermediate) 9 5/8 8.835 3,282.0 9,098.0 5,310.5 L-80 Hyd 521 40.00 Drilling Liner Casing Components ® Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 4-1 WFT"PBR"Tie back sleeve 3,282.0 2,726.1 9 5/8 8.835 2-6 15-131 4-2 WFT 9 5/8 x 11 3/4"TSP4R" 3,303.7 2,737.1 9 5/8 8.835 Liner top pkr 4-3 WFT 9 5/8 x 11 3/4"PHS" 3,305.8 2,738.2 9 5/8 8.835 Liner hng ' 2-7 4-4 XO 9 5/8 GBB box X HYD 3,310.8 2,740.6 9 5/8 8.835 5-14 521 pin 4-5 Casing 3,312.3 2,741.4 9 5/8 8.835 15-151 4-6 Ldg Collar 8,976.1 5,245.3 9 5/8 8.835 3 4 4-7 Casing 8,977.0 5,245.8 9 5/8 8.835 5-16 I 4-5 Page 1/3 Report Printed: 10/21/2013 i Current Schematic - State Well Name: ODSK-13 P IONEER • NATURAL RESOURCES Sidetrack 2, 10/21/2013 5:18:53 PM Casing Components Vertical schematic(actual) Item# Item Des Top Top(TVD) p(ftKB) (ftKB) OD(in) ID(in) Corn 15-16 1 33-4 4-8 Ldg Collar 9,015.9 5,266.6 9 5/8 8.835 C4 5 4-9 Casing 9,017.3 5,267.3 9 5/8 8.835 4-10 Float shoe 9,096.2 5,309.5 9 5/8 8.835 15-171 Intermediate2 9/6/2011,11,428.0ftK6 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ft.. Set Depth...Grade Top Thread W/Len(I... 15-181 I Intermediate2 7 6.276 8,949.6 11,428.0 8,406.2 L-80 Hyd 511 26.00 9/6/2011 Casing Components 15-191 Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 5-1 Polish Bore Receptacle 8,949.6 7,566.6 7 6.276 5-2 WFT TSP5 Liner Top Pkr 8,970.5 7,578.1 7 6.276 5-3 Vam Top Collar box X box 8,974.4 7,580.2 7 6.276 , 13-5I 5-4 PHR Liner Hanger 8,975.4 7,580.7 7 6.276 5-5 X-O Vam Top box X Hyd 8,981.4 7,584.0 7 6.276 511 pin 1.,E 13-6I 5-6 7"Casing 8,983.6 7,585.2 7 6.276 5-7 WFTLanding Collar 11,305.7 8,399.3 7 6.276 . 3-7 5-8 7"Casing 11,306.9 8,399.4 7 6.276 5-9 Float Collar 11,346.1 8,401.7 7 6.276 15-201-8. • F- 1 7"Casing 11,347.7 8,401.8 7 6.276 5-11 Halliburton Shoe 11,426.0 8,406.2 7 6.276 i 3-9 Production Liner,14,511.0ftKB Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Depth...Grade -'op Thread VWLen(I_. I Production Liner 4 1/2 3.958 11,283.3 14,511.0 8,478.0 L-80 12.60 13-10I Casing Components Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Com .3 11 6-1 Polish Bore Receptacle 11,283.3 8,397.9 4 1/2 3.958 5-1 6-2 NTH Liner Packer 11,298.7 8,398.8 4 1/2 3.958 r 6-3 Collar 11,301.2 8,399.0 41/2 3.958 6-4 PHR Liner Hanger 11,302.0 8,399.1 4 1/2 3.958 6-5 XO 4.5"Hyd 521 p x 5"New 11,307.3 8,399.4 4 1/2 3.958 I5 21 Vam b 6-6 4.5"12.6#L-80 Hyd 521 pup 11,308.1 8,399.4 4 1/2 3.958 1T1 6-7 XO 4.5"IBT-M p x 4.5"Hyd 11,317.8 8,400.0 4 1/2 3.958 521 b 6-8 Slotted Liner 11,319.0 8,400.1 4 1/2 3.958 6-9 XO Hydril 521 by IBT-M 11,776.3 8,423.9 4 1/2 3.958 4-6 6-10 Solid Liner 11,778.4 8,424.1 4 1/2 3.958 15_41 6-11 XO IBT-M by Hydril 521 11,974.9 8,426.7 4 1/2 3.958 6-12 Slotted Liner 11,976.5 8,426.7 4 1/2 3.958 6-13 XO IBT-M by Hydril 521 14,507.6 8,477.9 4 1/2 3.958 15-51 6-14 Shoe 14,509.7 8,477.9 41/2 3.958 Tubing Strings Tubing Description String M_. ID(in) Top(ftKB) Set Depth(f_.Set Dept...Nit(Ibtft) Grade Top Thread Tubing-Production 3 1/2 2.992 32.1 11,295.0 8,398.6 9.20 L.-80 TC-II Tubing Components 5-21 , . ". Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn ' 14-71 5-1 RKB correction for CUDD 32.1 32.1 3 1/2 2.992 5-2 VG Tubing Hanger 51.1 51.1 3 1/2 2.992 5-3 P x P X-O Pup 52.6 52.6 3 1/2 2.992 'l 4-g 5-4 X-O Pup Joint TC-II box X 56.6 56.6 3 1/2 2.992 IBT-M pin 5-5 X-O Pup Joint IBT-M box X 58.5 58.5 3 1/2 2.992 4-9 IC-II pin 5-6 3.5"Tubing Joint 60.5 60.5 3 1/2 2.992 • 14-101 5-7 Space Out Pup 92.9 92.9 3 1/2 2.992 5-8 3.5"Tubing Joint 116.1 116.1 3 1/2 2.992 15-221 1 I 5-6 5-9 Pup Joint 1,980.7 1,965.0 3 1/2 2.992 Page 2/3 Report Printed: 10/21/2013 IONEER 0 Current Schematic - State 0 Well Name: ODSK-13 P NATURAL RESOURCES Sidetrack 2, 10/21/2013 5:18:54 PM Tubing Components Vertical schematic(actual) Item# Item Des Top Top(TVD) p(ftK8) (ftK6) OD(in) ID(in) Com 15-221 5-10 HES TRSSSV w/2.813""X" 1,995.4 1,979.4 3 1/2 2.992 profile Fl- 5-11 Pup Joint 2,000.3 1,984.2 3 1/2 2.992 15-241 5-12 3.5"Tubing Joint 2,015.1 1,998.6 3 1/2 2.992 ® 5-13 Pup Joint 3,494.6 3,408.8 3 1/2 2.992 5-14 HES 3.5"x 1.5"GLM 9.2# 3,509.4 3,422.5 3 1/2 2.992 15-261 a Toll BxP w/dummy 15.271 5-15 Pup Joint 3,518.2 3,430.7 31/2 2.992 15-28 5 6 5-16 3.5"Tubing Joint 3,533.0 3,444.3 3 1/2 2.992 5-17 Pup Joint 8,861.7 7,517.7 3 1/2 2.992 15-291 . 5-18 HES 3.5"x 1.5"GLM 9.2# 8,876.5 7,526.0 3 1/2 2.992 5-30 ,'47'11 /p 51& Toll BxP w/1/4"OV 1 5-19 Pup Joint 8,885.4 7,530.9 3 1/2 2.992 15-311 /„�? T✓� 5-20 3.5"Tubing Joint 8,900.2 7,539.2 3 1/2 2.992 ® CPS 5-21 X-O Pup Joint TC-II box X 8,994.7 7,591.3 3 1/2 2.992 I IBT-M pin 15 331 5-22 3.5"Tubing Joint 8,996.7 7,592.4 3 1/2 2.992 5-34 or 5-23 X-O Pup Joint IBT-M box X 9,892.2 8,039.1 3 1/2 2.992 at 15-351 TC II pin 5-24 3.5"Tubing Joint 9,894.3 8,040.1 3 1/2 2.992 15-36 I 5-25 Pup Joint 9,926.7 8,054.2 3 1/2 2.992 15.371 5-26 HES"X"Nipple w/2.813" 9,941.4 8,060.7 3 1/2 2.992 bore 5-38 SIN 5-27 Pup Joint 9,942.7 8,061.3 3 1/2 2.992 15-391 I 5-28 3.5"Tubing Joint 9,957.4 8,067.7 3 1/2 2.992 15-401 5-29 Pup Joint 10,505.6 8,268.1 3 1/2 2.992 5-30 BHI 3.5"x 7"Premier Feed 10,515.7 8,271.0 3 1/2 2.992 Thru Retrievable pkr 5-41 li 5-31 Pup Joint 10,523.0 8,273.0 3 1/2 2.992 5-42 6-1 5-32 3.5"Tubing Joint 10,533.1 8,275.8 3 1/2 2.992 5-33 Pup Joint 10,597.4 8,293.1 3 1/2 2.992 5-34 HES"XN"Nipple with 2.750" 10,612.1 8,296.9 3 1/2 2.992 1€--_ 16-21 No-Go 5-35 Pup Joint 10,613.5 8,297.2 3 1/2 2.992 1 16-31 5-36 3.5"Tubing Joint 10,628.3 8,301.0 3 1/2 2.992 16-41 5-37 Pup Joint 11,107.7 8,383.3 3 1/2 2.992 ' 5-38 ROC Gauge Mandrel 11,115.4 8,384.1 3 1/2 2.992 I15-71 4' 5-39 Pup Joint 11,120.0 8,384.6 3 1/2 2.992 5-40 3.5"Tubing Joint 11,125.7 8,385.2 3 1/2 2.992 16-5 5-41 Locator Collar w/5" 11,286.4 8,398.1 5 1/2 2.992 LTC8RD Box x 3-1/2 TC-II 6-6 Box 6.7 5-42 5.2 18#L-80 Seal Stem(w/o 11,288.2 8,398.2 5.2 2.960 5 8 seals)w/Index Mules •• 5-9 P 15-101 I. 16-111 • 6-8 16-91 16-101 16-111 • 16-121 6-13 6-14 Page 3/3 Report Printed: 10/21/2013 • • ODSK-13 Kuparuk Production Well Completion FINAL Updated 11/19/2013 I Upper Completion 4 L I 1)Tubing Hanger 34' 34' I 16"Conductor 2)3-'/z" 9.2#/ft TC-II Tubing 3)3-1/2"Halliburton NE TRSV w/2.813""X"profile with single1/4"x 0.049"SS Control Line to surface.Cannon • I Packer Fluid mix: Cross-coupling clamps on every joint 1,976' 1902' Inhibited Kill weight 4)3-'/2" 9.2#/ft TC-II Tubing Brine 5)3-1/2"x 1.5"GLM 9.2#TC-II BxP w/DCK2 3,490' 2939' with 2000'TVD 6)3-'1/2�" 9.2#/ft TC-II Tubing *seam : 7)3-/2"x 1.5"GLM 9.2#TC-II BxP w/DV 8,858' 5295' kldiesel Cap 8)3-W 9.2#/ft TC-II Tubing © 9)2.813' 'X"Nipple 9 Cr w/3-/ 9.2#/ft TC-II BxP 9,922' 5828' I to surface 11-3/4"60 f L-80 H dril 521 10)3-'V 9.2#/ft TC-II Tubing pp y .11)3-1/2"x 7"Baker Premier Retrievable Feed Thru Packer 10,497' 6041' Surface Casing 12)3-W 9.2#/ft TC-II Tubing @ 3513' MD/2949'TVD 13) HES"XN"2.813"(2.75"NoGo)-with RHC Plug 10,593' 6068' © GL cemented to surface Set at 68 deg angle MAX 14)3-W 9.2#/ft TC-II Tubing(2 Joints) 15)3-1/2'Halliburton'ROC'Gauge Carrier with single I-wire 11,096' 6158' 16)3-1/2"9.2#/ft Hydril 521 Tubing i 7"26 ppf L-80 Hydril 521 17)Ratcheting Mule Shoe 11,269' 6203' Intermediate 2 Casing End of Assembly: 11,276' 6173' 1 Tie Back Sleeve Lower Completion L i @ 8961' MD/ 5350'TVD 18)Weatherford 15'Tie-Back Sleeve 11,283' 6,174' 19)Weatherford"NTH"Liner Top Packer 11,299' 6,175' 20)Weatherford"PHR"Rotating Hydraulic Set Liner Hanger 11,302' 6,175' 21)4-Y2"12.6#/ft L-80 IBT-Mod Slotted Liner w/Torque Rings 22)4-1/2"Hydril 521 Eccentric Shoe 14,510' 6,251' 9-5/8"40 ppf L-80 Hydril 521 End of Assembly: 14,511' 6,251' Intermediate 1 Casing 7 GL @ 9098' MD/5423'TVD 0 I x ! 3-1/2" 9.3 ppf L-80 TC-I(Tubing i0Vi7' MD tioKt' rvp IM 411) 13 TOC Estimated 500'above top of Kuparuk Perforated Intervals(MD ft): < I"' :zo 13490—13520 14060—14090 19 13520—13550 14125—14155 :::; 13650—13680 14270—14300 7"26 ppf L-80'il:: � 13695—137255 ^ ^ ^ ^ ^14320-14350 BTC-Mod . -, .,� LL LI 1111_LI_Il Hydril 511 -. „� Intermediate 2 - �.� Casing 2z @11428' MD/ 6182'TVD 4-1/2" 12.6#/ft L- V 1 V V V Y 6-1/8" Hole TD at 80 IBT-Mod at 14,513' MD/ Slotted Liner 6,251'TVD w/Torque Rings + STATE OF ALASKA � - 1 AASKA OIL AND GAS CONSERVATION COASION JUL 1 g 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon [J Repair Well[J Plug Perforations U Perforate U Other LI Patch Tbg&Establish Flow Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Pioneer Natural Resources Alaska, Inc Development El . Exploratory ❑ 209-146 • 3.Address: 700 G Street,Suite 600 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99501 50-703-20607-00-00 , 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 355036/ADL 389958 ODSK-13 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Oooguruk-Kuparuk Oil Pool 11.Present Well Condition Summary: Total Depth measured 14,513 feet ' Plugs measured N/A feet true vertical 6251 feet Junk measured N/A feet Effective Depth measured 14,495 feet Packer measured See Below feet true vertical 6250 feet true vertical feet Casing Length Size MD ND Burst Collapse Conductor 110' 16" 158' 158' N/A N/A Surface 3475' 11-3/4" 3513' 2949' 5830 psi 3180 psi Intermediate 1 5816' 9-5/8" 3282'-9098' 2847'-5423' 5750 psi 3090 psi Tie-Back 2478' 7" 6482'-8960' 4223'-5349' 7240 psi 5410 psi Intermediate 2 11,389' 7" 11,428' 6182' 7240 psi 5410 psi Liner 3241' 4-1/2" 11,270'-14,511' 6173'-6251' 8430 psi 7500 psi Perforation depth Measured depth See Attachment,pg 2 feet C tt True Vertical depth feet SCANNED NOV 0 C 2013 Tubing(size,grade,measured and true vertical depth) 3-1/2",9.2# L-80,TCII 11,276'MD 6173'MD TRSV(a©1997' Hyd II Pkr©9016' Ni H Liner top Pkr Packers and SSSV(type,measured and true vertical depth) MD/1921'TVD MD/5379'TVD ®11,299'MD/6175' TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development el " Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil [ Gas Li WDSPL U GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 312-043 Prepared By:Kathy Campoamor,343-2183 Contact Kathy Campoamor,343-2183 Email kathy.campoamorApxd.com Printed Name Kathy Campoamor Title Engineering Tech II Signature j�� , Phone 343-2183 Date k, Form 10-404 Revised 10/2012 1319 V j Submit Original Only • • Pioneer Natural Resources Alaska Inc. ODSK-13 Page 2 AOGCC Form 10-404, Report of Sundry Well Operations Present Well Condition Summary — Box #11 Perforation Depth (MD/TVD) - Attachment 4-W, 12.6#, L-80 IBT-M Slotted Liner : MD ND 11,306' - 1l,763' 6175' — 6198' 11,963' — 14,495' 6203' — 6250' Perforated Intervals in existing Slotted Liner (Feb 2012): MD ND 13,490' — 13,520' 6225' — 6226' 13,520' — 13,550' 6226' — 6227' 13,650' — 13,680' 6228' — 6229' 13,695' — 13,725' 6230' —6231' 14,060' — 14,090' 6240' — 6241' 14,125' — 14,155' 6242' — 6243' 14,270' — 14,300' 6244' — 6245' 14,320' — 14,350' 6246' — 6246' Blank Pipe Interval : MD ND 11,763' — 11,963' 6198' — 6203' PIONEEROperations Summary Report - Se Well Name: ODSK-13 NATURAL RESOURCES Well Name: Job Category: Start Date: End Date: Job Category WELL SERVICE Start Date End Date Start Depth(ftKB) End Depth(ftKB) Summary 2/10/2012 2/11/2012 0.0 0.0 Witness PTof all safety systems on the Expro equipment. Move in SLB Coil Tubing Unit,spot up unit and begin rig up. 2/11/2012 2/12/2012 0.0 0.0 Hold prejob safety meeting,with Pioneer,Expro,SLB and Pollard. Perform BOP test on back of the unit.MU Baker MHA and 2.63"OD Venturi and junk basket.Stab injector on Wellhead. Pressure lines with diesel LPT 500psi,HPT 4000 psi.Secure equipment for the night. 2/12/2012 2/13/2012 0.0 0.0 Hold Pre job safety meeting. PT lubricator to 3800 psi.RIH with 2.63"OD venturri and junk basket 1114,450'.Did not hit any obstructions,POOH recovered less than a 1/4 cup of gunk. MURIH jet swirl nozzle 1111,300'started pumping hot water-140 dgrees.Make 2 passes f/11,300'1114,448'jetting the slotted liner.Start N2 at 1000 scf/min until N2 reaches Nozzle,Slow N2 rate to 500 scf/min.POOH U11,300'. POOH 119,000' continue pumping N2.RBIH 1111,300' increase N2 rate to 700scf/m.POOH while pumping N2,recovered-249 bbls of fluid while jetting with N2.Shut in swab valve and leave well open to Expro,put well in by pass to flow back tanks. Shut down for the night. 2/13/2012 2/14/2012 0.0 0.0 Fluid level in tubing at 09:00 was 4,200'. At 14:00 was 4,000'and IA was 4,800'.RIH with Jet swirl nozzle 1111,500'while waiting for N2 to get ready pump.Start N2 CO 500 scf/min,POOH U11,000'. Increase rate to 1000 scf/m,then to 1500 scf/m until N2 turned corner,then back to 500scf/m.RIH at 34fpm jetting with N2 1114,406',Problem developed with CTU reel.Shut down N2 to fix reel.Total fluid recovered 74.8 bbls 2/14/2012 2/15/2012 0.0 0.0 Re-start N2 lift.Nozzle at 14,400'. Increase N2 rate to 750 scf min begin POOH at 50 fpm.OOH with Coil,close swab,keep well open to Expro,total fluid recovered from midnight 28.93 bbl. Have Operations shoot fluid levels,IA&Tubing at 6,000'. Fluid reported on expro would contain -47.5 bbls of fluid from the IA from previous day.RU and pump 1000 gal of 7.5%dad, jetting the acid across the entire interval f/11,300'1/14,400'. Follow acid with 20 bbls water mixed with soda ash for nuetralizer. Jet back through interval with 50 bbls seawater, then start lifting with N2 starting with 2000 scf/min,dropping rate to 500 scf/min.Jet well with N2 f/14,400'back U surface.Fluid recovered midnight to midnight 214.1 bbls,consisting of 109.8 bbls water and 104.3 bbls oil(mostly diesel that was pumped on pressure testsing coil) 2/15/2012 2/16/2012 0.0 0.0 Continue with N2 Lift,total fluid recovered since midnight 21.5 bbls wate with trace oil.shut down,crew houred out.Operation pump 20 bbls diesel down IA.Loaded tubing with seawater. MU Baker MHA,pull test,MU nozzle RIH 111,200'. Jet with N2 until no fluid coming back to allow for 500 psi underbalnce.POOH,MU SLB firing head and 30 ft of 2"6 spf PJ 2006 guns. PT to 2500 psi on backside of guns.RIH with guns-Job in progress 2/16/2012 2/17/2012 0.0 0.0 RIH with 30 ft of 2"6 spf PJ 2006 guns 1/14,391'. POOH to line up ball drop at 14,371'.Launch ball,POOH U14,350'bottom shot,Pump 34 bbls,pressure up and peforate 14,320'-14,350'. POOH,LD fired guns.Change out Baker MHA with a WFD MHA because of shorter length on WFD.Fill coil with 13 bbls diesel and test MHA,MU 30&RIH 30 ft of 2"6 spf PJ 2006 guns U14,300'bottom shot.Launch 1/2"ball and pump 38 bbls pressured up and peforate 14,270'- 14,300'.POOH,LD fired guns and MU 30 ft of 2"6 spf PJ 2006 guns,use 24 bbls to fill Coil, RIH and perforate f/14,125'U14,155'using 36 bbls diesel.POOH,LD fired guns,Fluid pack CT, PT connector with 20 bbls diesel.MU 30 ft of 2"6 spf PJ 2006 guns,PT on backside to 2500. -Job in Progress 2/17/2012 2/18/2012 0.0 0.0 Continue in hole with 30 ft of 2"6 spf PJ 2006 guns,U14,155'. POOH 1114,166',Launch ball)in reel,POOH t/14,090' bottom shot(top @ 14,060'). Ball landed with 35.4 bbls pumped pressure up to 3200 psi,guns fired,POOH,LD fired guns and MU 30 ft of 2"6 spf PJ 2006 guns,use 32.2 bbls to fill Coil and test RIH and perforate f/13,695'-13,725'using 36 bbls of diesel to pump ball.POOH,LD fired guns.MU 30 ft of 2"6 spf PJ 2006 guns,RIH,at 6,500'cracks were discover on reel,discussed with SLB cell leader,Pioneer HSE,operations and drilling on welding on location,discussed the hazards,communication,&migation of the hazards.The decision made by all present that the welding could be performed safely on location. POOH,secure well. 2/18/2012 2/19/2012 0.0 0.0 Complete repair on reel,perform chain inspection and BOP test.Accumulator failed test,wait on mechanic to fix. Page 1/2 Report Printed: 7/18/2013 • P I ® N E ER • Operations Summary Report - Se Well Name: ODSK-13 NATURAL RESOURCES Jobs Job Category WELL SERVICE Start Date End Date Start Depth(ftKB) End Depth(ftKB) Summary 2/19/2012 2/20/2012 0.0 0.0 Finish repairs,complete the BOP test,MU 30 ft of 2"6 spf PJ 2006 guns PT coil connector to 3800 and backside of guns to 2500.RIH to flag at 13,587'. PU U13,680'bottom shot,launch ball,ball on seat with 35 bbls diesel,pressure up to 3250 psi,guns fired perf zone 13,650'- 13,680'.POOH,LD fired guns.Test connector to 3800 psi,MU 30 ft of 2"6 spf PJ 2006 guns, PT backside to 2500 psi.RIH to flag,PU U13,550'bottom shot(top©13,520').Perf Launch ball ball on seat with 35.1 bbls,Perf zone 13,520'- 13,550'.POOH,LD fired guns.PT coil connector to 3800 psi,MU 30 ft of 2"6 spf PJ 2006 guns,PT backside to 2500 psi, RIH--Job continued 2/20/2012 2/21/2012 0.0 0.0 Continue RIH to flag PU t113,520'bottom shot(top at 13,490').Launch ball,ball on seat with 34.3 bbls,pressure up to 3150 psi-guns fired.POOH,LD fired guns.PT Coil Connector,MU 30 ft of 2"6 spf PJ 2006 guns.PT backside to 2500 psi.using 21 bbls,Start RIH,Run aborted do to a new crack found in reel.POOH.Call for N2 to blow down reel,RD unit to send to yard for repair.Job incomplete 3/7/2012 3/8/2012 0.0 0.0 Wait on tractor to be replaced under Coil Unit, 3/8/2012 3/9/2012 0.0 0.0 MIRU Coil tubing unit,Perform BOP test, Job in Progress 3/9/2012 3/10/2012 0.0 0.0 Complete BOP test.Prepare to cut when when main winch failed.Could not be repaired on Location. RD unit and sent to to yard for repairs and scheduled maintenance 3/21/2012 3/22/2012 0.0 0.0 Move on&RU Halliburton Coil Unit.Complete pre-pad inspection&held PJSMs.RU CTU. 3/22/2012 3/23/2012 0.0 0.0 Test lines.PU&MU lubricator.Test BOPE to 4000 psi.Had leaking swab valve.Repacked& greased valve. 3/23/2012 3/24/2012 0.0 0.0 MU drift assy.MHA,Stinger&2.25"Nozzle.RIH to 14,290'.POOH.Had steel wool in choke as before.MU perf gun&RIH w/same t/1,973'&stopped.Hitting on TRSV,2.813"ID.Cycle valve &attempt to go thru several times.No success. 3/24/2012 3/25/2012 0.0 0.0 Con't to attempt to go thru TRSV,no success.POOH&LD 2.25"nozzle.Had problem w/leaking chain drive lubricator.Repair same.PU 2.5"nozzle,RIH&attempt to wash thru 2.813"TRSV w/o success.POOH&recovered add'I steel wool mat'I.LD nozzle&BHA.Completely RD& move off CTU to allow for rig move. 3/25/2012 3/26/2012 0.0 0.0 Move CTU back up on location.Spot in unit&begin RU over well. 3/26/2012 3/27/2012 0.0 0.0 Finish RU CTU on Wellbore. MU lubricator&stab on injector head.PU 2.125"tool string w/ 2.125"magnet.Pressure test to 3000 psi.RIH w/magnet U1,974'&tag.Work magnet&cycle TRSV.No progress.POOH&recover add'I steel wool mat'l.MU 2.25"Wash Nipple&RIH.Wash U1,974'&tag hard.POOH&cycle TRSV.RIH, back w/2.25"nozzle&tag up(d1 1,974'.POOH &LD nozzle.Secure well&wait on mud motors&mills. 3/27/2012 3/28/2012 0.0 0.0 PU 2.25"Venturi Junk Basket.RIH&tag up hard©1,979.86'.PU 10'&Work VJB©1.5 BPM, 2000 psi.Tag up©1,979.7'.Work VJB up&down several times w/o progress.Final depth 1,979.7'.POOH&secure well.Recovered 1/2 cup of steel wool material.Dispatch ScSSSV tech from PB to troubleshoot valve. 3/28/2012 3/29/2012 0.0 0.0 PT lubricator&RIH w/2.73" LIB.Tagged up©1,983.4'.POOH&recover LIB.No impression on LIB.Blow down reel with N2 to open top tank.Release CTU.RD&move off CTU. Page 2/2 Report Printed: 7/18/2013 • • PIONEER NATURAL RESOURCES ODSK-13 Completion Schematic - Current . 9., .., . , hie I km MD 01) MI 011, 16"Conductor A 16-Conductor 158 158 B 11-314"60111.430Hydri 52t 10.772"ID 3,513 2,949 C 9-51r 401 1-80Hydr1521,1 835"10' 9,093 5,423 Packer Fluid mix D T 28111-80 EITC-M,6.276"ID Tie-Sack 8,961 5,350 Inhibited Kill weight E T 2E41-80 Hythil 511,8.2713"13 Liner 11,428 8,182 F 4-1r2" IBT-M Slated 3.958"ID et tc‘que rings 14,511 8,251 miammanaimiaTh9.211436 TO 11,278 8,173 with 2000'TVD diesel cap , 1 VetooGray Tbg Hanger w/3.725 MCA Boor m 3-82 TC-113 34 34 3-1/2"1281-80 TC-1 Pup Joint Ph tr Fln i 11-3/4"60 ppf L-80 Hydril 521 X0 iri3-1121BT Boit ir 3-112 TC-1 Pin Surface Casing 1 3-V2"9.2 1-80 TC-11 Tubing 3-1/2"'9.2 L-80 TC-I1Pup Joint et Collet @ 3513' MD/2949 TVD Welister 71,191/w 3-1/29.2 TC1 Boor H Pin Chr 2.613 at cemented to surface ! 2"X'Profile,OM e.049 SS Control line 1,997 1,921 3-1,2"92 L-80 TC-1 Pup Joint tit Caw 3-V2"&2 L-so TC-1 Tubing 3-V2-921-80 TC4 Pup Joint w i Cola II I 7"26 ppf L-80 Hydril 521 Intermediate 2 Casing Tie-Back Sleeve @ 8961'MD/5350'TVD 3 DI.M*1-Vanol 3-V2"K 4-1/2-w 3-1/2"TC1 DOH w Pin 3,496 2,942 , 4 3-12"9.2 1-80 TC-I1Pup Joint inoller 3-12"12 L-80 TC4 Tubing 3-V2"12 L-80 TC-I1Pup Joint wi Collar GUI*2-Vanoil 3-1/2"it1-112"w 3-12"TC1 Doe w Pin 6,864 5,309 3-12-12 L-80 TC-1 Pup Joint w/Colo 2"12 1-80 TC-1 Tubing 3-V2'121-80 Tal Pup Joint wi Collar HES2813 X N1wle w 3-12 9.21111Bani Pin 9-5/8"40 ppf L-80 Hydril 521 3-12'12 1-80 TC-1 Pup Joint ir/Collar 3-12'a2 1410 TC-1 Tubing Intermediate 1 Casing 3-117 12 1-80 Tr-4PuoJohe w)Collar 1 @ 9098'MD/5423'TVD X0 3-V2 1-80 w TIN Bose New Vam Bar 5 107 342 a T"WH-rHyd Rein Prod Pio 9,016 5,379 XO 9-1/2 9.21-80 TC1Pin a 3 V2 New Vern Boa 01 342"9.2 L-80 TC-1Puo Joint wi Collar 3-17921-110 IC-I'Mina 3-vr 9.;L-110 TC-11PupJoint vil Cofer HEszet-X-Figalee3-1/270119oesPin 3-V2'121410 TC-1 Pup Joint et Colas 3-1/2"9.3 ppf L-80 TC-IlTubing 3-W9.21-80 TC-1 Tubing Locator Collar 5-18i3.41 Sono w Index Muleshoe 11,269 6,173 Endo/ 11276 6.173 8 WET PBRIle Book Sleove151t 11,283 8,174 TOC Estimated 7 WFT VW Unit Tool% 11299 8,175 500'above top of 8+4E7"Ptir Rotating Hyd Set Liner Hanger 71,302 6,175 9 4-1/2"12.881-60 IBT-M Slotted Liner el torque rings Kuparuk 10 WFT Eccentric Solid Ai=Shoe 14,516 6251 Endo/Assembly 14,511 6,251 Perforated Intervals(MD ft): 13490—13520 14060—14090 \IL," 13520—13550 14125—14155 - ••• 13650—13680 14270—14300 7"26 ppf L-81 4 ... ...... . 13695—13725 14320—14350 BTC-Mod ' -,.... . -..... . .1 '.1.1_LA. Hydril 511 . ,"- ..--. ■ ., -...._.,.......... ... "1 Intermediate 2 "". "" ,-.;••• . ....,:-- Casing .. @ 11428'MD/ ...... 6182'TVD 4-1/2" 12.6#/ft L- 33333-7 6-1/8" Hole TD at 80 IBT-Mod at 14,513'MD/ Slotted Liner 6,251'ND w/Torque Rings DATA SUBMITTAL COMPLIANCE REPORT 9/11/2012 Permit to Drill 2091460 Well Name /No. OOOGURUK KUP ODSK -13 Operator PIONEER NATURAL RESOURCES AL API No. 50- 703 - 20607 -00 -00 MD 14513 TVD 6251 Completion Date 10/7/2011 Completion Status 1 -OIL Current Status 1 -OIL UIC N .. REQUIRED INFORMATION Mud Log No Samples No Directional Sury Yes ---- DATA INFORMATION Types Electric or Other Logs Run: MWD, LWD, GR, DIR, GABI, RES, DGR, DDS, EWR, PWD, ABI, AL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr 0 Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments Log / Induction /Resistivity 2 Col 223 14513 Open 11/18/2011 MD ROP DGR EWR ALD — L & R Quads CTN ADR Log v Induction /Resistivity 5 Col 223 14513 Open 11/18/2011 MD ROP DGR EWR ALD I —L &RQuadsCTNADR Log i- Induction /Resistivity 5 Col 223 6251 Open 11/18/2011 TVD DGR EWR ALD — L & R Quads CTN ADR Log / Induction /Resistivity 2 Col 223 6251 Open 11/18/2011 TVD DGR EWR ALD — L & R Quads CTN ADR Log t y Induction /Resistivity 5 Col 223 14513 Open 11/18/2011 MD ROP DGR EWR ALD CTN ADR Horizontal Presentation Log ,./ Induction /Resistivity 2 Col 223 14513 Open 11/18/2011 MD ROP DGR EWR ALD CTN ADR Horizontal Presentation Log U- Induction /Resistivity 2 Col 223 6251 Open 11/18/2011 TVD DGR EWR ALD CTN ADR Log if Induction /Resistivity 5 Col 223 6251 Open 11/18/2011 TVD DGR EWR ALD CTN III ADR Log,. Induction /Resistivity 2 Col 158 9224 Open 11/18/2011 MD PB1 ROP DGR EWR Log ./ Induction /Resistivity 5 Col 158 9224 Open 11/18/2011 MD PB1 ROP DGR EWR Log L. Induction /Resistivity 2 Col 158 5569 Open 11/18/2011 TVD PB1 DGR EWR Log k--' Induction /Resistivity 5 Col 158 5569 Open 11/18/2011 TVD PB1 DGR EWR Log �/ Induction /Resistivity 5 Col 223 11187 Open 11/18/2011 MD PB2 ROP DGR EWR ALD CTN Repeat Section ' Log i/ Sonic 5 Col 223 11187 Open 11/18/2011 MD PB2 BAT DGR EWR —Phase 4 ALD CTN Log t/ Sonic 2 Col 223 11187 Open 11/18/2011 MD PB2 BAT DGR EWR —Phase 4 ALD CTN DATA SUBMITTAL COMPLIANCE REPORT 9/11/2012 Permit to Drill 2091460 Well Name /No. 000GURUK KUP ODSK -13 Operator PIONEER NATURAL RESOURCES AL API No. 50 703 - 20607 - 00 - 00 MD 14513 TVD 6251 Completion Date 10/7/2011 Completion Status 1 -OIL Current Status 1 -OIL UIC N Log :/ Induction /Resistivity 2 CoI 223 11187 Open 11/18/2011 MD PB2 ROP DGR EWR ALD CTN Repeat Section Log t _. Induction /Resistivity 5 Col 223 6594 Open 11/18/2011 TVD PB2 DGR EWR Log — Sonic 5 Col 223 6594 Open 11/18/2011 TVD PB2 BAT DGR EWR –Phase 4 ALD CTN Log Induction /Resistivity 2 Col 223 6594 Open 11/18/2011 TVD PB2 DGR EWR CTN Repeat Section Log Sonic 2 Col 223 6594 Open 11/18/2011 TVD PB2 BAT DGR • EWR –Phase 4 ALD CTN ED Lc Las 14946 Induction /Resistivity 100 14514 Open 11/18/2011 Final, PB1& PB2 BAT, DGR, EWR – Phase 4, ALD, CTN & ROP, ADR plus TIFF, PDF EMF and CGM graphics ED C Las 14960 Report: Final Well R 0 14514 Open 12/8/2011 Final Well Report + Graphics adi, pdf, emf Rpt Report: Final Well R 0 20550 Open 12/8/2011 Final Well Report Log v Mud Log 2 Col 3525 14513 Open 12/8/2011 MD Fm Eval Log Log,/ Mud Log 5 Col 3525 14513 Open 12/8/2011 MD Fm Eval Log Log ' Mud Log 2 Col 3525 9224 Open 12/8/2011 MD PB 1 Fm Eval Log Log ✓ Mud Log 5 Col 3525 9224 Open 12/8/2011 MD PB 1 Fm Eval Log Log j/ Mud Log 2 Col 3525 11187 Open 12/8/2011 MD PB 2 Fm Eval Log Log ✓ Mud Log 5 Col 3525 11187 Open 12/8/2011 MD PB 2 Fm Eval Log • Log V Mud Log 2 Col 3525 14513 Open 12/8/2011 MD Drilling Evaluation Log Log 1../ Mud Log 2 Col 3525 9224 Open 12/8/2011 MD PB 1 Drilling Evaluation Log I Log 4/ Mud Log 2 Col 3525 11187 Open 12/8/2011 MD PB 2 Drilling Evaluation Log Log, Mud Log Col 3525 14513 Open 12/8/2011 MD Gas Ratio Log Log Mud Log 2 Col 3525 9224 Open 12/8/2011 MD PB 1 Gas Ratio Log Log V Mud Log 2 CoI 3525 11187 Open 12/8/2011 MD PB 2 Gas Ratio Log Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 9/11/2012 Permit to Drill 2091460 Well Name /No. 000GURUK KUP ODSK -13 Operator PIONEER NATURAL RESOURCES AL API No. 50- 703 - 20607 -00 -00 MD 14513 TVD 6251 Completion Date 10/7/2011 Completion Status 1 -OIL Current Status 1 -OIL UIC N 1 Cuttings' i 3600 14513 11/8/2011 1265 No samples were collected between 9,100' and (�/ 11,500' Cuttings 3545 9224 11/8/2011 1265 PB 1 Cuttings ✓ 9100 11187 11/8/2011 1265 PB 2 ADDITIONAL INFORMATION Well Cored? Y / N Daily History Received? Y / N Chips Received? Y / N Formation Tops Y / N Analysis Y / N • Received? Comments: (� J� f �_ ^� Z , i � C ( L - 7 4,1 S 1)pc:‘^i in r3 e, ‘..-i.jJ I�- Vtl "a- ' ! , /vv ," Compliance Reviewed By: A.C'--- Date: I 1 i. N i 1 _ • , - • • ri L __ u _, :‘ /SEANPARNELLGOVERNOR _ i ' ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM1IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Judy Golding Wellwork Engineer I t `_ Pioneer Natural Resources Alaska, Inc. c a©q `t" 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Kuparuk Oil Pool, ODSK -13 Sundry Number: 312 -043 Dear Ms. Golding: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holid. or weekend. S 0 f oe/. N orman om , i - ioner DATED this / day of February, 2012. Encl. C(?%'. 9* 1 f STATE OF ALASKA RECEIVED r` ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS JAN 0 2012 20 AAC 25.280 1 � 1 � 1. Type of Request: Abandon ❑ Plug or Redrill ye p Cow g LJ g ❑ Perfor New Pool ❑ �R pair Well � .. 'C fian a roved Pr ram Suspend ❑ Plug Perforations ❑ Perforate Er Pull Tubing ❑ ime extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ p -i Stimulate iff Alter Casing ❑ Other: Patch Tubing & Establish Flow Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resourcs Alaska, Inc. Development p Exploratory ❑ 209 - 146 , 3. Address: 700 G Street, Suite 600 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99501 50 703 - 20607 - 00 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes III No 0 ODSK -13 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 355036 / ADL 389958' Oooguruk - Kuparuk Oil Pool, 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14,513' ' 6251' , 14,495' 6250' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3475' 11 -3/4" 3513' 2949' 5830 psi 3180 psi Intermediate 1 5816' 9 -5/8" 3282' - 9098' 2847 - 5423' 5750 psi 3090 psi Tie -Back 2478' 7" 6482' - 8960' 4223' - 5349' 7240 psi 5410 psi Intermediate 2 11,389' 7" 11,428' 6182' 7240 psi 5410 psi Liner 3241' 4 -1/2" 11,270' - 14,511' 6173' - 6251' N/A N/A Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment, pg. 2 See Attachment, pg. 2 3 -1/2 ", 9.2# L -80, TCII 11,276' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Tubing Rtry ScSSSV; Hyd II Pkr 1997 MD/1921' TVD; 9016' MD/5379' TVD 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development El • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 2/10/2012 Commencing Operations: Oil 0 - Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tim Crumrine, 343 -2184 Printed Name Judy Golding Title Wellwork Engineer Signature ,hone 343 -2179 Date 1/27/2012 Prepared By: Kathy Campoamor, 343-2183 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 2 01 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: / / / APPROVED BY Approved by: 011irlor- • SSIONER THE COMMISSION Date: p../... /1■ 4 1° vF 4 /tt 210t J Sl '2_. 0R1G1NAL Submit in Duplicate i t Pioneer Natur�'I Resources Alaska Inc. ODSK -13 Tubing Patch /Establish Flow Page 2 AOGCC Form 10 -403, Application For Sundry Approvals Present Well Condition Summary — Box #11 Attachment Perforation Depth 11. Perforation Depth 4W, 12.6 #, L -80 IBT -M Slotted Liner : MD TVD 11,306' —11, 763' 6175' — 6198' 11,963' — 14,495' 6203' — 6250' Blank Pipe Interval : MD TVD 11,763' — 11,963' 6198' — 6203' • PI5NEER NATURAL RESOURCES ALASKA ODSK -13 Proposed Workover Summary Tubing Patch and Establish Flow with CTU: 1 1. RIH with Venturi junk basket on coil tubing and collect sample in the slotted liner. . 2. Run jet swirl nozzle and jet liner with sea water to attempt to induce flow. Nitrogen lift well to establish flow. If flow is established flow well for 2 days with CT and nitrogen. Skip to Step 6. , 3. If unable to establish flow jet line with 1000 gal of 7.5% DAD acid: Nitrogen lift well to establish flow. If flow is established flow well for 2 days with CT and nitrogen. Skip to Step 6. 4. If well will still not flow it will be necessary to perforate 1,500' of the existing slotted liner. 5. After perforating nitrogen lift the well to establish flow (if Step 4). Flow well with nitrogen as needed, for 2 days prior to shutting in well. 6. Run a leak detect log to determine collar depth of known tubing leak (Interval is 6,900' — 7,200'). 7. Set reducer nipple in 3.5" X- nipple at 9,063' for 2 -3/8" X -plug. 8. Set tubing patch across the leak determined in Step 6. 9. Set 2 -3/8" X -plug in nipple reducer and pressure test tubing. 10. Pull plug and put well on production with gas lift. ODSK -13 AOGCC Form 10 -403 January 27, 2012 STATE OF ALASKA % A L�P OIL AND GAS CONSERVATION COMMON REPaRT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other Ei Gas Lift Completion Performed: Alter Casing ❑ Pull Tubins0 Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Pioneer Natural Resources Alaska Inc Development Q Exploratory ❑ 209 -146 3. Address: 700 G Street, Suite 600 Stratigraphic❑ Service ❑ 6. API Number: ■.+ Anchorage, AK 99501 50- 703 - 20607 -00 -00 7. Property Designation (Lease Number): , 8. Well Name and Number: ADL 355036 / ADL 389958 •• ODSK -13 9. Field /Pool(s): Oooguruk - Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 14,513 feet Plugs measured N/A feet true vertical 6251 feet Junk measured N/A feet Effective Depth measured 14,495 feet Packer measured See Below feet true vertical 6250 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3475' 11 -3/4" 3513' 2949' 5830 psi 3180 psi Intermediate) 5816' 9 -5/8" 3282' - 9098' 2847' - 5423' 5750 psi 3090 psi Tie -Back 2478' 7" 6482' - 8960' 4223' - 5349' 7240 psi 5410 psi Intermediate2 11,389' 7" 11,428' 6182' 7240 psi 5410 psi Liner 3241' 4 -1/2" 11,270' - 14,511' 6173' - 6251' N/A N/A Perforation depth Measured depth See Attachment, pg 2 feet True Vertical depth See Attachment, pg 2 feet Tubing (size, grade, measured and true vertical depth) 3 -1/2 ", 9.2# L -80, TCII 11,276' MD 6173' TVD Packers and SSSV (type, measured and true vertical depth) TRScsssv @ 1997' Hyd Retr Prod Pkr @ MD / 1921' TVD 9016' MD/5379' TVD RECEIVED 11. Stimulation or cement squeeze summary: Intervals treated (measured): [ a1z Treatment descriptions including volumes used and final pressure: \i.�s ;a Oil & Gas Cons. Commissiofi iv TIC; 'rr 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -389 Contact Rib Tirpack, 343 -2121 Prepared By: Kathy Campoamor, 343 -2183 Printed Name Rob Tirpack Title Drilling Superintendent Signature i j iie /i „ for ! � / ,,,, Phone 343 -2121 Date 1/27/2012 r Form 10 -404 Revised 10/ f 8DmS+ JAN 3 1 1012 71 A s, 0.— Su... it Original Only / y�rl Pioneer N ral Resources Alaska Inc. ODSK -13 Gas Lift Completion Page 2 AOGCC Form 10 -404, Report of Sundry Well Operations Present Well Condition Summary — Box #10 Attachment Perforation Depth 10. Perforation Depth 4 -W, 12.6 #, L -80 IBT -M Slotted Liner : MD TVD 11,306' — 11,763' 6175' — 6198' 11,963' — 14,495' 6203' — 6250' Blank Pipe Interval : MD TVD 11,763' —11, 963' 6198' — 6203' P I 0 N E E R •perations Summary Report - Sta Well Name: ODSK -13 NATURAL RESOURCES Well Name: ODSK -13 Contractor: NABORS DRILLING Rig Number: 19AC Job Category: WORKOVER Start Date: 1/3/2012 End Date: 1/14/2012 Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud pb /gal) Summary 1/5/2012 1/6/2012 14,513.0 11.00 Spot and level rig over ODSK -13. RU all exits, stairways and handrails. Lay spill containment where needed. Take on Brine to rig pits. Check tubing IA and OA, both at 0 psi. Install BPV, ND Tree, install test dart, begin to NU BOPE and secure same. AOGCC Notified of BOPE test 1/4/2012 08:00 hrs. AOGCC Inspector Chuck Scheve waived BOPE test on 1/5/2012 @ 23:45 hrs. 1/6/2012 1/7/2012 14,513.0 11.10 Continue to NU BOPE. RU testing equipment and test BOPE w/ 2 7/8" & 4" test joint as per AOGCC PTD. -Test upper and lower variable rams to 250 psi low and 4500 psi high. -Test lower IBOP valves to 250 psi low and 4500 psi high. -Test annular w/ 2 7/8" test joint to 250 psi low and 2500 psi high. -Test all floor valves to 250 psi low and 4500 psi high. f t' -Test 14 choke manifold valves to 250 psi low and 4500 psi high. �/ -RD testing equipment. -All tests charted and all test held for 5 min. -Test witness waived by AOGCC rep Chuck Scheve at 23:45 hrs on 1/5/2012. - Initial system psi. 3000; 2050 after closure, 200 psi= 27 sec, full pressure 1 min 41 sec. - Release packer, displace diesel in IA to Ops flow back tanks. - Circulate 11.1 ppg Brine surface to surface. -Begin POOH with 3 1/2" completion string. 1/7/2012 1/8/2012 14,513.0 11.00 POOH with 3 1/2" completion liner f19,716'. LD SSSV, GLM, Baker packer and ESP, spooling ESP cable. Recovered all line clamps, Tec -Wire, and ESP Cable. RD ESP line spooling equipment. 1/8/2012 1/9/2012 14,513.0 11.00 MU Polish mill BHA and TIH picking up singles t/11,270'. Work polish mill f/11 270' 011.282' gsr WFT rep. Pump 25 bbl sweep and 3X BU. Displace well with fresh 11.0 ppg Brine. TOOH standing back 4" drill pipe f/11,270' t17,771' while monitoring hole for correct displacement. 1/9/2012 1/10/2012 14,513.0 11.00 TOOH and LD Polish Mill BHA. RU 3.5" handling equipment and RIH w/ 3.5 ", 9.2 #, L -80, TC -Il tubing f/ surface t/10,244'. 1/10/2012 1/11/2012 14,513.0 11.00 Continue RIH w/ 3.5" Tubing. Top of Liner © 11,270'. Sting in 011,276'. Space out PU pup joints. PU Hanger and Landing joint. Feed control line through hanger and spliced back to spool. Circ and Condition, Spotting 30bbls of Corrosion Inhibitor between packer and lower GLM. Land Hanger in WH and Ratcheting Muleshoe in 4 1/2" Tie back sleeve. Test Hanger seals to 5000psi. Set Packer w/ 3500psi. Observed 500psi pressure loss in Tubing and 200psi increase in IA in 15 mins. Repeat process w/ same results. Bled tubing t/ 1500psi and Pressured up IA t/ 2750psi. After 1 hr IA lost 300psi while Tubing pressure increased t/ 2275psi. RU Slickline Unit. MU Lubricator, BOPS, and Pump in Sub. 1/11/2012 1/12/2012 14,513.0 11.00 Finished RU Slickline Lubricator, BOP and Pump in Sub. RIH, latched Ball /Rod and pulled up 200'. Flushed w/ 2bbls and reseated. Pressure test Tubing with 100psi drop in 5mins, IA increased to 250psi. POOH with Ball /Rod. Retrieve RHC -M plug. Set PXX plug in upper X Nipple, Pressured tubing to 3500psi and Observed 450psi drop in 15mins, IA increased 200psi. POOH w /PXX Prong. Retrieve and Replace Shear Valve with Dummy Valve in upper GLM, Pressure Test IA to 3500psi w/ 150psi drop in 15mins. Retrieve Dummy Valve in Lower GLM. RIH w/ New Dummy Valve to set in GLM #2. 1/12/2012 1/13/2012 14,513.0 11.00 Continue to RIH w/ Dummy Valve and Set in GLM #1 @ 8,901'. Pressure test IA to 3500psi and lost 150psi in 10mins, POOH. MU an RIH w/ D &D hole finder tool, Tests below and above GLM ? #1 failed. POOH t/5,300' and tested tubing to 900psi, w/ 100psi loss in 15mins. Verify Surface Equipment Test - Unable to achieve good test. Isolate IA to Hot oil truck and Tubing to rig pump and tested each independently to 3500psi = Good Test. Pressure Tested IA to 3500psi and lost 300psi in 25 mins. Pressure test tubing above D &D hole finder © 5,270' w/ 900psi for 30mins = ,rof ood Test. POOH w/ Hole finder and Redress same. RIH w/ hole finder t/8,915' and could not tool to set. Page 1/2 Report Printed: 1/27/2012 n I O N E E n ci perations Summary Report - Ste* Well Name: ODSK -13 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (MKS) (ft) Mud (Ib/gal) Summary 1/13/2012 1/14/2012 14,513.0 11.00 Continue testing out of hole w/ D &D hole finder on slickline t/6,942' and achieved good tubing test. Test @ 7,262',failed indicating Connection leak between 6,942' and 7,262'. POOH w/ D &D hole finder and LD same. PU PX prong and RIH and attempt to set in X nipple © 8,935', POOH and still had PX prong. Redress and make 2nd RIH and set Prong successfully. POOH w/ slickline. RU and Pressure test tubing to 2000psi and IA to 500psi, observed pressure migrate from tubing to IA for 15mins. Pressure test IA to 2000psi and tubing to 500psi, observed pressure migrate from IA to tubing. Pressure both IA and Tbg to 3500psi, observed no leakage for 30mins. Shut in SSSV and bleed tubing above to Opsi. Monitor IA and Tubing pressure for 30mins = Good Test. Open SSSV and Bleed off all pressure. RD Slickline. ND BOPE. NU Tree, install test dart and BPV. Test Tree to 5000psi for 10mins. Function and Pressure test SSSV to 5000psi and leave open w/ 3000psi. RD all lines in HUTZ and PUTZ. Clean Well Bay. Well Secure - Rig Released @ 23:59hrs on 1/13/12. Page 2/2 Report Printed: 1/27/2012 0 0 ODSK -13 Kuparuk Production Well - RWO Completion Casing Item • Item MD (ft) TVO (ft) A 16" Conductor 158 158 B 11 -314" 60# L -80 Hydril 521,10.772" ID 3,513 2,349 C 9 -518" 40# L -80 Hydril 521, 8.835" ID' 9,098 5,423 Well Head: 11 - 3/4 ", 5K, VetcoGray D 7" 26* L - 80 BTC - M, 6.276" ID Tie - Back 8.961 5,350 Tree: 3 5K, Horizontal E 7" 26# L -80 Hydril 511, 6.276" ID Liner 11,428 6,182 F 4 -112" 12.6# IBT -M Slotted 3.958" ID wl torque rings 14,511 6,251 3 G 3 -112" 9.2# L -80 TCII 11,276 6,173 O 1 VetcoGray Tbg Hanger wf3.725 MCA Box H 3 -1f2 TC -II B. 34 34 3 -112" 9.2# L -80 TC -II Pup Joint Pin x Pin 3 XO w13-112 IBT Box x 3 -112 TC -II Pin 3 -112" 9.2 L -80 TC -II Tubing 3 -112" 9.2 L -80 TC -II Pup Joint wl Collar O Wellstar TRSV w 3 -112 9.2 TCII Box H Pin 9 Chr w 2.813 2 "X" Profile w 114 x .049 SS Control Line 1,937 1,921 3 -112" 9.2 L -80 TC -II Pup Joint wl Collar 41P 3 -112" 9.2 L -80 TC -II Tubing 3 -112" 9.2 L -80 TC -ll Pup Joint wf Collar 0- 3 GLM #1- Vanoil 3 -112" x 1 -112" w 3 -112" TCII Box w Pin 3,496 2,942 O 3 -112" 9.2 L -80 TC -II Pup Joint w? Collar 3 -112" 9.2 L -80 TC -II Tubing 3 -112" 9.2 L -80 TC -II Pup Joint wf Collar 4 GLM #2 - Vanoil 3 -112" x 1 - 112" w 3 - 112" TCII Box w Pin 8,884 5,309 3 -112" 9.2 L -80 TC -II Pup Joint w/ Collar 3 -112" 9.2 L -80 TC -II Tubing 3 -112" 9.2 L -80 TCII Pup Joint wl Collar HES 2.813 "X" Nipple w 3- 112 9.2 TCII Box x Pin 3 -112" 9.2 L -80 TC -II Pup Joint wl Collar TD ,...__./ , - j 3 - 112" 9.2 L - 80 TC - II Tubing 8 Qp 3-1/2" 9.2 L-80 TC -II Pup Joint wl Collar l XO 3 -112 L -80 w TCII Box w New Vam Box 5 WFT 3 -112 x 7" "W H -6" Hyd Retry Prod Pkr 3,016 5,379 XO 3 -112 9.2 L -80 TCII Pin x 3112 New Vam Box © &I. 3 -112" 9.2 L -80 TC -II Pup Joint w1 Collar Al 3 -112" 9.2 L -80 TC -II Tubing 3 -112" 9.2 L -80 TC -II Pup Joint wl Collar HES 2.813 "X" Nipple w 3 -112 TCII Box H Pin . 3 -1f2" 9.2 L -80 TC -II Pup Joint wl Collar 3 -112" 9.2 L -80 TC -II Tubing O ® Locator Collar 5" 18# Seal Stem w Index Muleshoe 11,263 6,173 Endo f, sswn,6 v 11,276 6,173 Lover Completion . - Item I Item MD (ft) TVD (ft) 6 WFT PBR Tie Back Sleeve 15ft 11,283 6,174 7 WFT "NTH" Liner Top Pkr 11,233 6,175 1 O 8 WFT "PHR" Rotating Hyd Set Liner Hanger 11,302 6,175 9 4 -1f2" 12.6# L -80 IBT -M Slotted Liner w 1 torque rings / 10 WFT Eccentric Solid Alum Shoe 14,510 u � 6,251 O v En�ff7 s�m k. d 14,511 6,251 • e L1 � All O O 10 e O n 10 N E E R Date: Revision By: Comments ODSK -13 Producer 01/27/12 KLC Post RWO Well Schematic AOGCC Copy NATURAL RESOURCES AIASC • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, January 12, 2012 9:49 PM To: Crumrine, Tim Subject: Re: Pioneer ODSK -13 Workover (PTD 209 -146) Tim, ,. A pressure loss of 200 psi is less than 10 % but sounds like it wasn't stabilizing to meet passing criteria. Doing a CMIT is prudent and would establish competent casing and packer. You would always have the option to fix the leak with a patch ( clearance allowing) later. Regards, - Guy Sent from my iPhone On Jan 12, 2012, at 7:57 PM, "Crumrine, Tim" <Tim.Crumrine @pxd.com> wrote: > Guy, > We have identified a leak in our production tubing during testing the packer on K -13. The leak has been isolated to a connection, and is losing about 200 psi in 30 minutes. Do we have the option to combo test the tubing and IA to prove mechanical integrity of the 7" casing, and move off of the well? The plan for the well is to conduct CT operations to chemically treat formation damage and clean out the wellbore, then move the rig back on in the near future to swap to an ESP. > Tim Crumrine > (907) 240 -4295 > > Statement of Confidentiality: > This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 1 Page l of l Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, January 03, 2012 4:58 PM To: 'Peltier, Brandon' Subject: RE: Sundry 311 -389, ODSK -13 RWO Brandon, Thanks for the update on the change to the procedure. Sounds like a good call to reduce the risk of damage to the casing. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Peltier, Brandon [ mailto:Brandon.Peltier @pxd.com] Sent: Tuesday, January 03, 2012 4:22 PM To: Schwartz, Guy L (DOA) Subject: Sundry 311 -389, ODSK -13 RWO Guy I wanted to notify you of a change to the pre -rig work on ODSK -13. Step 4, which was to tubing punch below the packer was not done. Instead we pulled the DV (GLM @ 2728') from below the packer to vent gas which may be present. This operation reduced the risk of damaging the 7" casing. Let me know if you need more information. Thank you. Brandon Peltier Pioneer Natural Resources Alaska, Inc Staff Drilling Engineer 907 - 343 -2116 (office) 907 - 229 -7545 (Mobile) brandon.peltier @pxd.com Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 1/3/2012 • • • 3 =' b : q / / SEANPARNELLGOVERNOR ITU ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Brandon Peltier Staff Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 ao -I Anchorage, AK 99501 Re: Oooguruk Field, Kuparuk Oil Pool, ODSK -13 Sundry Number: 311 -389 Dear Mr. Peltier: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4 e ) " Daniel T. Seamount, Jr. Chair DATED this 2Z' day of December, 2011. Encl. 411 1111 2 .69-/Y4. ODSK -13 Background and Rig Work -over Summary: 37,6-, 311- .3 k / The K -13 well has failed to produce hydrocarbon after being drilled and completed on 10/7/2011. Since completion, post rig work has included: • Expro flow back using ESP with no oil rate. The ESP was appeared to be working properly. • Extended slick -line fishing job and preparation for gas lifted flow back (10/13/11 to 11/18/11) • Expro flow back using gas lift with no oil rate Additionally, fluid and solids samples produced during flow back have indicated a significant amount of asphaltines present, which may be an indicator for wellbore to reservoir contamination. The RWO scope summary: • Swap the ESP completion with a 3.5" gas lift and coil tubing accessible completion • Conduct a coil tubing clean-out of the lateral o Conduct well diagnostics as necessary o Produce or flow back the well as necessary • Swap the 3.5" gas lift completion with an ESP completion at a later date as determined by the clean-out results and the rig schedule. 133r4-►^ia'. Ln " (2- vic-e-t- 474 `'‘j " / 4.-7 -p, re- r • �d -� 7 0 IqP i ‘ d i ALASKA u 0 0 ,is *RECEIVED) d ' ATE OF \\1/ y ni c g 3 .2111, ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 A�t�k.a ail & Cas irpilS• Cot�amissi0ri< 1. Type of Request: Abandon ❑ Plug for Redrill El Perforate New Pool ❑ Repair Well ❑ Chang�w ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing 0 f SP -94 Time Extensior n E] � � f F Operations Shutdown ❑ Re -enter Susp. Well El Stimulate El Alter Casing ❑ Other: Re-run Upper ompletion 0 - 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resourcs Alaska, Inc. Development p - Exploratory ❑ 209 -146 . 3. Address: 700 G Street, Suite 600 Stratigraphic ❑ Service 0 6. API Number: Anchorage, AK 99501 50- 703 - 20607 -00 -00 ` 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 ODSK - 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 355036 / ADL 389958 Oooguruk - Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14,513' . 6251' 14,495' 6250' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3475' 11 -3/4" 3513' 2949' 5830 psi 3180 psi Intermediate 1 5816' 9 -5/8" 3282' - 9098' 2847' - 5423' 5750 psi 3090 psi Tie -Back 2478' 7" 6482' - 8960' 4223' - 5349' 7240 psi 5410 psi Intermediate 2 11,389' 7" 11,428' 6182' 7240 psi 5410 psi Liner 3241' 4 -1/2" 11,270' - 14,511' 6173' - 6251' N/A N/A Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment, pg. 2 See Attachment, pg. 2 3 -1/2 ", 9.3# L -80, IBT -M 10,043' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Tubing Rtry ScSSSV; Hyd II Pkr 1994' MD/1918' TVD; 2675' MD/2484' TVD 12. Attachments: Description Summary of Proposal el 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 12/26/2011 Commencing Operations: Oil Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brandon Peltier, 343 -2116 Printed Name Brandon Peltier Title Staff Drilling Engineer Signature 343 -2116 Date 12/16/2011 Prepared By: Kathy Campoamor, 343-2183 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ! ( ' J 9 Plug Integrity ❑ BOP Test e Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3 P$" /3 i f 4z. 2 SUO pSc- 4fr1n w ith 4- 6 +14: 4 Subsequent Form Required: / 9 L/6 0 ' APPROVED BY % Approved by i COMMISSIONER THE COMMISSION Date: /2 / 2 L I 1 / Form 10 -403 Revis : t • DEC 2 2 20 Si, ;' Submi ' Duplicate j /yLo•l/ Ft ORIGINAL. %��% ►U r1 • • • Pioneer Natural Resources Alaska Inc. ODSK -13 Pull & Re -run Tubing Page 2 AOGCC Form 10 -403, Application For Sundry Approvals Present Well Condition Summary — Box #11 Attachment Perforation Depth 11. Perforation Depth 4 -W, 12.6 #, L -80 IBT -M Slotted Liner : MD TVD 11,306' — 11,763' 6175' — 6198' 11,963' — 14,495' 6203' — 6250' Blank Pipe Interval : MD TVD 11,763' — 11,963' 6198' — 6203' , • • • • ODSK -13 Proposed Rip Work -over Summary Well Status: Z Z /e 1. Well Information M A r o Drilling BHP: 3487 psi (10.72 ppg @ 6251' tvd) / it• ze• A o BHT: -155 F Pre Rig: 1. Perform pre -rig check -list tasks (grease valves and test voids). 2. Shut off gas lift support 1 -3 day prior to MIRU of Nabors 19AC. 3. Add a second swab valve for a -line and slick -line work. o Set and pull BPV as needed for this work _ 4. RU E/L and perforate 10' of the 3.5 ", 9.3# tubing using 4 SPF tubing punches just below the production packer at 2660' MDrkb. o Perform gauge ring run below perforation depth 5. Open PVV and vent gas from below packer into IA. Bleed IA and tubing as necessary. 6. RU S/L and pull OV from GLM at 2534' MDrkb. 77. Fluid pack IA, tubing, and PVV control line with 11.0 ppg Brine o Circulate annulus volume + tubing volume down to GLM at 2534' MDrkb at 2 -3 bpm. Record the pump pressure and WHP while pumping. Bullhead down the tubing as needed. A. Verify ScSSSV actuation, close and verify, monitor control line pressure. PT ScSSSV from below to 500 psi. r9. Freeze protect TxIA to 2000' with diesel (well may be underbalanced) 10. RU Slick -line and install DV in GLM at 2534' MDrkb. 11. MITIA to 3500 psi r 12. Pull DV from GLM at 2534' MDrkb. Rig down slick -line. 13. Monitor WHP and IAP via operator's daily reading schedule until rig moves on location, Prep surface equipment for rig move. Nabors 19AC Rig Operation: 1. MIRU Nabors 19AC. 2. Monitor TxIAxOA pressures 3. Ensure that the ScSSSV is open." 4. Bleed off pressure and bullhead 11.0 ppg Brine as needed. Monitor well and ensure static conditions. - 5. Install a BPV into the tubing hanger profile. Test from below to 500 psi 6. ND swab valves and NU BOP ✓ a. Barriers are (a minimum of 2): i. Tubing side 1. BPV in the tubing hanger 2. Closed ScSSSV ii. Annulus Page 1 of 3 PIONEER NATUaAI RESUUR(S ALASKA 4110 • • • 1. 2 independent seals in the tubing hanger (tested during MITIA and pre -rig) 2. Wellhead and horizontal tree 7. Test BOP's as per standard AOGCC requirements. With low (250 psi) and high (3500 psi) 5 minutes each. State will need to be notified to witness test.- - a. Have FOSV available and drifted to 2.25" minimum to ensure a -line cutting tools can pass through I.D. 8. Pull BPV from tubing hanger. a. If trapped pressure is observed below BPV, bullhead KWF 2x tubing volume down tubing 9. Pull to release packer a. Gas may be present below the packer, so be looking for a gas bubble once the packer is released. b. Note: If the packer does not pull to release, the contingency plan would be to jet cut cow the tubing above the packer, pull the tubing, then spear and pull the packer with 4" drill pipe. c. Circulate out diesel freeze protect after releasing packer. 10. Pull 3 -1/2" completion string out of the hole filling hole as needed. a. The Echometer is available through OPS to monitor fluid levels in the well as needed. t �nw b. Joint with FOSV should be in the mouse hole as a contingency. As 11. PU 4" DP and 2 -7/8" DP as needed for clean -out run if the well is not on losses. 7 - 12. PU & RIH 3.5 ", 9.3 ppf, L -80, TC -II tubing consisting of: a. WLEG b. X nipple w/ RHCM plug body pm) te t t ., c. X nipple one joint below packer d. Packer e. X nipple GLM per gas lift design (shear valve in upper mandrel) f. TRSSV 13. PU LJ w/ Production Tubing Hanger. 14. Land Tubing Hanger. RILDS for Tubing Hanger. Test both the upper and lower Tubing Hanger body seals to 5000psi. a. Spot corrosion inhibitor above packer 15. Drop ball and rod down tubing. a. Ensure the tubing is fluid packed prior to dropping the ball and rod. b. Monitor SCSSSV control line pressure to ensure adequate hold open pressure during ball drop 16. Pressure set the packer with 3500 psi. 17. Test tubing to 3500 psi for 30 minutes. 18. Pressure test IA to 3500 psi. a. Bleed tubing pressure to 1500psi and maintain less than 2500 pressure differential between TxIA to prevent shearing shear - valve. 19. Shear out shear -valve a. Reverse circulate 75 bbls of diesel and allow time for u -tube for TxIA freeze protect to 2000' TVD. /20. Install BPV with blanking plug and test from above and below. e1. ND BOPE a. Barriers are (a minimum of 2): Page 2 of 3 PICINEER NATURAL RESOURCES ALASKA • • • • iii. Tubing side 1. BPV in the tubing hanger 2. Closed ScSSSV iv. Annulus 1. Wellhead and tubing hanger with 2 independent seals 22. NU Vetco Swab valve and cap a. Test tree to 5000 psi. Post Rig: Pull BPV w/ blanking plug. 2. MIRU HES Slick -line a. Retrieve ball /rod assy from RHCM plug body b. Install valves in GLM per completion engineer 3. Rig down slickline 4. Function Test TRSSSV 5. Conduct coil tubing lateral clean -out as needed. Page 3 of 3 PIONEER NATURAL RE'.iOUR(,'ES ALASKA 0 . 4 • 1 ODSK -13 Ivik Fault Block Kuparuk Production Well E5° Casing Item # Item MD (ft) TVD (ft) A 16" Conductor 158 158 B 11 -3/4" 60# L -80 Hydril 521, 10.772" ID 3,513 2,949 C 9 -5/8" 40# L -80 Hydril 521, 8.835" ID* 9,098 5,423 Well Head: 11 -3/4 ", 5K, VetcoGray D 7" 26# L -80 BTC -M, 6.276" ID Tie -Back 8,961 5,350 Tree: 3 -1/2 ", 5K, Horizontal E 7" 26# L -80 Hydril 511, 6.276" ID Liner 11,428 6,182 F 4 -1/2" 12.6# IBT -M Slotted 3.958" ID w/ torque rings 14,511 6,251 0 G 3 - 1/2" 9 3# L -80 IBT -M x 2 -7/8" 6.4# IBT -M 10,043 5,881 O ' ` Upper Completion Item # Item MDrkb (ft) TVDrkb (ft) 0 1 VetcoGray Tubing Hanger 34 34 3 -1/2" 9.2# L -80 IBT -Mod Pup Joint Pin x Pin 3 -1/2" 9.2# L -80 IBT -Mod Tubing 0 3 -1/2" IBT -Mod Box x 2 -7/8" IBT -Mod Pin 2 2 -7/8" Wellstar Tubing Retreivable ScSSSV 1,994 1,918 2 -7/8" IBT -Mod Box x 3 -1/2" IBT -Mod Pin ■ '; 3 -1/2" 9.2# L -80 IBT -Mod Tubing O 3 -1/2" IBT -Mod Box x 2 -7/8" IBT -Mod Pin O B 3 GLM #1 - 2 -7/8" x 1 -1/2" w DCK Shear Valve 2234 2,379 $ 1 2 -7/8" 6.4# L -80 IBT -Mod Tubing ��- 4 2 -7/8" X Nipple 2.313" I.D. J 2 -7/8" 6.4# L -80 IBT -Mod Tubing 2,587 2,420 5 WFT 7" x 2 -7/8" Gas Vent Valve Packer 2,660 2,474 - 0 J 2 -7/8" 6.4# L -80 IBT -Mod Tubing D 6 GLM #2 - 2 -7/8" x 1 -1/2" (min. 1 jt below packer) 2,728 2,522 ■ 2 -7/8" IBT -Mod Box x 3 -1/2" IBT -Mod Pin 3 -1/2" 9.2# L -80 IBT -Mod Tubing • 0 ■ 3 -1/2" IBT -Mod Box x 2 -7/8" IBT -Mod Pin 0 7 GLM #3 - 2 -7/8" x 1 -1/2" (min. 2 jts above X nipple) 9,633 5,698 2 -7/8" 6.4# L -80 IBT -Mod Tubing 8 2 -7/8" X Nipple, 2.313" ID w/ RHC -M Plug Body 9,710 5,734 2 -7/8" 6.4# L -80 IBT -Mod Tubing 9 Automatic Divert Valve (ADV) 9,963 5,846 10 10 ESP (Pump, Motor, and Jewelry) 9,968 5,848 End of Assembly 10,043 5,881 Lower Completion Item # Item MD (ft) TVD (ft) 11 WFT PBR Tie Back Sleeve 15ft 11,283 6,174 12 WFT "NTH" Liner Top Pkr 11,299 6,175 13 WFT "PHR" Rotating Hyd Set Liner Hanger 11,302 6,175 14 4 -1/2" 12.6# L -80 IBT -M Slotted Liner w/ torque rings 15 WFT Eccentric Solid Alum Shoe 14,510 6,251 74 13 End of Assembly 14,511 6,251 1 O 74 15 E n 10 N E E R Date: Revision By: Comments ODSK -13 Producer Well Schematic AOGCC Copy NATURAL RESOURCES ALASKA • • • • ODSK -13 Ivik Fault Block Kuparuk Production Well — RWO Proposed Completion c L ;-c4— Casing Item # Item MD (ft) TVD (ft) Well Head: 11 -3/4 ", 5K, VetcoGray A 16" Conductor 158 158 Tree: 3 -1/2 ", 5K, Horizontal B 11 -3/4" 60# L -80 Hydril 521, 10.772" ID 3,513 2,949 C 9 -5/8" 40# L -80 Hydril 521, 8.835" ID * 9,098 5,423 D 7" 26# L -80 BTC -M, 6.276" ID Tie -Back 8,961 5,350 O Aill E 7" 26# L -80 Hydril 511, 6.276" ID Liner 11,428 6,182 F 4 -1/2" 12.6# IBT -M Slotted 3.958" ID w/ torque rings 14,511 6,251 0 G 3 -1/2" 9.3# L -80 IBT -M x 2 -7/8" 6.4# IBT -M 11,283 5,881 O Drkb (ft) TVDrkb (ft) 1 VetcoGray Tubing Hanger 34 3 -1/2" 9.2# L -80 Pup Joint Pin x Pin 3 -1/2" 9.2# L -80 TC -II Tubing 2 3 -1/2" Wellstar Tubing Retreivable ScSSSV -2000 Ilk 0 O 3 -1/2" 9.2# L -80 TC -II Tubing 3 GLM #1 - 3.5 ", shear eeINe -3500 3 -1/2" 9.2# L -80 TC -II Tubing 4 GLM #2 - 3.5 ", Dummy wloe -6000 3 -1/2" 9.2# L -80 TC -II Tubing 4 5 X Nipple 3.5" tbd I 3 -1/2" 9.2# L -80 TC -II Tubing 6 3.5x7" Packer tbd 3 -1/2" 9.2# L -80 TC -II Tubing 7 X Nipple 3.5" tbd O C 3 -1/2" 9.2# L -80 TC -Il Tubing 8 X- Nipple 3.5" tbd 3 -1/2" 9.2# L -80 TC -II Tubing 9 WLEG 11,283 3 End of Assembly 11,283 6,175 m. _ 11 WFT PBR Tie Back Sleeve 15ft 11,283 6,174 U 12 WFT "NTH" Liner Top Pkr 11,299 6,175 13 WFT "PHR" Rotating Hyd Set Liner Hanger 11,302 6,175 0 14 4 -1/2" 12.6# L -80 IBT -M Slotted Liner w/ torque rings 15 WFT Eccentric Solid Alum Shoe 14,510 6,251 End of Assembly 14,511 6,251 13 O■ 14 15 ED E P I O N E E R Date: Revision By: Comments ODSK -13 Producer 12/15/2011 BJP RWO Well Schematic AOGCC Copy NATURAL RESOURCES ALAS r • 2-0R -(4G t 4 CO PIONEER NATURAL RESOURCES ALASKA Letter of Transmittal Date: December 8, 2011 FROM TO Ron Smith AOGCC Pioneer Natural Resources Attn: Howard Okland 700 G Street, Suite 600 333 W. 7 Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps ❑ Report X Other — Logs, End of Well Report w /CD ❑ Agreement DETAIL QTY DESCRIPTION ODSK -13 (API:50- 703 - 20607 -0000) 1 End of Well Report w/ CD ODSK -13 PB1 (API:50- 703 - 20607 -7000) ODSK -13 PB2 (API:50- 703 - 20607 -7100) 12 Well Logs See Details Below We request that all data be treated as confidential information. Thank you. Received by: 6,44 Date: 42_A Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Ron Smith 700 G Street, Suite 600, Anchorage, AK 99501 907 -343 -2193 fax 907 -343 -4928 phone • +fr December 6, 2011 QTY DESCRIPTION 1 Report with CD ODSK - 13i Surface Data Logging End of Well Report w /CD ODSK -13 (API:50- 703 - 20607 -0000) Surface Data Logging - 2" MD Gas Ratio Log, CVE Gas Extraction (1:600) Surface Data Logging 2" MD Formation Evaluation Log, CVE Gas Extraction (1:600) Surface Data Logging 2" MD Drilling Engineering Log, CVE Gas Extraction (1:600) Surface Data Logging 5" MD Formation Evaluation Log, CVE Gas Extraction (1:240) 12 Well Logs ODSK -13 PB1 (API:50- 703 - 20607 -7000) Surface Data Logging - 2" MD Gas Ratio Log, CVE Gas Extraction (1:600) Surface Data Logging 2" MD Formation Evaluation Log, CVE Gas Extraction (1:600) Surface Data Logging 2" MD Drilling Engineering Log, CVE Gas Extraction (1:600) Surface Data Logging 5" MD Formation Evaluation Log, CVE Gas Extraction (1:240) ODSK -13 PB2 (API:50- 703 - 20607 -7100) Surface Data Logging - 2" MD Gas Ratio Log, CVE Gas Extraction (1:600) Surface Data Logging 2" MD Formation Evaluation Log, CVE Gas Extraction (1:600) Surface Data Logging 2" MD Drilling Engineering Log, CVE Gas Extraction (1:600) Surface Data Logging 5" MD Formation Evaluation Log, CVE Gas Extraction (1:240) • Page 2 jam -44 PIONEER — NATURAL RESOURCES ALASKA Letter of Transmittal Date: November 16, 2011 FROM TO Shannon Koh /Ron Smith AOGCC Pioneer Natural Resources Attn: Howard Okland 700 G Street, Suite 600 333 W. 7 Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps ❑ Report X Other - Logs, CDs ❑ Agreement DETAIL QTY DESCRIPTION ODSK -13 (API:50- 703 - 20607 -0000) 2 CDs ODSK -13 PB1 (API:50- 703 - 20607 -7000) ODSK -13 PB2 (API:50- 703 - 20607 -7100) 20 Well Logs See Details t ils Below We request that all data be treated as confidential information. Thank you. Received by: 17 -41t% Date: Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Ron Smith 700 G Street, Suite 600, Anchorage, AK 99501 907 - 343 -2193 fax 907 -343 -4928 phone November 16, 2011 QTY DESCRIPTION ODSK- 13 +PB1 +PB2 2 CDs LWD Final Processed Data (digital graphic logs, digital data) ODSK -13 PB2 Open -hole BAT Data (Wave forms LAS data) ODSK -13 (API:50- 703 - 20607 -0000) ROP, DGR, EWR, ALD, CTN, ADR (1:240, 1:600) MD ROP, DGR, EWR, ALD, CTN, ADR (1:240, 1:600) TVD ROP, DGR, EWR, ALD, CTN, ADR, Horizontal Presentation (1:240, 1:600) MD 20 Well Logs DGR, EWR, ALD, CTN, ADR (1:240, 1:600)TVD ODSK -13 PB1 (API:50- 703 - 20607 -7000) ROP, DGR, EWR (1:240, 1:600) MD DGR, EWR (1:240, 1:600) TVD ODSK -13 PB2 (API:50- 703 - 20607 -7100) BAT, DGR, EWR, ALD, CTN (1:240, 1:600) ND BAT, DGR, EWR, ALD, CTN (1:240, 1:600) MD ROP, DGR, EWR, ALD, CTN, Repeat Section (1:240, 1:600) MD ROP, DGR, EWR, ALD, CTN, Repeat Section (1:240, 1:600) TVD • Page 2 STATE OF ALASKA A,KA OIL AND GAS CONSERVATION COM ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: One Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Aband.: 10/7/2011 209 - 146 3. Address: 700 G Street, Suite 600 6. Date Spudded: 13. API Number: Anchorage, AK 99501 1/2/2010 50 703 - 20607 - 00 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2960' FSL, 1152' FEL, Sec. 11, T13N, R7E, UM 9/15/2011 ODSK - Top of Productive Horizon: 8. KB (ft above MSL): - 56.2' 15. Field /Pool(s): 5040' FSL, 87' FEL, Sec. 2, T13N, R7E, UM GL (ft above MSL): „ 13.5' Total Depth: 9. Plug Back Depth(MD +TVD): Oooguruk - Kuparuk 011 Pool 2176' FSL, 1987' FEL, Sec. 35, T14N, R7E, UM N/A 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x - 469845.81 y 6031076.06 Zone 14,513' MD / 6251' TVD ADL 355036 / ADL 389958 TPI: x 470934.64 y - 6038430.82 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x - 469042.68 y 6040854.02 Zone - Asp 4 1994' MD / 1918' TVD 417497 18. Directional Survey: Yes 0 No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 875' MD / 873' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re- drill /Lateral Top Window MD/TVD: Gyro, MWD/ LWD, GR, DIR, GABI, RES ,DGR,DDSr,DDS,EWR,PWD,ABI,ALD ,CTN,PCDC,ACAL,DM,SDR,PCG,BAT N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 109# H -40 Surface 158' Surface 158' 24" Driven 11 -3/4" 60# L-8 521YD Surface 3513' Surface 2949' 14 -1/2" 502 sx PF'L'; 260 sx Class 'G' 9 -5/8" 40# L $521YD 3282' 9098' 2847' 5423' 11 -3/4" 480 sx Class 'G' 7" 26# s M D, 8960' p 5349' 9-1/2" Tie-Back CC.�r,a A. 7" 26# L -80 Attrmr. 11,428 -Sucfaca 6182' 9 -1/2" 159 sx Class 'G' (...6,;, / Hyd -511 4 -1/2" 12.6# I B$M 11,270' 14,511' 6173' 6251' 6 -1/8" Uncemented 24. Open to production or injection? Yes U No Li If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and ,Number), SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) . u 1,','LE.1. V?+ i 3-1/2", 9.3#, Hyd II Pkr @ 2675' MD / 4 - 1/2 ", 12.6#, L - 80 IBT - M Slotted Liner: 1 0 ` i L - 80, IBT - M 10 2484' TVD MD TVD !26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11,306' - 11,763' 6175' - 6198' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 11,963' - 14,495' 6203' - 6250' °" -- __ , Blank Pipe Interval: MD TVD 11,763' - 11,963' 6198' - 6203' 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No IS If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. None R EI EL) RBDMS NOV 0 4 210 , Ii',' , ,' f'i .„1,,,,, ` ,ska OH & tip Coos. Commission Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE o Submit original only /$ • - /Z ' , , 2 G • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 12 No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top 841' 840' needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base 1716' 1668' Top West Sak 2442' 2305' Top Tuffaceous Shale 3377' 2890' None Top Torok Ss 8582' 5150' Base Torok Ss 9076' 5411' Top HRZ 10,104' 5907' Base HRZ 10,467' 6033' Kalubik 10,782' 6111' Top Kuparuk C 11,426' 6182' LCU 11,949' 6203' Formation at total depth: 14,513' 6251' 31. List of Attachments: Summary of Daily Drilling Operations, Well Schematic Diagram, Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Alex Vaughan, 343 - 2186 Printed Name: Alex Vau•han,,,. ' ! Title: Sr. Drilling Engineer Signature: Phone: 343 - 2186 Date: 10/31/2011 Well Name: ODSK -13 'ermit No.: 209 -146 _ Prepared By: Kathy Campoamor, 343 -2183 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection, Water Injection, Water - Altemating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 P I 0 N E E R •Operations Summary Report - Sta Well Name: ODSK -13 NATURAL RESOURCES Well Name: ODSK -13 Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: DEVELOPMENT DRILL Start Date: 12/31/2009 End Date: 1/8/2010 Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud (lb/gal) Summary 12/31/2009 1/1/2010 0.0 Move Rig from ODSK -42Ai to ODSK -13. Rig accepted 12/31/09 @ 00:00 hrs. 1/1/2010 1/2/2010 0.0 Move Pit/Pipeshed Complex from south side to north side of Wellbays. Installed MPD Pump Skid. Spotted Pit/Pipeshed Complex next to Substructure. Lower and /or install all EXIT route stairs. RU rig for Drilling operations. NU Drilling Adapter, Surface Drilling Riser and Air Boot Adapter. CIO pump liners f/ 5 -1/2" t/ 6 ". C/O Top Drive Upper and Lower IBOP's f/ 4" 11 5". 1/2/2010 1/3/2010 158.0 65.00 9.10 Change out Top Drive 4" IBOP and stabbing guide to 5 ". PU 105 jts 5" DP, 14 jts 5" HWDP, Drilling Jars and stand back in derrick. PU 14 -1/2" Conductor Clean -Out BHA, 14 -1/2" Security XT1C Bit (1x12 and 3x16 jets) - SperryDrill Motor (1.5 deg bend) - Float Sub - Stablizer - UBHO - XO = 48.8'. Clean out 16" Conductor f/55' 11158'. Drill f/158' t/233'. CBU. POOH 1/43'. PU BHA #1. 1/3/2010 1/4/2010 223.0 1,218.00 9.25 RU Gryo survey sheaves in denickand hang wireline. RU MGT on ODSN -35. RIH f/144' 11223'. Drill 14-1/2" new hole f/223' 1/1,441'; (RD Gryo at 918'). 1/4/2010 1/5/2010 1,441.0 1,284.00 9.20 Drill 14 -1/2" new hole f/1,441' 1/2,235'. Circulate and reciprocate DP (stood back 1 std DP every 1/2 hr 1/1,965'). Decision was made to perform wiper trip while repairing Hammer Mill. POOH f/1,965' 1/632'. RIH f/632' 112,156'. Ream down f/2,156' 112,235'. Drill 14 -1/2" new hole f/2,235' 1/2,725'. 1/5/2010 1/6/2010 2,725.0 800.00 9.30 Drill 14 -1/2" new hole f/2,725' 1/3,525'. Circulate 50 bbls Hi -Vis weighted sweep S/S and condition mud for wiper trip, (stood back 3 stands DP during circulation). POOH f/3,201' 11207'; worked tight areas at 1,659'; 1,617' and 1,520'. RIH f/207' 1/2,250'. 1/6/2010 1/7/2010 3,525.0 0.00 9.60 RIH f/2,250' 113,525'. Circulate and condition mud for 11 -3/4" casing. POOH w/ BHA #1 and LD same. Remove VG Spacer Spool and install VG Landing Ring. RU casing handling equipment. RIH w/ 85 jts 11 -3/4" 60# L -80 Hydril 521 Casing 1/3,470'. 1/7/2010 1/8/2010 3,525.0 0.00 9.40 MU 11 -3/4" Casin Han er and Landin Jt. Land 11 -3/4" Casing at 3,512.6'. MU Cement Head. Circulate and condition mud or cement operations. PJSM - Release 1st Bottom Cement Plug. 3 . Pump 10 bbls seawater. Test cement lines to 4000 psi. Pump 60 bbls 10.0 ppg Dual Spacer. Released 2nd Bottom Plug. Pump 371 bbls 10.9 ppg (502 sx 4.15 CuFt/Sk) Lead Permafrost .j( "L" @ 5 bpm/600 psi followed by 55.2 bbls 15.9 ppg (260.5 sx t 1.19 CuFUSk) Premium Class �" G' Cement w/ 2% Calcium Chloride and 2% CFR -3 @ 5 bpm /675 psi. Pump 1 bbl seawater, Drop Top Cement Plug, pump 20 bbls seawater. Swtiched to rig and displaced cement w/ 368.5 bbls seawater at 10 bpm w/ ICP of 1850 psi, FCP 2600 psi, bump plug w/ 3509 psi, held pressure 30 min. CIP @ 12:45 hrs. 100 bbls cement retums to surface. Bleed back 4 bbls seawater after pressure test, floats held. RD cementing and casing equipment. LD Landing Joint. ND Drilling Riser. NU Multibowl Wellhead. Freeze protect w/ 225 bbls diesel to 2,000'. Rig released from ODSK -13 on 01/07/10 @ 23:59 hrs. 1/8/2010 7/25/2011 3,525.0 0.00 9.40 Inactive 7/25/2011 7/26/2011 3,525.0 0.00 9.40 Prep rig for rig move from slot 11 to ODSK -13 and RU. RU lines to circulate out freeze protect diesel to the flow back tanks. Transfer 280 bbls of sea water into rig mud pits. Test IA to 1000 psi for 5 min - Good test. RD circulating lines. Install electrical covers on top drive while loading 5" DP in pipe shed. ND production tree and install test dart in tubing hanger. NU BOPE and drilling riser. Install IBOP, wear sub, bails on top drive, and service same. Install trip nipple and NU flow line. Page 1/13 Report Printed: 10/31/2011 P I 0 N E E R • ns Summary Report - Staa Well Name: ODSK -13 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud (IbNal) Summary 7/26/2011 7/27/2011 3,525.0 0.00 8.60 Install 2 -7/8" test joint, and pressure up Koomey. Seat new bladder in Koomey bottle to stop leak. RU test equipment and test BOPE w/ 2 -7/8" & 5" test joint. Test upper and lower variable rams to 250 psi low / 4500 psi high. Test upper and lower IBOP valves to 250 psi low / 4500 psi high. Test annular w/ 2 -7/8" & 5" test joint to 250 psi low / 2500 psi high.Test all floor valves to 250 psi low / 4500 psi high. Test 14 choke manifold valves to 250 psi low / 4500 psi high. All tests charted and all test held for 5 min. Test witness waived by AOGCC Rep. Chuck Scheve at 10:30 hrs 07/24/11. Initial system psi = 3000; 2000 after closure; 200 psi = 20 sec; full pressure 1 min 42 sec. RD test equipment. RU tubing tongs and handling equipment to pull 2 -7/8" tubing. V ck out LDS on well head and unseat hanger with 150k. Pull hanger to floor, LD landing joint, and hanger. POOH laying down 63 joints of 2 -7/8" tubing. RD 2 -7/8" tubing handling tools. ND BOPE and drilling riser - rack back same in cellar. ND Multi -bowl wellhead. Install drilling spool, NU BOPE, and riser. Install test plug in well head and install MPD test flange. Perform body test on BOP stack to 250 psi low / 4500 psi high. Test MPD equipment and lines to 250 psi low / 3500 psi high. All test held 5 min each on chart - Good test. RD testing equipment, pull test plug, and install trip nipple. RU Katch Kan spill containment and hoses on BOP stack. MU stack flushing tool and TIH f/ surface t/3,280'. 7/27/2011 7/28/2011 3,525.0 0.00 8.60 Perform DP management. RIH w/ 4" DP f/ derrick w/ 33 stands at time. POOH, LD same. Service rig. Change over f/ 4"1/ 5" handling equipment. RIH w/ 35 joints of 5" DP to ±1,030'. 7/28/2011 7/29/2011 3,525.0 8.60 Continue DP management: PU 5" DP (108 jts.) to ±3,380'. Circ DP volume. Circ to balance fluid. POOH stand back 5" DP. PU 108 jts, 5" DP f/ shed to ±3,380'. Circ 120 bbls at 750 gpm. POOH stand back 5" DP. PU cleanout BHA. PU 5" DP. Tag fill at 3,245'. Cut & slip drilling line. Pump 25 bbls H.V. spacer followed by 8.6 ppg LSND. Displace well f/ seawater to 8.6 ppg LSND. Tag F.C. at 3,427'. Drill F.C. and cement t/3,455'. 7/29/2011 7/30/2011 3,545.0 354.00 8 65 Continue drilling cement f/3,455' ±/3,512' (Float Shoe). Drill shoe and clean out rathole ±/3,525'. Drilling new formation f/3,525' 1/3,545'. Pull into 11 -3/4" shoe. CBU - MW in / out = 8.6 ppg. Perform Leakoff to 14.24 ppg. EMW. OMW= 8.6 ppg/ TVD = 2,949' / Leakoff pressure = 865 psi. (X Pump dry job. POOH. LD c assembly. PU RSS drilling assembly. RIH 1/3,422'. Pull trip nipple. Install RCD head. Wash to bottom at 3,545'. Drill 11 -3/4" new hole f/3,545' 1/3,611'. Drop 1 -5/8" ball to activate Rhino Reamer cutters. Pull test Rhino reamer against 11 -3/4" shoe w/ 10k overpull. Directional drill 11 -3/4" new hole f/3,611' 1/3,899'. 7/30/2011 7/31/2011 3,899.0 1,679.00 9.30 Directional drill 11 -3/4" hole f/3,899' 1/5,039'. Change RCD head. Directional drill 11 -3/4" hole f/5,039' 1/5,578'. 7/31/2011 8/1/2011 5,578.0 928.00 9.35 Directional drill 11 -3/4" hole f/5,578' 1/6,084'. Continue Directional drill 11 -3/4" hole f/6,084' U6,506'. Maintaining 11.5 ppg EMW using MPD. Work tight hole / packoff. Establish circulation w/ 1/2 bpm, 650 psi to 1 bpm, 750 psi f/6,506' 1/6,498'. POOH on elevators f/6,398' 1/5,858'. Backream f/5,858' 1/4,849' w/ 40-60 rpm, 1/2 to 1 -1/2 bpm attempting to establish circulation. Establish circulation at 4,849' w/ 1 bpm, 750 psi. Stage up to 4 bpm, 750 psi. 8/1/2011 8/2/2011 6,506.0 244.00 9.20 Continue to stage pumps up in 1 bpm increments f/ 170 gpm, 750 psi to 700 gpm, 2400 psi. Establish rotation f/ 40 rpm to 90 rpm. Pump H.V. 11.0 ppg sweep. CBU w/ 800 gpm, 2800 psi. - 80 rpm on down stroke - 120 rpm on up stroke. Stand back 1 stand and CBU x1 w/ same parameters - No significant cuttings observed. POOH on elevators f/4,849' U3,803' placing Rhino reamer 100' outside shoe. Break circ and stage up to 800 gpm, 2750 psi. Circulate until shakers cleaned up. Pump 30 bbls 11.0 ppg H.V. sweep + 2x bottoms up. Pull reamer into casing 1/3,585'. Backream f/3,585' 1/2,175' w/ 280 gpm, 30 rpm. RIH U3,422'. Service rig. RIH 1/3,803'. Circulate and condition mud. RIH f/3,803' 1/6,369'. Wash & ream f/6,369' 1/6,506'. Directional drill 11 -3/4" hole f/6,506' 1/6,750'. Maintaining 11.9 ppg - 12.3 ppg EMW using MPD. 8/2/2011 8/3/2011 6,750.0 1,333.00 9.35 Directional drill 11 -3/4" hole f/6,750' U7,226'. Service rig and change pop -off on #2 Mud Pump. Drill 11 -3/4" hole f/7,226' ±/7,607'. Change pop -off on #2 Mud Pump. Service rig. Drill 11 -3/4" hole f/7,607' 1/8,000'. Change pop -off on #2 Mud Pump. Drill 11 -3/4" hole f /8,000' 08,083' maintaining 11.5 ppg EMW using MPD. *"'Function test BOPE per AOGCC weekly requirement. Page 2/13 Report Printed: 10/31/2011 P I 0 N E E R * Operations Summary Report - Sta Well Name: ODSK -13 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftta) (ft) Mud (1b /gal) Summary 8/3/2011 8/4/2011 8,083.0 1,141.00 9.45 Directional drill 11 -3/4" hole f/8,083' t/9,224' (Inter/ TD). Maintaining 11.5 ppg EMW using MPD.Circulate hole clean. 8/4/2011 8/5/2011 9,224.0 0.00 9.45 Continue CBU 4x to hole clean. Maintain 11.6 ppg EMW using MPD. Stand back 1 stand ± every hour t/8,939'. POOH on elevators f/8,939' t/4,503'. Encountered tight spot @ 4,503'. RIH t/4,551'. Break circulation. Backream out of hole f/4,551' 03,930'. Experienced packoff at 3,930'. RIH t/4,052'. Break circ. POOH t13,625' placing top stab at 11 -3/4" shoe. RIH V3,772'. Stage pumps up to 400 gpm. Backream out f/3,772' to /3,500'. Drop ball to deactivate Rhino Reamer. Pressure up to 3500 psi and attempt to shear Rhino Reamer to deactivate w/ no success. RU to pump w/ cement pump. Attempt to shear w/ 4500 psi - no success. RD cement pump. Backream w/ no pump f/3,772' t/3,506'. Establish circ w/ 1/2 -1 bpm. Backream out f/3,506'1/3,224'. POOH on elevators f/3,224' t/1,885' - no issues. Service rig and change out Top Drive saver sub. Pull RCD head. Install trip nipple. 8/5/2011 8/6/2011 9,224.0 0.00 9.45 POOH f/1,804' t/ surface & LD BHA. Break out PWD from MWD tool string to rerun on new BHA. TIH picking up Rhino reamer assembly 045'. Plug in and upload MWD data - shallow pulse test same = Good test. Drop Rhino reamer activation ball, sheer same with 1000 psi - observed cutters open at 375 gpm with 270 psi. TIH f/45' t/3,532'. CBU while pull testing Rhino reamer - Good test. Remove trip nipple and install RCD bearing - maintain EMW to 12.0 ppg using MPD. TIH f/3,532' 06,919'. Establish circulation using step rate method and CBU while reaming f/6,919' 06,954'. Wash and ream in the hole f/6,954' t/7,049'. 8/6/2011 8/7/2011 9,224.0 0.00 9.60 Wash and ream in the hole f/7,049' t/9,224'. Circulate hole clean with 2 - 100 bbl hi -vis weighted 11.5 ppg sweeps. Hole packed off when second sweep exited bit - no retums. TIH f/9,048' t/9,200' - attempt to establish circulation. POOH attempting to establish circulation f /9,200' 1/7,646'. Close annular and pump down annulus thru kill line to confirm location of packoff. 20 gpm with 1000 psi pumping in - confirms packoff is in open hole. POOH attempt to establish circulation f/7,646' t/6,934'. TIH f/6,934' t17,190'. Establsih circulation using step rate method and stage pumps up. Staged pumps up to 725 gpm with 2875 psi in 1/2 bbl increments. Maintain 11.8 ppg EMW using MPD. Note** AOGCC was notified about shutting the well in due to high H2S alarm in rig mud pits and also notified prior to opening annular after verifying that H2S was from an accumulation of sour mud. 8/7/2011 8/8/2011 9,224.0 0.00 9.55 Pump 50 bbl hi -vis sweep and circulate the hole clean with same. Pump out the hole f/7,240' 1/7,049'. High H2S alarm in rig pits (25 ppm), shut in well, and evacuate rig. Tool pusher and PNR safety rep (donned escape packs) monitored level until it dissipated. Personnel allowed to return to the rig after level below 10 ppm. AOGCC was notified when well was shut in. Circulate thru gas buster while monitoring retums for H2S - 0 ppm detected. Open annular and use RCD as annular preventer. Investigation showed H2S to be coming from 11.5 ppg mud in rig pits. Active system mud contained no H2S. AOGCC was notified prior to opening annular preventer. CBU thru MPD to insure no H2S was in the well bore - No H2S metered for entire circulation. Pump out the hole f/7,049' (/6,219' - packed off at 6,219'. Establish circulation using step rate method and stage pumps up to 700 gpm. Circulate hole clean at 700 gpm. Back ream out the hole f/6,219' (/5,100' - multiple pack off events. Packed off with no returns at 5,100'. Establish circulation at 5,090' using step rate method and stage pumps up to 750 gpm. Pump hi -vis sweep and circulate hole clean at 750 gpm. Pump out the hole f/5,100' t/4,673'. Maintain 12.4 ppg EMW using MPD. *"'Note*" Gave 24 hr notice to AOGCC of upcoming BOPE test at 18:30 hrs on 08/07/11. 8/8/2011 8/9/2011 9,224.0 0.00 9.60 Circulate at reduced rate while Gearing cuttings from MPD lines. Reciprocate pipe while unplugging hammer mill at RSC. Staged pumps up to 750 gpm with 2800 psi. Pump out the hole f/4,673' t/3,850' - multiple pack off events. Staged pumps up to 850 gpm with 2900 psi. CBU 4x with hole unloading tuffaceous shale. POOH on elevators f/3,850' 1/1,913'. Mix 56 bbls hi -vis spacer and transfer 17.0 ppg mud from RSC to rig mud pits. Spot hi -vis spacer f/1,850' 01,345'. POOH on elevators f/1,850' (/1,345'. Spot 146 bbls of 17.2 ppg pill at 1,345'. Pull RCD bearing, change out air boot, and repair housing, install trip nipple. POOH on elevators f/1,345' t/ surface. Install wear ring junk screen, flush BOP with stack flushing tool, pull wear ring junk basket. RU testing equipment to test BOPE, and fill stack.Maintain 12.6 ppg EMW using MPD. Page 3/13 Report Printed: 10/31/2011 P I 0 N E E R • Operations Summary Report - Sta Well Name: ODSK -13 ATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud (lb/gal) Summary r and lower variable rams to 250 psi low / 4500 psi 8/9/2011 8/10/2011 9,224.0 0.00 10.70 Te OPE w/ 4" & 5" test joint. Test u e a d o p 1 PP P high. Tupper and lower IBOP valves to 250 psi low / 4500 psi high. Test annular w /4" test joint to 250 psi low / 2500 psi high. Test all floor valves to 250 psi low / 4500 psi high. Test 14 choke manifold valves to 250 psi low / 4500 psi high. All tests charted and all test held for 5 min. RD test equipment. Test witness waived by AOGCC Rep. John Crisp at 13:00 hrs 08/08/11. i S Initial system psi = 3000; 2050 after closure; 200 psi = 20 sec; full pressur 1 min. 35 sec. TIH picking up 1027' of 4" DP 1/4,300'. CBU and spot 140 bbis of hi -vis 15.4 ppg mud at 4,300'. POOH f/4,300' 1/3,498'. CBU at 3,498'. TIH f/3,498' 1/3,900'. CBU at 3,900'. RU cement manifold and lines. Pump 11 bbis seawater. Test cement lines to 3000 psi. Pump 71 bbis 15.9 ppg (340 • sxs © 1.16 CuFt/Sk) "G" Cement w/ 1.5% Calcium Chloride and .75% CFR -3. Pump 3 bbl seawater, swtiched to rig and displaced cement w/ 50 bbls 10.7 ppg mud at 10 bpm with 375 psi. CIP @ 15:10 hrs. LD cement manifold. POOH (/3,900' 1/3,493'. Drop DP wiper ball, and CBU 2x at 3,493'. Slip and cut 64' of drill line. TIH f/3,493' V3,770' - tag cement with 20k. Circulate hole clean at 3,770' - dumped 105 bbis of cement contaminated mud. RU cement manifold and lines. Pump 11 bbls seawater. Test cement lines to 3000 psi. Pump 25 bbis 15.9 ppg (121 sxs @ 1.16 CuFt/Sk) Class 'G' Cement w/ 1.5% Calcium Chloride and .75% CFR -3. Pump 3 bbl seawater, Swtiched to rig and displaced cement w/ 52 bbis 10.7 ppg mud at 10 bpm with 375 psi. CIP © 21:30 hrs. LD cement manifold. POOH f/3,770' 1/3,660'. Drop DP wiper ball and CBU 2x at 3,660'. POOH f/3,660' 113,498'. Circulate and condition mud while wait St 8/10/2011 8/11/2011 3,512.0 15.00 10.70 TIH 1/3,498' 1/3,670' - tag cement with 5k. RU cement manifold and lines. Pump 11 bbls seawater. Test cement lines to 3000 psi. Pump 71 bbls 15.9 ppg (340 sxs © 1.16 CuFUSk) "G" Cement w/ 1.5% Calcium Chloride and .75% CFR -3. Pump 3 bbl seawater, swtiched to rig and displaced cement w/ 52 bbis 10.7 ppg mud at 650 gpm with 2000 psi - hole packed off when cement tumed the comer. CIP © 01:40 hrs. LD cement manifold. POOH f/3,660' 1/3,117'. Drop DP wiper ball and CBU at 3,117' - close annular and squeeze cement in place with 13.0 ppg EMW for 10 min - 2.5 bbls total. Wash and ream 1/3,117' 1/3,300'. Rack back 1 stand 1/3,212' and CBU hole clean 4x. POOH f/3,212' V surface laying down 4" cement stinger. Pick directional BHA f/ surface 1/285' - Up loaded LWD data at 94' and shallow pulse tested same - Good test. TIH 1/285' 113,000' - tag cement stringer with 10k. Wash and ream thru cement and contaminated mud 1 /3,000' 1/3,306'. Drill cement 1/3,306' V3,512'. Directional drill f/3,512' 1/3,527' - hole packed off and stuck pipe at 3,527'. Jarring on stuck pipe, attempting to circulate with out success - Jarred pipe 1/3,527' V3,514' - pipe free at 3,514'. Circulate and condition mud while inspecting derrick after jarring. 8/11/2011 8/12/2011 3,527.0 92.00 11.00 Circulate and condition mud while inspecting derrick and top drive. POOH f/3,512' V surface laying down BHA. TIH f/ surface 1/625'. Upload MWD data and shallow pulse test same - Good test. TIH f/625' 1/3,480'. Wash and ream f/3,480' 1/3,527'. Directional drilling f/3,527' 1/3,619'. Back ream out the hole f/3,619' 1/3,480' - hole packing off severely. Pump 50 bbis hi -vis weighted sweep at 12.9 ppg. CBU hole clean 3x. 8/12/2011 8/13/2011 3,619.0 622.00 10.90 Wash in the hole f/3,480' 1/3,619'. Directional drilling f/3,619' 1/4,241'. Pump 50 bbis hi -vis weighted sweep at 13.0 ppg and CBU hole clean 3x - rack back 1 stand every 30 min 1/4,241' V3,956'. Back ream out the hole 1/3,956' 1/3,660' and pull on elevators t/3,480'. CBU hole clean 2x. POOH 1/3,480' t/3,290'; 25 -75K overpull and swabbing. Pump 50 bbls hi -vis weighted sweep at 13.0 ppg. CBU hole clean 2x. Pump out the hole 1/3,290' 1/1,672'. POOH 1/1,672' 1/625' and start laying down BHA #6. 8/13/2011 8/14/2011 4,241.0 705.00 11.00 LD BHA up to the MWD tools, down load data, and finish laying down BHA # 6 and clear same from rig floor. TIH with BHA #7 f/ surface 1/625'. Up load MWD data and shallow pulse test same - Good test. TIH f/625' 1/3,620'. Wash in the hole 1/3,620' 1/4,241'. Directional drill f/4,241' 1/4,322'. Drop 1 -5/8" activation ball for Rhino Reamer, pump down same, and shear ball seat with 1000 psi - confirmed open with pump pressure loss and increase in torque. Directional drill f/4,322' 1/4,946'. 8/14/2011 8/15/2011 4,946.0 1,494.00 11.00 Directional drill f/4,946' 116,440'. 8/15/2011 8/16/2011 6,440.0 610.00 11.00 Directional drill (/6,440' t/6,535'. CBU, pump 80 bbl hi -vis weighted sweep at 13.0 ppg and circulate surface to surface with same. Back ream out the hole f/6,467' 1/4,356'. CBU, pump 80 bbl hi -vis weighted sweep at 13.0 ppg and circulate surface to surface with same. TIH f/4,471' 1/6,467'. Establish circulation, wash and ream 1/6,467' 116,535'. Directional drill f/6,535' 1/7,050'. 8/16/2011 8/17/2011 7,050.0 1,152.00 11.00 Directional drill 1/7,050' 1/7,399'. Function test BOPE as per AOGCC PTD. Directional drill 1/7,399' 1/8,202'. Page 4/13 Report Printed: 10/31/2011 P I 0 N E E R * Operations Summary Report - Sta Well Name: ODSK -13 NATURAL RESOURCES Start Depth Foot Meters Dens Last Start Date End Date MKS) (ft) Mud (Ib/gal) Summary 8/17/2011 8/18/2011 8,202.0 898.00 11.00 Directional drill f/8,202' 1/9,100'. Pump 80 bbl hi -vis 13.0 ppg sweep and CBU hole clean 3x while opening up rathole with Geo -Pilot quadrant TF settings. Drop 2" deactivation ball, pump down same and deactivate Rhino reamer - confirm same. Back ream out the hole f/9,036' t17,514'. 8/18/2011 8/19/2011 9,100.0 0.00 11.00 Back ream out the hole f/7,514' t/5,611'. Back feed RSC and CCU - unplug cuttings transfer line from CCU. Back ream out the hole f/5,611'1/4,566'. Pump 90 bbl hi -vis 13.0 ppg sweep and CBU hole clean 2x. Unplug flow line while servicing rig. Pump 90 bbl hi -vis 13.0 ppg sweep and CBU hole clean 2x. Back ream out the hole f14,376' t/4,281'. Perform check TIH f14,281' t/4,661' to evaluate clean hole. POOH f/4,661' t/4,281' with no issues. Back ream out the hole f/4,281' t/3,813'. Work pipe f/3,813' t/3,910' attempting to establsih circulation at full rate. TIH f/3,910' 1/3,965' and establish circulation. CBU hole clean 3x. 8/19/2011 8/20/2011 9,100.0 0.00 11.00 Pump out the hole from 3,901' to 3,512'. Pump 90 bbl hi -vis 13.0 ppg sweep and circulate 2x bottoms up. Pump out the hole from 3,512' to 3,329'. Change out swivel packing on top drive. Pump out the hole from 3,329 to 1,807'. Pump 80 bbl hi -vis 13.0 ppg sweep and circulate 2x bottoms up. Pull out the hole from 1,807' to surface, and lay down BHA. Pick up BHA tools, and reconfigure MWD tools for PWD run. Pick up Rhino reamer, make up assembly to pump thru same -- observed blades opening. Reamer was not deactivated. Pick up BHA # 8 from surface to 601' -- upload MWD data, and shallow pulse test same -- Good test. Trip in the hole from 601' to 3,456'. Slip and cut drill line. Circulate surface to surface at 3,456'. Trip in the hole on elevators from 3,456' to 4,692'. Circulate and condition mud for liner run. 8/20/2011 8/21/2011 9,100.0 0.00 11.00 CBU and condition mud 3x to run liner. POOH on elevators f14,692' t/3,512'. Pump 80 bbl hi -vis 13.0 ppg sweep and CBU 2x. POOH f/3,512' 1/ surface laying down BHA. PU 9, 8" DC's, pump thru same, and rack back in derrick. RD iron rough neck tracks and RU Tesco casing running tool. Change out bottom rams from VBR's to 9 -5/8" casing rams. RU testing equipment and test same to 250 psi low / 4500 psi - on chart 5 min each. RD test equipment. Finish rigging up to run 9 -5/8" liner, and held PJSM with all personnel. Run 9 -5/8" 40# L -80 Hyd 521 liner f/ surface t/4,845'. 8/21/2011 8/22/2011 9,100.0 0.00 10.00 Run 9 -5/8" 40# L -80 Hyd 521 liner f/4,845' 1/5,785'. Pty liner hanger / packer assembly f/5,785' t/5,834'. TIH with 9 -5/8' liner on 5" DP f/5,834' 1/9,098'. Establish circulation using step rate method in 1/2 bbl increments. Drop the hanger setting ball and pump onto seat at 4 bpm with 400 psi. Ball pumped onto seat - set the hanger with 2000 psi and slack off 75k to engage slips - shear the ball seat with 3100 psi. Release hanger - PU and verify released. TOL at 3,282'. Liner shoe at 9,098'. Circulate and stage rate up to 8 bpm with 650 psi. Held Pre -job meeting and line up to cementers: Pump 10 bbls seawater ahead - test lines to 4000 psi. Pump 60 bbls dual spacer at 12.5 ppg. Pr imp 1 nn hhls (480 sx) Class 'C;' cement at 15.8 oog. w/ yield of 1.17 and \ , additives: 0.5% HALAD 344 - 0.2% CFR -3 & 0.3% SCR -100. Drop DP wiper plug - Kick out w/ 20 bbls seawater. Line up to rig pumps - Displace w/ 10.0 ppg LSND mud. Slow pumps to bump plug with 5,520 strokes and seen 100 psi pressure spike, however, attempt to pressure up and pump by the plug. Shut down pumps at 5,556 strokes to not exceed half the shoe track (Note: 481 bbls total displacement which includes 17 bbls of Seawater to kick out dart + 464 bbls of 10.0 ppg drilling fluid). Witnessed full returns throughout job with verification of cement lift while pressure increased continuously as spacer and cement exited the shoe. Bleed off and check floats (Held). CIP at 15:50 hrs. PU and expose dogs, slack off, and set packer - sheared with 50K. PU and establish rotation at 5 rpm and slack off 50K to verify set - test packer down annulus to 3500 psi for 5 min - Good test. CBU 1.5x at 3,238' - no cement on bottoms up. RD cement head, cement lines, and casing equipment. POOH f/3,238' 1/ surface. LD liner running tool. Page 5/13 Report Printed: 10/31/2011 n I O N r r n operations Summary Report - State Well Name: ODSK -13 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud (lb/gal) Summary 8/22/2011 8/23/2011 9,100.0 0.00 10.00 MU retrievable bridge plug and TIH 1/3,331'. Set RBP, set down with 20k, overpull 10k to confirm set. Set 10k down on RBP to test casing. Test 11 -3/4" casing to 3500 psi for 30 min on chart - Good test. Release running tool from RBP and tag with 10k to confirm same. POOH f/3,331' t/ surface and LD running tool. ND BOPE and drilling spool. Install and NU Multi -bowl well head. Test same to 5000 psi on chart for 10 min. NU BOPE. Change out lower rams from 9 -5/8" casing rams to 2 -7/8" x 5" VBR's. Install trip nipple and turn buckles on BOP stack. RU test equipment and test BOPE with 5" test jt. Test upper and lower variable rams to 250 psi low / 4500 psi high. Test upper and lower IBOP valves to 250 psi low / 4500 psi high. Test annular to 250 psi low / 2500 psi high. Test all floor valves to 250 psi low / 4500 psi high. Test 14 choke manifold valves to 250 psi low / 4500 psi high. All tests charted and all test held for 5 min. RD test equipment. Test witness waived by AOGCC Rep Bob Noble at 08:40 hrs 08/21/11. Initial system psi = 3000; 2200 after closure, 200 psi = 26 sec, full pressure 1 min 45 sec. Pull test plug and install wear bushing. MU retrieval tool for RBP and TIH 1/3,331'. Latch onto RBP, unset same and POOH f/3,331' 113,224' - RBP above liner top at 3,282' in 11 -3/4" casing. Test 11 -3/4" x 9 -5/8" casing to 3500 psi for 30 min on chart - Good test. 8/23/2011 8/24/2011 9,100.0 20.00 9.80 POOH f/3,227' U surface and lay down RBP assembly. TIH picking up clean out BHA f/ surface 1/477'. TIH f/477' 1/8,945' - wash down f/8,945' - tag plug at 8,971'. Drilling cement, float equipment, and 20' new hole f/8,971' 1/9,120'. Pull up into casing U9,086' and perform F.I.T. at 5,423' tvd; with 10.1 ppg mud to 1100 psi for EMW of 14.0 ppg - Good test. Circulate and displace well from 10.1 ppg mud to 9.8 ppg LSND mud. POOH f/9,086' 1/ surface - LD BHA #9. Pull wear ring and install test plug to test MPD lines. 8/24/2011 8/25/2011 9,120.0 435.00 9.80 Remove trip nipple and install MPD test flange. Test MPD pump and choke lines to 250 psi low / 4500 psi high. Remove MPD test flange and install trip nipple. Remove test plug and install wear bushing. PU BHA #10 1/612'. RIH 1/8,794'. Pull trip nipple. Install RCD head. Wash and ream f/8,794' t/9,120'. Directional drill 8 -1/2" new hole f/9,120' 1/9,555'. 8/25/2011 8/26/2011 9,555.0 1,025.00 10.20 Directional drill 8 -1/2" new hole f/9,555' U10,127'. Change swab and liner. Repair crack in# 2 mud pump suction line. Continue Directional drill 8 -1/2" hole f/10,127' 1/10,580'. Maintain 11.8 ppg EMW using MPD. 8/26/2011 8/27/2011 10,580.0 607.00 10.30 Directional drill 8 -1/2" hole f/10,580' 1/10,830'. Replace washed out valve /seat in #2 mud pump. Continue directional drill 1/11,187' (8 -1/2" pilot hole TD). Maintain 13.0 ppg EMW using MPD. Pump 12.1 ppg H.V. sweep, surface to surface followed by CBU 2x. Pump out of hole w/ 30 spm f/11,187' U9,270' leaving top stab outside 9 -5/8" shoe. Pump 12.1 ppg H.V. sweep to surface. POOH f/9,270' 1/8,978'. Service rig. RIH f/8,978' 1/11,140'. Fill pipe and break circ. Log down f/11,140'1/11,187' at 150 fph. Pump 12.1 ppg H.V. sweep. 8/27/2011 8/28/2011 11,187.0 0.00 13.00 Continue to pump 12.1 ppg H.V. sweep to surface. - Displace well w/ 13.0 ppg KWM f/11,187' U surface maintaining 13.1 ppg EMW using MPD rate/pressure schedule. Monitor well. Pull RCD. Install trip Nipple.POOH on elevators f/11,187' 1/10,595' (PUW 285k). MAD Pass f/10,595' U10,495' (bit depth) at ±350 fph. Continue POOH 1/612' (BHA). LD BHA and download MWD. RIH PU 4" DP 1/1,092'. RIH on 5" DP 1/7,754'. Service rig. 8/28/2011 8/29/2011 11,187.0 0.00 9.90 RIH f/7,754' U11,177'. Circulate and condition mud for upcoming cement abandonment plug. Hold PJSM w/ all involved in upcoming cement plug abandoment job. -Line up HES cementers and pump 24.5 bbls water, 59 bbls 15.8 ppg Class 'G' cement followed by 5 bbls water. Displace w/ rig pumps and spot cement f/11,187' 1/10,437' (CIP @ 07:00 hrs). POOH 8 stands U10,416'. CBU. Cement contminated mud observed with B.U. Cement calculations based on caliper log. -Line up HES cementers and pump 24.5 bbls water, 59 bbls 15.8 ppg Class 'G' cement followed by 5 bbls water. Displace w/ rig pumps and spot cement f/10,437' U9,687' (CIP @ 10:30 hrs.). POOH 8 stands 1/9,654'. CBU. Cement contminated mud observed with B.U. Cement calculations based on caliper log. -Line up HES cementers and pump 24.5 bbls water, 65 bbls 16.4 ppg Class 'G' cement followed by 5 bbls water. Displace w/ rig pumps and spot cement f/9,687' 1/8,887' (CIP @ 14:30 hrs). POOH 9 stands 1/8,798'. CBU. Cement contminated mud observed with B.U. Cement calculations based on 9.2" caliper log + additional 100' inside 9 -5/8" shoe for a total of 200' inside casing. - Displace well from 13.0 ppg KWM to new 9.8 ppg LSND. POOH f/8,798' 1/1,092' (4" DP cement stinger). LD 4" DP and muleshoe. Service rig. PU 5" handling equipment. Page 6/13 Report Printed: 10/31/2011 P I 0 N E E R ,Perations Summary Report - Stab Well Name: ODSK -13 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (1t(B) (ft) Mud pb/gal) Summary 8/29/2011 8/30/2011 9,098.0 308.00 9.80 * *Function test BOPE per AOGCC weekly requirement * *. PU BHA #11 f/ surface 1/96'. Download MWD tools and pulse test same. Continue PU BHA f/96' ±/280'. RIH w/ 5" HWT and 5" DP 1/8,644'. Slip & cut drilling line. Service rig. Wash & ream f/8,644' 1/8,840' encountering some cement stringers. Taking weight at 8,840'. Stop rotary and PU. Set down and tag hard cement with 10k down weight. 9 -5/8" shoe at 9,098' (258' of cement inside casing). Drill cement f/8,840' t19,098' (9 -5/8" shoe) w/ 8 -10k WOB. CBU 2x to clean cement out of hole. Pull trip nipple. Install RCD head. Directional drill 8 -1/2" hole f/9,098' 1/9,406' 8/30/2011 8/31/2011 9,406.0 1,047.00 9.90 At 9,406'; Drop Rhino Reamer 1 -1/4" activation ball and pump down same. Observe ball seat and shear at 2300 psi. Bring pumps up to 500 gpm, 2300 psi - Increase to 700 gpm, 3600 psi (3850 psi prior to shear). PU 1/9,396' bit depth (9,318' R.R. depth) - Open hole f/9,396' 1/9,401' bit depth. Stop rotary. Set down on ledge w/ 10k down to verify reamer open. Make connection and open hole 119,406' bit depth. Continue directional drill 8 -1/2" hole f/9,406' 1/9,561'. Change swab & liner on #1 mud pump. Drill f/9,561' 119,882'. Change RCD head due to bearing seal failure. Service rig. Drilling f19,882' 1110,299'. Change swab & liner in #2 mud pump. Drill f/10,299' 1110,453'. Service rig. Change swab in #1 mud pump. 8/31/2011 9/1/2011 10,453.0 665.00 9.90 Working on mud pump #1. Replace wear plate & gasket in #1 mud pump. Repair mud pump pop off. Drill f/10,453' 1/11,118'. Service rig. Inspect gear end on #2 mud pump. POOH 1/10,834' while pumping s pin, pst. 9/1/2011 9/2/2011 11,118.0 312.00 10.20 POOH f/10,834' t/9,050' (43' inside 9 -5/8" casing). Continue to replace fluid end on #2 mud pump. (#3 pod). Change RCD bearing while while working on mud pump. Shut in #2 pump and pressure test same to 4500 psi. RIH f/9,025' t/ ±9,500'. Bring pumps up to drilling rate to verify rod bearing on #2 mud pump running properly. Continue RIH 1/11,024'. Wash & ream f/11,024' , 111,118'. Drill f/11,118' 1111,430' (Inter. 2 TD). Open pilot hole using Sperry quadrant reaming technique. Replace valve & seat on #1 mud pump. Weld up hole in #2 mud pump suction manifold. Pump weighted H.V. sweep to surface. Drop Rhino Reamer deactivation ball - pump down same. Observe reamer shear. POOH for wiper trip f/11,430' 1111,049'. RIH to TD at 11,430'. Break circulation and circ 1/2 BU. Pump weighted H.V. sweep surface to surface. 9/2/2011 9/3/2011 11,430.0 0.00 13.00 Continue CBU 3x after sweep. Displace well f/ 10.2 ppg to 13.0 ppg KWM. Monitor well. Pull RCD. Install Trip Nipple. POOH f/11,430' 1/9,025' while pumping pipe displacement + (9 -5/8" shoe at 9,098'). Monitor well. Pump dry job. Drop DP drift. POOH (SLM) f/9,025' 1/558' (BHA). Stand back Hwt, LD jars. Download MWD tools. LD remainder of BHA. Change lower rams from 2 -7/8" x 5" variables to 7 ". PU 7" test joint and test annular to 250 psi low / 2500 psi high for 5 charted min each test. Test lower rams to 250 psi low / 4500 psi high for 5 charted min each test. RD test equipment. 9/3/2011 9/4/2011 11,430.0 0.00 10.20 RU casing tools - PJSM w/ all involved with upcoming casing job. (-PU 7" shoe track - baker -lock 1st 4 connections and toraue to 6200 ft/lbs. -Run 7" 26# Hydril 511 casing per liner running tallytl2,444'. PU liner hanger /packer and running tool t/2,496'. Circulate liner volume. RIH w/ liner on 5" DP 1/11,425'. PU cement head and pump joint. Tag bottom at 11,430'. Break circulation and stage pumps up to 1 bpm, 700 psi. Pump 50 bbls 13.0 ppg H.V. spacer followed by 10.2 ppg LSND mud. Position liner shoe at 11,428' (2' off bottom). TOL at 8,949' & BOL at 11,428'. Continue to stage pumps up to 5 bpm, 850 psi. Page 7113 Report Printed: 10/31/2011 P I 0 N E E R •)perations Summary Report - Statt Well Name: ODSK -13 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud (lb/gal) Summary 9/4/2011 9/5/2011 11,430.0 10.20 Continue pump hanger setting ball and observe seat at 207 bbis away. Pressure up to 2300 psi. Set 35k down weight. Pressure up and observe ball seat shear w/ 3100 psi. Break circulation w/ 5 bpm, 600 psi. PU to verify released f/ hanger. PUW 225k (lost 40k up wt. Stage pumps up to 7 bpm, 800 psi. Contnue to circulate & condition for cement job & achieve 10.2 ppg to surface. -Line up Halliburton: - Pump 10 bbis seawater - Test lines to 4000 psi. -Pump 45 bbis Dual Spacer at 12.5 ppg w/ 5 bpm, 1100 psi. -Pum• 33.1 bbis 159 sx Class G cement at 15.8 • • • • • • 1.17 ield & 5.12 GPS w/ 5 bpm, 1300 � psi. - Class 'G' Additives: 0.65% Naiad 344, 0.2% CFR 3 & 0.35% SCR -100. l i t - Displace using rig pumps w/ 10.2 ppg LSND w/ 8 bpm, 1600 psi. - Slow pumps and latch up at 1447 stks (200 stks early) - Observe shear w/ 800 psi. -Reset HES flowmeter. -Bump plug w/ 88.1 bbis away after latch (2513 total stks.). CIP at 03:30 hrs. - Pressure up to 3500 psi. & hold f/ 5 min. Bleed & check floats. Floats holding. , -PU & open bumper sub w/ 225k - PU 6 1/2' to expose setting dogs. -Set down & observe packer set w/ 35k down - Observe tieback shear w/ 55k down. -PU & set down 55k on liner top. PU & rotate 5 rpm. Set down 55k, PU & repeat. -Close top rams. Pressure up to 3500 psi. Hold for 5 min on chart. Good test. -Pull running tool and packoff to clear liner - CBU w/ 8 bpm, 550 psi. - TOL 8,949'. Liner shoe 11,428'. -LD cement head. POOH f/8,949' t/ surface. LD running tools. PU polish mill assembly & RIH 1/8,949'. Pump 12.7 ppg H.V. sweep. Polish ID of tie -back f/8,949' t/8,969'. CBU 2x. Close top rams and pressure test 7" x 9 -5/8" liner la, / casin• t. 3500 • • f•r • ,i • • • 1 Good test. POOH LD 5" DP 1/4,940'. * Notified AOGCC w/ 24 hr notice of upcoming BOP test.** 9/5/2011 9/6/2011 11,430.0 10.20 Continue to POOH f/4,940' 1/ surface. LD polish mill BHA. Pull wear ring. RU to test BOPE. -Test BOPE per AOGCC PTD: -Test upper variable rams to 250 psi low / 4500 psi high w/ 4" test joint. -Test lower 7" rams to 250 psi low / 4500 psi high w/ 7" test joint. -Test upper and lower IBOP valves to 250 psi low / 4500 psi high. -Test annular to 250 psi low / 2500 psi high w/ 4" & 7" test joint. -Test all floor valves to 250 psi low and 4500 psi high. -Test 14 choke manifold valves to 250 psi low and 4500 psi high. -All tests charted and all tests held for 5 min. -Rig down test equipment. -Test witnessed by AOGCC Rep Chuck Scheve. - Initial system psi. 3000, 1900 after closure, 200 psi= 22 sec, full pressure 2 min. 2 sec. -Gas detector at shaker -LEL initally failed = audible. Re- calibrated and re- tested - OK. RD and install wear ring. MU muleshoe & RIH w/ 5" DP 1/3,527'. Cut & slip drilling line. POOH, LD 5' DP to surface. Pull wear ring. RU Tesco casing tools. RIH w/ 7" 26# L -80 BTC -M casing (tie -back) t/1,497'. 9/6/2011 9/7/2011 11,430.0 10.20 Continue RIH w/ 7" 26# L -80 BTC -M casing f/1,497' t/8,949' (top PBR). Sting into PBR w/ seal assembly and indexing muleshoe and tag w/ no -go locator. PU 10' placing muleshoe at 8,959' (middle of PBR). Test 7" x 9 -5/8" x 11 -3/4' annulus to 3500 psi f/ 5 min.Take spaceout mesurements. LD 3 joints 7" casing. PU spaceout pups & place below 1st full joint below hanger. /' MU hanger and landing joint. Spot seal assembly 1' above PBR. Pump 135 bbis diesel down r annulus taking returns out casing to rig pits. Strip through annular, land hanger, and spot seals f/8,957' 1/8,959' (middle of PBR). Indexeing muleshoe at 8,962'. Verify hanger on seat. Close lower 7" rams. Test annulus to 3500 psi f/ 30 min on chart - Good test. Pump down casing to set "SHR" hold down sub (set to shear at 815 psi). v - Continue to pressure up and test casing to 3500 psi f/ 30 min on chart - Good test. Bleed pressure & PU to pull test "SHR" Hold Down sub. Slips failed. Continue to PU and string broke over at 225k up wt & pressure bled off. Repeat pressure up to 3000 psi to set sub w/ no success. Apply 400 psi and PU to attempt to set slips w/ no success. Service rig and mobilize tools to rig floor while W.S.L. discusses options w/ town team. Decision made to land hanger and proceed forward. Sting seals into PBR. Seals at 8,957' 1/8,959' - Muleshoe at 8,962'. Retest casing to 3500 psi f/ 30 min on chart - Good test. LD landing joint. RD Tesco casing tools. Vetco Rep. install 7" packoff. Vetco Rep test packoff to 5000 psi f/ 10 min on chart - Good test. Install test plug. Change lower rams f/ 7" t/ 2 -7/8" x 5" variables. Change Top Drive upper & lower IBOP f/ 4 -1/2" IF 1/4" XT -39. RU test tools. Test annular w/ 4' test joint to 250 psi low / 2500 psi high. -Test upper vbls, IBOP, kill line w/ 4" test joint to 250 psi low / 4500 psi high. -Test lower vbls, FOSV w/ 4" test joint to 250 psi low / 4500 psi high. -All tests charted and all tests held for 5 min. Page 8/13 Report Printed: 10/31/2011 P I 0 N E E R *Operations Summary Report - Stal Well Name: ODSK -13 l \IATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud (lb/gal) Summary 9/7/2011 9/8/2011 11,430.0 10.20 Test lower vbls w/ 4 -1/2" test joint to 250 psi low / 4500 psi high f/ 5 charted min each test. Pull test plug. LD landing joint. Install 6 -3/8" ID wear ring. RU 4" handling equip. PU muleshoe on joint of 4" DP. RIH PU 4" DP 1/5,500'. Circulate DP volume. POOH standing back 4" DP PU cleanout BHA w/ BAT Sonic tool 11340'. Work on Iron Roughneck. RIH PU 4" DP f/340' 1110,612'. 9/8/2011 9/9/2011 11,430.0 24.00 10.30 TIH f/10,6121111,137' - tag cement with 20k. Drill cement and float equipment f/11,137' 1/11,430'. Drill new formation f/11,430' 1/11,454'. CBU at 11,454'. Perform F.I.T. at 11,428' md/6,182' tvd with 10.2 ppg mud to 740 psi for EMW of 12.5 ppg - Good test. POOH for MAD pass f/11,454' 1/9,100'. Continue to POOH t/ surface, laying down BHA. PU BHA #14 f/ surface 1140'. Troubleshoot hydraulic leak on blind rams hinge pin and repair same. Tightened hinge bolts on ram door to stop leak. PU BHA #14 f /40' 1/144' and shallow pulse same - Good test. 9/9/2011 9/10/2011 11,454.0 194.00 8.50 PJSM, load nuclear sources and PU BHA f/144' 11420'. TIH f/420' 1/11,400'. Slip and cut drill line. Remove trip nipple and install RCD bearing. Displace hole from 10.2 ppg LSND to 8.6 ppg Quick Drill -N mud. Directional drill 6 -1/8" hole f/11,454' U11,555'. Perform Pore Pressure test w/ MPD on Kup "C" formation - Final WHP 230 psi = 9.21 ppg EMW. Directional drill 6 -1/8" hole f/11,555' 1/11,648'. 9/10/2011 9/11/2011 11,648.0 77.00 8.50 Directional drill 6-1/8" hole f/11,648' 1111,725'. 9/11/2011 9/12/2011 11,725.0 194.00 8.50 Directional drill 6 -1/8" hole f/11,725' 1111,854'. Unable to get response from Geo -Pilot after down link & trouble shoot same. Directional drill f/11,854' t/11,919'. Slight pack off event while drilling - PU and circ hole clean. Pull above LCU 1111,790'. 9/12/2011 9/13/2011 11,919.0 15.00 8.50 Pump out the hole f/11,790' 1111,400'. Circulate and condition mud at 11,400' - Dump oil saturated saponified mud on bottoms up. Displace hole with new 8.5 ppg Quick DriI -N mud. Wash and ream in the hole f/11,400' 1111,900' - slight pack off event. POOH f/11,900' 1111,796' and CBU 2x. Perform Pore Pressure test w/ MPD on Kup "C" formation - Final WHP 459 psi = 9.92 ppg EMW. EMW. Perform weekly function test of BOPE as per AOGCC PTD - Good test. Wash and ream in the hole f/11,796' 1/11,919'. Directional drill 6 -1/8" hole f/11,919' 1111,934'. 9/13/2011 9/14/2011 11,934.0 846.00 8.50 Directional drill 6 -1/8" hole f/11,934' U12,780'. 9/14/2011 9/15/2011 12,780.0 1,126.00 8.50 Directional drill 6 -1/8" hole f/12,780' U13,906'. 9/15/2011 9/16/2011 13,906.0 607.00 8.55 Directional drill 6 -1/8" hole f/13,906' 1114,513'. Trouble shoot Directional tools - No success. CBU 4x to clean hole and 40 bbl hi -vis sweep racking back 1 stand every hour 1114,290'. POOH f/14,290' U11,400'. 9/16/2011 9/17/2011 14,513.0 0.00 11.20 CBU 2x to clean hole at 11,400'. TIH f/11,400' 1/14,513'. CBU at 14,513'. Perform Pore Pressure test w/ MPD on Kup "C" formation - Final WHP 694 psi = 10.73 ppg EMW. Pump 50 bbl hi -vis sweep, and circulate hole clean with same. POOH on elevators f/14,513' U11,949'. Circulate and condition mud while RSC weights up brine to 11.2 ppg. POOH f/11,949' U11,400'. Waiting on RSC to weight up brine from 10.5 ppg to 11.2 ppg. TIH f/11,400' 1/11,949'. POOH f/11,949' U11,400' - laying 11.2 ppg hi -vis pill in open hole. Displace well from 8.5 ppg to 11.2 ppg brine at 11,400'. Monitor well for 15 min - static, pull RCD, and install trip nipple. Pump out the hole f/11,400' 1/10,053' and monitor well 20 min - static. Drop 2.4" rabbit and POOH f/10,053' 1/8,608'. 9/17/2011 9/18/2011 14,513.0 0.00 11.20 POOH f/8,608' U surface laying down BHA. TIH picking up 21 joints of HWDP and pump 3x DP volume. Rack back 7 stands HWDP in derrick. RU 4 -1/2" casing equipment. RIH with 4.5" L -80 12.6# Imp -BTC slotted liner f/ surface 113,202'. Record PU, SO, ROW and Torgue. MU WFT "PHR" liner hanger, "NTH" liner top pkr, and Razorback scraper / magnet assembly f/3,202' U3,366'. TIH with 4.5" slotted liner on 4" DP f/3,366' 114,521. Page 9/13 Report Printed: 10/31/2011 P I 0 N E E R •Perations Summary Report - State Well Name: ODSK -13 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftlB) (ft) Mud (Ib/gal) Summary 9/18/2011 9/19/2011 14,513.0 0.00 11.15 TIH with 4.5" slotted liner on 4" DP f/4,521' t/14,513'. Circulate 1.25x pipe capacity. Drop 1 -3/4" phenolic ball and pump to seat ball. Ball failed to seat. Increase rate and pump 2x DP volume. Stroke pipe in attempt to jar ball free. Drop 1 -3/4" aluminum ball and pump to seat ball. Ball failed to seat. Increase rate and pump 2x DP volume. Stroke pipe in attempt to jar ball free. Attempt to mechanical release liner running tool off liner hanger packer. Work left hand torque and reciprocate pipe — unsuccessful. Mix and pump 20 bbls hi -vis sweep in attempt to transport balls to seat. Pump 2x DP volume — no success. Pump 6" wiper ball in attempt to sweep balls to seat. Pressure spiked to 1600 psi at calculated strokes. Stroked pipe to determine if liner hanger set, hanger moved up hole. Attempt to stroke pipe back down, stacked up on hanger and unable to move liner back down. Work left hand torque down and mechanically release hanger. PU and expose setting dogs and set packer with 20-50K down weight 2x. TOL= 11,270'. Liner shoe= 14,498'. Pressured liner packer to 3500 for 15 mintues to confirm packer set (Note: this test was simply performed to confirm that packer set and is not required for mechanical integrity since this is a slotted liner). CBU 2x at 11,240'. POOH f/11,240' t/6,779' laying down DP. 9/19/2011 9/20/2011 14,513.0 0.00 11.10 POOH f/6,779' laying down DP with 4-1/2" liner running string. RU test tools - Test annular w/ 4' test joint to 250 psi low / 2500 psi high. Test upper vbis, IBOP, kill line w/ 4" test joint to 250 psi low / 4500 psi high. Test lower vbls, FOSV w/ 4" test joint to 250 psi low / 4500 psi high. All tests charted and all tests held for 5 min. Test lower vbls w/ 2- 7/8" test joint. to 250 psi low / 4500 psi high f/ 5 charted min each test. Pull test plug - LD landing joint. Install 6 -3/8" ID wear ring. Jeff Jones w/ AOGCC waived witness @18:52 hrs on 09/18/2011. RIH t/11,412' with hydraulic bailer to retrieve rubber wiper ball. Stack 10k on bailer to function five times resulting in 10 bbls lost from trip tank. 9/20/2011 9/21/2011 14,513.0 0.00 11.10 POOH f/11,412' t/ surface laying down DP & BHA. Monitor well static. RU to run ESP completion. 9/21/2011 9/22/2011 14,513.0 0.00 11.10 RIH ESP completion f /0' t1902'. Tag up on obstruction, Work completion free, and POOH. Missing 3 "x2 "x2" Christolizer gate. 9/22/2011 9/23/2011 14,513.0 0.00 11.10 RD ESP and perform fishing operations on DP and Slickline. Recover Chrisstolizer gate. Still missing 1 "x7/8 "x3/4" Chrisstolizer hinge plate. 9/23/2011 9/24/2011 14,513.0 0.00 11.10 RIH with Mule shoe, Magnet, Scraper, Bumper jars. Test packer on 4" DP f/ surface t/10,174'. Set Baker test packer at 2,996'. Pressure up to 2000 psi and observed immediate pressure loss and gained string weight to 150k. Monitor well. Reset packer 5' deeper. Pressure up to 500 psi and confirm communication with OA. RU circulating manifold to circ through IA / OA. Test manifold and lines to 1000 psi for 5 min. Pump down IA taking retums out OA to production flowback tank to displace diesel freeze protect out of OA. RU and pump down OA taking retums out IA to flowback tank to remove any residual diesel. Bleed off and blow down all lines. 9/24/2011 9/25/2011 14,513.0 0.00 11.10 Continue to circ down OA taking returns out IA to flowback tank. Release test packer per Baker Rep. Observe well f/ 10 min. Static. POOH f/10,174' 1/8,151' muleshoe depth (packer at 970'). PU storm valve per Baker Rep. RIH on 4" DP 1/10,190'. RIH PU 4" DP from shed 1/11,148' placing test packer at 3,968' and storm valve at 2,992'. Fill pipe. Set packer and release from form valve. POOH f/2,992' t/ surface. LD running tool. Install test plug. Change top rams f/ Lt18" x 5" vbls to 7 ". Test 7" rams to 250 psi low / 4500 psi high f/ 5 charted min each test. Pull , � p itest plug. Verify 0 psi on OA. Pull 7" packoff. PU 7" landing joint and engage 7" hanger. Pull t V hanger and casing to rig floor. LD hanger and landing joint. RU circ swadge and manifold. Test r lines to 1000 psi. Pump down 7" casing w/ 11.1 ppg taking returns out OA to production flowback l tank. Pump down OA w/ 11.1 ppg taking returns out 7" casing to achieve 11.1 ppg around. Lay • down 20 joints 7" casing + 3 pup joints. Service rig. Change top rams f/ 7" to 2 -7/8" x 5" vbis. test same to 250 psi low / 4500 psi high f/ 5 charted min each test. RD test equip. Install wear ring. Page 10/13 Report Printed: 10/31/2011 P I 0 N E E R •Perations Summary Report - Sta Well Name: ODSK -13 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud (Ib/gat) Summary 9/25/2011 9/26/2011 14,513.0 0.00 11.10 PU Baker storm valve retrieving tool and RIH (tag top 7" at 926'). Engage storm valve and screw into same. PU and release test packer per Baker Rep. Monitor well f/ 15 min - Static. POOH racking back 4" DP. LD storm valve and continue to POOH. LD test packer and continue to POOH t/616'. Cut & slip drilling line. LD BHA. Service rig. PU Baker RBP and RIH. SpotRBP at 9,160' (211' below 7" liner top). Drop 1/2" steel setting ball and pump down. No shear observed. Drop 1/2" aluminum setting ball and pump down. ** NOTE: AOGCC was given 24 hr. notice of upcoming BOP test. AOGCC Rep. Chuck Scheve waived right to witness at 10:30 hrs. on 09/25/2011. 9/26/2011 9/27/2011 14,513.0 0.00 11.10 Continue to attempt to pump ball on seat w/ 3 -8 bpm w/ no success. Drop 1 -1/4" teflon ball and pump down w/ 4 bpm, 550 psi. Slow to 3 bpm, 400 psi. Observe ball seat. Pressure up to 3000 psi to set RBP. PU w/ no overpull. Continue to PU t/9,133'. Close top rams. Pressure up to 1000 psi. Bleeding off. Repeat w/ same result. Bleed pressure. Set down 35k on RBP. PU t/9,133'. Close top rams and pressure up to 3500 psi. Bleeding off. Plug leaking. POOH f/9,133' t/ surface. RU to test BOPE. RD test equipment (AOGCC ruled 14 day test cycle applied to Tie Back Casing Repair Operations). Function test BOPE per AOGCC weekly requirement. MU Baker test packer w/ RBP retrieving tool below. RIH. Tag 7" casing stub at 890'. Attempt to enter 7" w/ no success. POOH and inspect packer elements. Packer was in set position. Reset and RIH t/9,103'. Spot test packer at 9,090' (140' below 7" liner top). Attempt to test RBP set at 9,160' to 3500 psi w/ no success. Close top rams and test annulus to 1000 psi f/ 10 charted min. Good test. Bleed annulus pressure to 750 psi and pump down DP to attempt 3500 psi test on RBP. RBP leaking. Release test packer per Baker Rep. Enagage RBP at 9,160' and shift bypass valve. Monitor well. Static. Release RBP. Monitor well. PU t19,150' and slack off t19,170' to verify RBP latched. POOH w/ test packer and RBP f19,170' 112,425'. 9/27/2011 9/28/2011 14,513.0 0.00 9.00 Continue POOH w/ test packer and RBP f/2,425' t/ surface. LD test packer & RBP. PU "G" set retrievable bridge plug and RIH 119,178'. Set packer at 9,180' (bottom). Top of packer at 9,166'. Center of element at 9,170'. Test packer to 1000 psi for 10 charted min. Good test. Reverse circulate and displace the well to 9.0 ppg viscosified seawater. Open rams. Monitor well. Static. Pump 20 bbls 11.2 ppg pill. Dump 850 lbs 20/40 silica sand down DP. POOH f /60' 1/9,110'. Pump sand down w/ 43 bbls 9.0 ppg seawater. RD and blow down lines. Wait on sand to fall. Attempt to tag. No tag. Pump 21 bbls at 2.5 bpm. No tag. Pump 21 bbls. work pipe. No tag. RU and reverse circ sand w/ 5 bpm, 1200 psi. Fill pit w/ 8.6 ppg seawater. Reverse circ and displace well to 8.6 ppg seawater. Dump 800 lbs 20/40 silica sand down DP and chase w/ 60 bbls seawater. Wait 30 min. Attempt to tag sand. No tag. Continue pumping in 4 bbls increments and working pipe 60' strokes until) DP volume pumped (93 bbls). Stop pumps and rotate 40 rpm working 90' strokes w/ no pump to assist sand in falling. 9/28/2011 9/29/2011 14,513.0 0.00 9.00 Rotate 40 rpm, 90' strokes and no pump to assist sand in falling. Tag sand at 9,131' (total 39' on top of packer). POOH 1/9,060'. RU to reverse circulate. Displace well f/ 8.6 ppg S.W. to 9.0 ppg viscosified seawater treated w/ 1 ppb "No -Surf' to treat probable sour mud on backside of 7" casing. POOH w/ "G" set running tool f/9,060' 11 surface. LD same. Pull wear ring. Install test plug and 7" test joint. Change top rams f/ variables to 7 ". Test 7" rams to 250 psi low / 4500 psi high f/ 5 charted min each test. RD test equip. Install wear ring. PU spear and packoff dressed for 7" 26#. PU remainder of fishing BHA and RIH. Tag and engage 7" casing stub at 890'. Tum pipe and torque to 8k ft/lbs (total of 244 tums). Pressure up to 500 psi. Pull seals from PBR w/ 215k up wt. Break circ w/ 1 bpm. Close rams, line up and circ through gas buster to remove any possible sour mud from 7" x 9 -5/8" annulus. Open rams and CBU x 1.5. Attempt to pull fish up hole. Observed 400k pull (175k over). Lower pipe and enter PBR w/ no issues. Pull up and pull pipe free w/ 275k. POOH w/ fish standing back DP & DC's. Release spear and LD same. Change T.D. IBOP to 4 -1/2" IF. 9/29/2011 9/30/2011 14,513.0 0.00 9.00 Attempt to test 4 -1/2' IF T.D. IBOP - Leaking. Remove backup wrench, stabbing guide, and IBOP /Saver sub. Rebuild IBOP. Install same. Reassemble T.D. Retest IBOP to 250 psi low / 4500 psi high for 5 charted min each test - Good test. Adjusting timing on IBOP actuator. RU Tesco casing tools. LD 199 joints of 7" casing and seal assembly (indexing muleshoe left in hole). Change IBOP / saver sub on Top Drive to 4" XT39. Test same to 250 psi low / 4500 psi high for 5 min on chart. Pull wear ring. Install test plug w/ 4" test joint. Change top rams from 7" to 2 -7/8' x 5" variables. Test top rams to 250 psi low / 4500 psi high for 5 charted min each test. RU to test rams and IBOP. Page 11/13 Report Printed: 10/31/2011 P I 0 N E E R Operations Summary Report - Statg Well Name: ODSK -13 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftK8) (ft) Mud (lb/gal) Summary 9/30/2011 10/1/2011 14,513.0 0.00 9.00 Test top 2 -7/8" x 5" variable rams and IBOP to 250 psi low / 4500 psi high for 5 charted min each test. Pull test plug. Install wear ring. PU Itco spear w/ 6.220' nominal catch grapple & 7-1/8" stop ring. PU bumper sub and jars. RIH w/ 9, 4 -3/4' DC's t/305'. RIH on 4" DP. Engage fish at 8,974' and POOH. LD fish and spear assembly. PU Polish mill assembly and RIH. Polish PBR and liner top. POOH 1/8,929'. Pump 60 bbls H.V. sweep around. 10/1/2011 10/2/2011 14,513.0 0.00 9.00 Continue pumping H.V. sweep to surface f18,929'. Cut & slip drilling line. Service rig. POOH f18,929' to surface. LD BHA. Pull wear ring. Install test plug. Change top rams from variables to 7 ". Test 7" rams to 250 psi low / 4500 psi high for 5 charted min each test. Change IBOP / saver sub f/ 4" XT -39 to 4 -1/2" IF. Change backup wrench and stabbing guide. Test T.D. IBOP to 250 psi low / 4500 psi high for 5 charted min each test. RU Tesco casing equipment. PU Weatherford seal assembly w/ indexing muleshoe and "hold down" sub. Install torque rings and drift same. Run 7" 26# L -80 tieback string f/ surface 1/4,629'. 10/2/2011 10/3/2011 14,513.0 0.00 9.00 Continue to run 7" 26# L -80 tieback casing. Sting seal assembly into PBR and no -go on top at 8,949'. PU to position seals in middle of PBR. Test 7" x 9 -5/8" x 11 -3/4" annulus to 3500 psi for 5 charted min (preliminary test). Space out and PU Vetco 7" casing hanger. Set Indexing Muleshoe at 8,947'. Close annular and pump 135 bbls diesel down annulus taking returns up 7" liner back to the rig pits. Strip through annular holding 400 psi back pressure with P -6 pump while stinging Seal Assy into Tie -back sleeve. Seals positioned f/8,955' 1/8,958'. Pressure test 11 -3/4" x 9 -5/8" x 7" annulus and seal assy to 3500 psi for 30 min. Good test. Pressure test 7" tie- back liner and seal assy to 3500 psi for 30 min. Good test. Hold down sub to set with 1200 psi. Attempted to pull 20k over last 7" string PU weight of 265k to check setting of hold down sub. At 260k PU weight liner /hold down sub moved 3' up hole. Slacked back down and reseated hanger in wellhead. Proceeded to repeat PU process to verify hold down sub moving; 2nd attempt hold down sub moved up hole 2'. DID NOT pull Seal Assy seals out of tie -back sleeve. Install 7" Pack - off and test seals to 5000 psi. f/ 10 charted min. Change TD lower IBOP from 4 -1/2 IF to 4" XT39. Change top rams to 2 -7/8" x 5" VBRs. Test top rams and IBOP to 250 psi low / 4500 psi high for 5 charted min each test. Install Wear Ring. PU Reverse Circulating Junk Basket BHA. RIH w/ RCJB BHA on 4" DP t/6,881'. *" AOGCC given notice of upcoming BOP test. AOGCC Rep. Bob Noble waived witness of test at 16:00 hrs on 10/02/11.*" 10/3/2011 10/4/2011 14,513.0 0.00 11.10 Continue to RIH w/ RCJB f/6,881' 1/9,095' (RIH w/ ball on seat). Tag sand at 9,123' - PU and rotate down w/ no pump at 60 rpm. Dry drill 2' into sand. PU 1/9,118' and engage pumps w/ 6 bpm, 1500 psi. Work RCJB f/9,118' 1/9,123' several times. Drop dart and shear open pump out sub w/ 950 psi. POOH f/9,118' 1/328' (BHA). LD BHA. Pull wear ring. Install Test plug. RU to test BOPE. Test BOPE per AOGCC PTD using 4" & 3 -1/2" test joints. -Test upper and lower variable rams to 250 psi low and 4500 psi high w/ 4" & 3 -1/2 ". -Test upper and lower IBOP valves to 250 psi low and 4500 psi high. -Test annular to 250 psi low and 2500 psi high w/ 4" & 3 -1/2 ". -Test all floor valves to 250 psi low and 4500 psi high. -Test 14 choke manifold valves to 250 psi low and 4500 psi high (while POOH). -All tests charted and all test held for 5 min. -Rig down test equipment. -Test witness waived by AOGCC Rep. Bob Noble at 16:00 hrs 10/02/11. - Initial system psi. 3000, 2000 after closure, 200 psi= 24 sec, full pressure 1 min. 54 sec. *Choke manifold valve #13 failed initially. Greased, cycled and retested - OK.* - Install wear ring. PU bridge plug retrieving tool. RIH 1/9,100'. Tag sand at 9,128'. Reverse circ sand out of hole f/9,128' 1/9,165' (top of BP). Open annular. Displace well from 9.0 ppg visc. brine to 11.1 ppg visc. brine. Continue to circulate hole clean w/ 11.1 ppg. brine. 10/4/2011 10/5/2011 14,513.0 0.00 11.10 Continue to circ sand out w/ 11.1 ppg viscosified brine. Release "G" set BP. Observe well. Static. Slack of past setting depth 1/9,190'. POOH f/9,190' 1/ surface. LD RBP and retrieving tool. Pull wear ring. RU to run ESP completion. PU ESP pump and motor assembly. Splice same. Run 3 1/2" ESP completion w/ 2 -7/8" jewelry f/ surface 1/2,344'. Page 12/13 Report Printed: 10/31/2011 P I 0 N E E R �Perations Summary Report - State Well Name: ODSK -13 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud (Ib /gal) Summary 10/5/2011 10/6/2011 14,513.0 0.00 11.10 RIH w/ 3 1/2" L -80 9.2# BTC -M completion f/2,344' t/7,357'. Make up WFT Hydrow II packer with G.V.V. Test top of G.V.V. to 4000 psi for 10 min - Good test. Test bottom of G.V.V. to 3500 psi for 10 min - Good test. Cut ESP cable and run through packer body. Make ESP connection to packer and test same - Good test. RIH w/ 3 -1/2" L -80 9.2# BTC -M completion f/7,357' 1/10,000'. MU hanger and orient same. Make ESP, G.V.V. and SSSV control line penetrations through hanger. Splice same to monitor while landing. 10/6/2011 10/7/2011 14,513.0 0.00 11.10 Make ESP, G.V.V. and SSSV control line penetrations through hanger. Maintain 4000 psi on SSSV and 1000 psi on G.V.V. control lines - test ESP cable - Good test. Land hanger f /10,000' 1/10,043'. Test upper and lower hanger seals to 5000 psi held 10 min on chart - Good test. RU slick line unit and lubricator - test same to 300 psi - Good test. RIH with roller ball bar rod 1/9,716'. POOH - Did not shear off of roller ball bar rod. Redress ball bar rod, drop same, and pump down at 1 bpm - Ball on seat with 800 psi. RU lines to tubing and IA - test lines to 3500 psi. Pressure up on tubing to 3500 psi to set packer. Test tubing to 3500 psi - held 30 min on chart - Good test. Bleed tubing to 1000 psi, test IA to 2750 psi - held 30 min on chart - Good test. Bleed tubing to 0 psi to activate shear valve in GLM #1. Pressure test down IA thru the shear valve to test the SSSV. Tested to 1000 psi held 10 min on chart - Good test. Pull landing joint and install BPV in tubing hanger. RD all tubing equipment. Prep BOPE for inspection, remove RCD bowl, remove all rams, remove wing valves, and break down BOPE sections. 10/7/2011 10/8/2011 14,513.0 0.00 11.10 Trouble shoot and repair BOPE bridge crane. Nipple down BOPE. Make control line terminations thru wellhead and test SSSV control line to 5000 psi held 10 min - Good test. Test G.V.V. control line to 4000 psi held 10 min - Good test. Install and NU production tree. Test tree and voids to 5000 psi held 15 min on chart - Good test. LD 345 joints of 4" DP from derrick using mouse hole. RD rig floor, pipe skate, and blow down rig in preparation for rig move. RIG RELEASED AT 11:59 HRS ON 10/07/11 Page 13/13 Report Printed: 10/31/2011 • • ODSK -13 Ivik Fault Block Kuparuk Production Well Casing Item # Item MD (ft) TVD (ft) A 16" Conductor 158 158 B 11 -3/4" 60# L -80 Hydril 521, 10.772" ID 3,513 2,949 C 9 -5/8" 40# L -80 Hydril 521, 8.835" ID* 9,098 5,423 Well Head: 11 - 3/4 ", 5K, VetcoGray D 7" 26# L -80 BTC -M, 6.276" ID Tie -Back 8,961 5,350 Tree: 3 - 1/2 ", 5K, Horizontal E 7" 26# L -80 Hydril 511, 6.276" ID Liner 11,428 6,182 F 4 -1/2" 12.6# IBT -M Slotted 3.958" ID w/ torque rings 14,511 6,251 L 0 G 3 - 1/2" 9.3# L -80 IBT -M x 2 -7/8" 6.4# IBT -M 10,043 5,881 O Upper Completion Item # Item MDrkb (ft) TVDrkb (ft) g 1 VetcoGray Tubing Hanger 34 34 3 -1/2" 9.2# L -80 IBT -Mod Pup Joint Pin x Pin 3 -1/2" 9.2# L -80 IBT -Mod Tubing © 3 -1/2" IBT -Mod Box x 2 -7/8" IBT -Mod Pin 2 2 -7/8" Wellstar Tubing Retreivable ScSSSV 1,994 1,918 2 -7/8" IBT -Mod Box x 3 -1/2" IBT -Mod Pin . l♦1 . ai 3 -1/2" 9.2# L -80 IBT -Mod Tubing ai l O 3- 3 -1/2" IBT -Mod Box x 2 -7/8" IBT -Mod Pin IN CAI 3 GLM #1 - 2 -7/8" x 1 -1/2" w DCK Shear Valve 2,534 2,379 $3 ;, 2 -7/8" 6.4# L -80 IBT -Mod Tubing 4 2 -7/8" X Nipple 2.313" I.D. 2,587 2,420 © -1 2 -7/8" 6.4# L -80 IBT -Mod Tubing ' 5 WFT 7" x 2 -7/8" Gas Vent Valve Packer 2,660 2,474 J 2 -7/8" 6.4# L -80 IBT -Mod Tubing 0 D 6 GLM #2 - 2 -7/8" x 1 -1/2" (min. 1 jt below packer) 2,728 2,522 2 -7/8" IBT -Mod Box x 3 -1/2" IBT -Mod Pin 3 -1/2" 9.2# L -80 IBT -Mod Tubing IO • 7.44 3 -1/2" IBT -Mod Box x 2 -7/8" IBT -Mod Pin © 7 GLM #3 - 2 -7/8" x 1 -1/2" (min. 2 jts above X nipple) 9,633 5,698 s 2 -7/8" 6.4# L -80 IBT -Mod Tubing o 8 2 -7/8" X Nipple, 2.313" ID w/ RHC -M Plug Body 9,710 5,734 2 -7/8" 6.4# L -80 IBT -Mod Tubing 9 Automatic Divert Valve (ADV) 9,963 5,846 10 10 ESP (Pump, Motor, and Jewelry) 9,968 5,848 End of Assembly 10,043 5,881 Lower Completion Item # Item MD (ft) TVD (ft) 11 WFT PBR Tie Back Sleeve 15ft 11,283 6,174 12 WFT "NTH" Liner Top Pkr 11,299 6,175 • 13 WFT "PHR" Rotating Hyd Set Liner Hanger 11,302 6,175 14 4 -1/2" 12.6# L -80 IBT -M Slotted Liner w/ torque rings ■ g& A 15 WFT Eccentric Solid Alum Shoe 14,510 6,251 1 End of Assembly 14,511 6,251 4£ 14 15 • O O n I 0 N E E R Date: Revision By: Comments ODSK -13 Producer Well Schematic AOGCC Copy NATURAL. RESOURCES ALASKA • rr- Well Planning - Pioneer - Oooguruk Oooguruk Development • Oooguruk Drill Site ODSK-13 • - Sperry Drilling Services Definitive Survey Report 22 September, 2011 „.! [ • r, r L”. `.:•• 1 HALLIBURTON Sperry Drilling Services 0 Pioneer Natural Resources 0 Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co-ordinate Reference: Well ODSK -13 - Slot ODS -13 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -13 North Reference: True Wellbore: ODSK -13 Survey Calculation Method: Minimum Curvature Design: ODSK -13 Database: EDM Project Oooguruk Development 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 Well ODSK -13 - Slot ODS -13 Well Position +N /-S 0.00 ft Northing: 6,031,076.06 ft Latitude: 70° 29' 45.498 N +E/-W 0.00 ft Easting: 469,845.81 ft Longitude: 150° 14' 47.653 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft Wellbore ODSK -13 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) ( ?) (nT) User Defined 7/27/2011 20.82 80.97 57,639 Design ODSK -13 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,067.50 Vertical Section: Depth From (TVD) +N / -S +E/ -W Direction (ft) (ft) (ft) ( ?) 42.70 0.00 0.00 349.42 Survey Program Date 9/22/2011 From To Survey (ft) (ft) Survey (Wellbore) Tool Name Description Start Date 100.00 532.00 ODSK -13 Gyro (ODSK- 13PB1) SR- Gyro -SS Fixed:v2:surface readout gyro single shot 01/04/2010 573.71 3,468.28 ODSK -13 MWD (ODSK- 13PB1) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 01/04/2010 3,512.00 4,188.14 ODSK -13PB2 MWD Run 600 (ODSK -13 MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 08/11/2011 4,249.10 9,067.50 ODSK -13PB2 MWD Run 700 (ODSK -13 MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 08/25/2011 9,098.00 11,397.45 ODSK -13 MWD Run 1100 (ODSK -13) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 08/30/2011 11,459.07 14,447.61 ODSK -13 MWD Run 1300 (ODSK -13) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 09/22/2011 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E / -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) (° /100') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,076.06 469,845.81 0.00 0.00 UNDEFINED 100.00 0.34 221.19 100.00 43.80 -0.13 -0.11 6,031,075.93 469,845.70 0.59 -0.11 SR- Gyro -SS (1) 168.00 0.16 130.95 168.00 111.80 -0.34 -0.17 6,031,075.72 469,845.63 0.55 -0.30 SR- Gyro -SS (1) 259.00 0.70 164.84 259.00 202.80 -0.96 0.07 6,031,075.10 469,845.87 0.63 -0.96 SR- Gyro -SS (1) 350.00 0.37 253.30 349.99 293.79 -1.58 -0.07 6,031,074.48 469,845.73 0.86 -1.54 SR- Gyro -SS (1) 441.00 1.19 307.31 440.99 384.79 -1.09 -1.10 6,031,074.97 469,844.70 1.12 -0.87 SR- Gyro -SS (1) 532.00 1.95 322.83 531.95 475.75 0.71 -2.79 6,031,076.78 469,843.02 0.95 1.21 SR- Gyro -SS (1) 573.71 1.85 317.80 573.64 517.44 1.78 -3.67 6,031,077.85 469,842.15 0.47 2.42 MWD +IFR2 +MS +sag (2) 626.58 3.17 315.66 626.46 570.26 3.45 -5.26 6,031,079.54 469,840.56 2.50 4.36 MWD +IFR2 +MS +sag (2) 671.26 4.30 316.56 671.04 614.84 5.55 -7.28 6,031,081.64 469,838.55 2.53 6.80 MWD +IFR2 +MS +sag (2) 9/222011 2:59:36PM Page 2 COMPASS 2003.16 Build 42 . , • Pioneer Natural Resources 0 Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -13 - Slot ODS -13 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5 © 56.20ft (Nabors 19AC) Well: ODSK -13 North Reference: True Welibore: ODSK -13 Survey Calculation Method: Minimum Curvature Design: ODSK -13 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N /-S +El -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °l100') (ft) Survey Tool Name 763.81 6.86 316.45 763.14 706.94 12.08 -13.47 6,031,088.19 469,832.39 2.77 14.35 MWD +IFR2 +MS +sag (2) 813.54 8.01 316.35 812.46 756.26 16.74 -17.91 6,031,092.87 469,827.97 2.31 19.74 MWD +IFR2 +MS +sag (2) 860.24 8.60 315.98 858.67 802.47 21.61 -22.59 6,031,097.76 469,823.31 1.27 25.38 MWD +IFR2 +MS +sag (2) 909.76 9.51 313.90 907.57 851.37 27.11 -28.11 6,031,103.28 469,817.82 1.95 31.80 MWD +IFR2 +MS +sag (2) 956.78 9.35 312.67 953.95 897.75 32.39 -33.71 6,031,108.58 469,812.23 0.55 38.03 MWD +IFR2 +MS +sag (2) 1,005.95 9.18 310.28 1,002.48 946.28 37.63 -39.64 6,031,113.85 469,806.32 0.86 44.27 MWD +IFR2 +MS +sag (2) 1,049.84 11.17 311.64 1,045.68 989.48 42.72 -45.49 6,031,118.96 469,800.50 4.57 50.34 MWD +IFR2 +MS +sag (2) 1,096.33 13.93 309.80 1,091.05 1,034.85 49.29 -53.16 6,031,125.56 469,792.86 6.00 58.22 MWD +IFR2 +MS +sag (2) 1,145.56 15.24 312.60 1,138.70 1,082.50 57.47 -62.47 6,031,133.77 469,783.58 3.02 67.96 MWD +IFR2 +MS +sag (2) 1,194.22 15.31 310.88 1,185.64 1,129.44 66.00 -72.04 6,031,142.35 469,774.05 0.94 78.10 MWD +IFR2 +MS +sag (2) 1,240.56 16.78 310.92 1,230.17 1,173.97 74.39 -81.72 6,031,150.77 469,764.40 3.17 88.13 MWD +IFR2 +MS +sag (2) 1,289.96 18.95 309.46 1,277.19 1,220.99 84.16 -93.30 6,031,160.59 469,752.86 4.48 99.86 MWD +IFR2 +MS +sag (2) 1,336.79 20.72 308.92 1,321.24 1,265.04 94.19 - 105.62 6,031,170.67 469,740.59 3.80 111.98 MWD +IFR2 +MS +sag (2) 1,384.42 22.51 306.84 1,365.52 1,309.32 104.96 - 119.47 6,031,181.49 469,726.78 4.09 125.11 MWD +IFR2 +MS +sag (2) 1,430.42 23.07 305.99 1,407.93 1,351.73 115.53 - 133.81 6,031,192.12 469,712.48 1.41 138.14 MWD +IFR2 +MS +sag (2) 1,479.83 23.39 304.58 1,453.33 1,397.13 126.79 - 149.72 6,031,203.44 469,696.62 1.30 152.12 MWD +IFR2 +MS +sag (2) 1,525.32 23.94 305.15 1,494.99 1,438.79 137.23 - 164.70 6,031,213.94 469,681.68 1.31 165.13 MWD +IFR2 +MS +sag (2) 1,576.16 24.01 305.92 1,541.45 1,485.25 149.23 - 181.51 6,031,226.01 469,664.92 0.63 180.02 MWD +IFR2 +MS +sag (2) 1,621.34 24.33 306.96 1,582.67 1,526.47 160.22 - 196.39 6,031,237.06 469,650.09 1.18 193.55 MWD +IFR2 +MS +sag (2) 1,671.07 25.79 307.41 1,627.72 1,571.52 172.95 - 213.17 6,031,249.86 469,633.36 2.96 209.15 MWD +IFR2 +MS +sag (2) 1,705.60 25.58 308.15 1,658.83 1,602.63 182.12 - 225.00 6,031,259.07 469,621.57 1.11 220.34 MWD +IFR2 +MS +sag (2) 1,766.84 25.73 308.07 1,714.04 1,657.84 198.48 - 245.86 6,031,275.52 469,600.78 0.25 240.25 MWD +IFR2 +MS +sag (2) 1,811.68 25.57 310.02 1,754.46 1,698.26 210.71 - 260.93 6,031,287.80 469,585.76 1.92 255.04 MWD +IFR2 +MS +sag (2) 1,862.23 25.52 312.44 1,800.07 1,743.87 225.07 - 277.33 6,031,302.23 469,569.43 2.07 272.16 MWD +IFR2 +MS +sag (2) 1,907.09 25.51 313.53 1,840.55 1,784.35 238.25 - 291.46 6,031,315.46 469,555.35 1.05 287.71 MWD +IFR2 +MS +sa 2 9O 1,958.99 26.92 315.00 1,887.11 1,830.91 254.25 - 307.87 6,031,331.53 469,539.00 2.99 306.46 MWD +IFR2 +MS +sag (2) 2,001.97 27.61 317.15 1,925.32 1,869.12 268.43 - 321.53 6,031,345.77 469,525.41 2.80 322.90 MWD +IFR2 +MS +sag (2) 2,097.12 28.74 323.48 2,009.21 1,953.01 302.99 - 350.14 6,031,380.44 469,496.94 3.36 362.13 MWD +IFR2 +MS +sag (2) 2,192.69 29.36 331.16 2,092.79 2,036.59 341.99 - 375.13 6,031,419.54 469,472.11 3.95 405.06 MWD +IFR2 +MS +sag (2) 2,241.25 29.14 334.14 2,135.16 2,078.96 363.06 - 386.02 6,031,440.65 469,461.30 3.03 427.77 MWD +IFR2 +MS +sag (2) 2,287.81 29.36 334.80 2,175.78 2,119.58 383.59 - 395.83 6,031,461.22 469,451.58 0.84 449.75 MWD +IFR2 +MS +sag (2) 2,383.06 33.63 338.04 2,256.99 2,200.79 429.21 - 415.65 6,031,506.91 469,431.95 4.82 498.22 MWD +IFR2 +MS +sag (2) 2,477.86 36.61 342.39 2,334.53 2,278.33 480.52 - 434.02 6,031,558.28 469,413.78 4.10 552.04 MWD +IFR2 +MS +sag (2) 2,530.79 38.32 345.12 2,376.55 2,320.35 511.42 - 443.01 6,031,589.22 469,404.92 4.50 584.07 MWD +IFR2 +MS +sag (2) 2,572.80 40.97 347.17 2,408.89 2,352.69 537.44 - 449.42 6,031,615.27 469,398.62 7.03 610.82 MWD +IFR2 +MS +sag (2) 2,619.68 42.07 349.45 2,444.00 2,387.80 567.87 - 455.70 6,031,645.72 469,392.46 3.99 641.89 MWD +IFR2 +MS +sag (2) 2,668.18 44.23 350.62 2,479.38 2,423.18 600.54 - 461.44 6,031,678.41 469,386.86 4.75 675.05 MWD +IFR2 +MS +sag (2) 2,763.56 46.77 352.08 2,546.23 2,490.03 667.79 - 471.65 6,031,745.69 469,376.92 2.88 743.03 MWD +IFR2 +MS +sag (2) 2,857.18 49.32 354.88 2,608.82 2,552.62 736.95 - 479.52 6,031,814.87 469,369.33 3.52 812.46 MWD +IFR2 +MS +sag (2) 2,953.56 52.79 357.15 2,669.40 2,613.20 811.71 - 484.69 6,031,889.64 469,364.47 4.04 886.90 MWD +IFR2 +MS +sag (2) 9/222011 2:59:36PM Page 3 COMPASS 2003.16 Build 42 • Pioneer Natural Resources Definitive Survey Report - Oooguruk Company: Well Planning Pioneer Ooogu u Local Co- ordinate Reference: Well ODSK -13 - Slot ODS -13 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -13 North Reference: True Wellbore: ODSK -13 Survey Calculation Method: Minimum Curvature Design: ODSK -13 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +N /-S +E / -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °11001 (ft) Survey Tool Name 3,048.04 54.50 358.46 2,725.40 2,669.20 887.74 - 487.59 6,031,965.68 469,361.87 2.13 962.17 MWD +IFR2 +MS +sag (2) 3,143.06 57.30 358.73 2,778.67 2,722.47 966.39 - 489.52 6,032,044.33 469,360.26 2.96 1,039.84 MWD +IFR2 +MS +sag (2) 3,239.01 61.30 359.87 2,827.65 2,771.45 1,048.87 - 490.51 6,032,126.80 469,359.61 4.29 1,121.10 MWD +IFR2 +MS +sag (2) 3,332.55 64.45 1.07 2,870.29 2,814.09 1,132.10 - 489.82 6,032,210.02 469,360.64 3.56 1,202.79 MWD +IFR2 +MS +sag (2) 3,429.23 64.20 1.45 2,912.18 2,855.98 1,219.21 - 487.90 6,032,297.12 469,362.91 0.44 1,288.07 MWD +IFR2 +MS +sag (2) 3,468.28 63.59 2.08 2,929.36 2,873.16 1,254.26 - 486.82 6,032,332.16 469,364.13 2.13 1,322.32 MWD +IFR2 +MS +sag (2) 3,512.00 63.49 2.41 2,948.84 2,892.64 1,293.37 - 485.29 6,032,371.26 469,365.82 0.71 1,360.49 MWD +IFR2 +MS +sag (3) 3,555.33 62.03 1.18 2,968.67 2,912.47 1,331.88 - 484.08 6,032,409.76 469,367.19 4.21 1,398.11 MWD +IFR2 +MS +sag (3) 3,616.51 64.15 2.52 2,996.36 2,940.16 1,386.40 - 482.31 6,032,464.26 469,369.17 3.98 1,451.39 MWD +IFR2 +MS +sag (3) 3,665.79 64.07 1.46 3,017.88 2,961.68 1,430.71 - 480.77 6,032,508.56 469,370.89 1.94 1,494.66 MWD +IFR2 +MS +sag (3) 3,712.23 63.29 1.97 3,038.47 2,982.27 1,472.31 - 479.53 6,032,550.16 469,372.31 1.95 1,535.33 MWD +IFR2 +MS +sag (3) 3,807.59 63.18 1.37 3,081.42 3,025.22 1,557.42 - 477.05 6,032,635.24 469,375.13 0.57 1,618.53 MWD +IFR2 +MS +sag (3) 3,902.42 63.18 1.51 3,124.20 3,068.00 1,642.02 - 474.92 6,032,719.83 469,377.60 0.13 1,701.30 MWD +IFR2 +MS +sag (3) 3,997.88 62.71 0.22 3,167.62 3,111.42 1,727.02 - 473.63 6,032,804.81 469,379.23 1.30 1,784.62 MWD +IFR2 +MS +sag (3) 4,093.20 62.04 359.94 3,211.82 3,155.62 1,811.48 - 473.51 6,032,889.26 469,379.69 0.75 1,867.62 MWD +IFR2 +MS +sag (3) 4,188.14 63.53 0.20 3,255.24 3,199.04 1,895.90 - 473.41 6,032,973.68 469,380.14 1.59 1,950.59 MWD +IFR2 +MS +sag (3) 4,249.10 63.12 0.16 3,282.61 3,226.41 1,950.37 - 473.24 6,033,028.14 469,380.53 0.68 2,004.11 MWD +IFR2 +MS +sag (4) 4,342.75 62.39 1.86 3,325.48 3,269.28 2,033.62 - 471.78 6,033,111.37 469,382.33 1.79 2,085.67 MWD +IFR2 +MS +sag (4) 4,439.42 63.41 7.57 3,369.55 3,313.35 2,119.33 - 464.69 6,033,197.04 469,389.77 5.36 2,168.62 MWD +IFR2 +MS +sag (4) 4,534.56 63.63 10.80 3,411.98 3,355.78 2,203.38 - 451.09 6,033,281.03 469,403.70 3.05 2,248.75 MWD +IFR2 +MS +sag (4) 4,629.62 63.38 14.09 3,454.39 3,398.19 2,286.44 - 432.77 6,033,364.01 469,422.37 3.11 2,327.03 MWD +IFR2 +MS +sag (4) 4,721.64 63.48 17.57 3,495.56 3,439.36 2,365.60 - 410.32 6,033,443.07 469,445.13 3.38 2,400.73 MWD +IFR2 +MS +sag (4) 4,818.91 63.26 20.75 3,539.17 3,482.97 2,447.73 - 381.79 6,033,525.07 469,473.99 2.93 2,476.21 MWD +IFR2 +MS +sag (4) 4,911.96 63.66 24.62 3,580.76 3,524.56 2,524.51 - 349.69 6,033,601.71 469,506.40 3.75 2,545.79 MWD +IFR2 +MS +sag (4) 5,007.94 63.69 27.95 3,623.33 3,567.13 2,601.62 - 311.60 6,033,678.66 469,544.80 3.11 2,614.61 MWD +IFR2 +MS +sag (4) 5,103.05 63.87 30.03 3,665.36 3,609.16 2,676.25 - 270.25 6,033,753.11 469,586.45 1.97 2,680.37 MWD +IFR2 +MS +sag (4) 5,198.48 63.74 31.88 3,707.49 3,651.29 2,749.68 - 226.21 6,033,826.36 469,630.78 1.74 2,744.47 MWD +IFR2 +MS +sag (4) 5,293.95 64.38 34.93 3,749.26 3,693.06 2,821.33 - 178.94 6,033,897.81 469,678.33 2.95 2,806.22 MWD +IFR2 +MS +sag (4) 5,388.05 64.77 37.53 3,789.66 3,733.46 2,889.88 - 128.72 6,033,966.14 469,728.83 2.53 2,864.38 MWD +IFR2 +MS +sag (4) 5,483.36 65.50 39.43 3,829.74 3,773.54 2,957.56 -74.91 6,034,033.61 469,782.90 1.96 2,921.04 MWD +IFR2 +MS +sag (4) 5,579.29 66.01 42.51 3,869.14 3,812.94 3,023.59 -17.57 6,034,099.40 469,840.51 2.98 2,975.42 MWD +IFR2 +MS +sag (4) 5,673.51 65.72 44.70 3,907.67 3,851.47 3,085.85 41.73 6,034,161.41 469,900.05 2.14 3,025.73 MWD +IFR2 +MS +sag (4) 5,768.88 65.19 47.30 3,947.29 3,891.09 3,146.11 104.12 6,034,221.41 469,962.68 2.54 3,073.51 MWD +IFR2 +MS +sag (4) 5,863.95 66.34 49.90 3,986.32 3,930.12 3,203.43 169.15 6,034,278.45 470,027.93 2.77 3,117.91 MWD +IFR2 +MS +sag (4) 5,959.06 67.46 51.77 4,023.64 3,967.44 3,258.67 236.98 6,034,333.41 470,095.98 2.16 3,159.76 MWD +IFR2 +MS +sag (4) 6,054.68 67.35 52.31 4,060.38 4,004.18 3,312.97 306.58 6,034,387.43 470,165.79 0.53 3,200.36 MWD +IFR2 +MS +sag (4) 6,149.01 67.62 52.84 4,096.50 4,040.30 3,365.93 375.78 6,034,440.10 470,235.20 0.59 3,239.71 MWD +IFR2 +MS +sag (4) 6,244.58 67.61 52.94 4,132.90 4,076.70 3,419.24 446.25 6,034,493.12 470,305.88 0.10 3,279.18 MWD +IFR2 +MS +sag (4) 6,339.78 67.33 52.56 4,169.37 4,113.17 3,472.47 516.25 6,034,546.06 470,376.09 0.47 3,318.65 MWD +IFR2 +MS +sag (4) 6,433.33 67.79 51.93 4,205.08 4,148.88 3,525.41 584.61 6,034,598.72 470,444.66 0.79 3,358.14 MWD +IFR2 +MS +sag (4) 9/22/2011 2:59:36PM Page 4 COMPASS 2003.16 Build 42 • Pioneer Natural Resources Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -13 - Slot ODS -13 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -13 North Reference: True Welibore: ODSK -13 Survey Calculation Method: Minimum Curvature Design: ODSK -13 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N /-S +El -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 6,499.89 68.02 51.58 4,230.12 4,173.92 3,563.59 633.05 6,034,636.69 470,493.24 0.60 3,386.77 MWD +IFR2 +MS +sag (4) 6,529.96 67.69 51.89 4,241.46 4,185.26 3,580.84 654.91 6,034,653.85 470,515.18 1.45 3,399.71 MWD +IFR2 +MS +sag (4) 6,625.13 66.73 51.49 4,278.32 4,222.12 3,635.23 723.76 6,034,707.96 470,584.24 1.08 3,440.54 MWD +IFR2 +MS +sag (4) 6,720.41 67.39 51.27 4,315.46 4,259.26 3,689.99 792.32 6,034,762.44 470,653.01 0.72 3,481.79 MWD +IFR2 +MS +sag (4) 6,813.96 67.62 51.79 4,351.25 4,295.05 3,743.76 859.99 6,034,815.93 470,720.89 0.57 3,522.22 MWD +IFR2 +MS +sag (4) 6,910.56 67.95 51.12 4,387.77 4,331.57 3,799.49 929.93 6,034,871.36 470,791.05 0.73 3,564.15 MWD +IFR2 +MS +sag (4) 7,005.87 67.72 50.71 4,423.73 4,367.53 3,855.14 998.44 6,034,926.73 470,859.78 0.47 3,606.28 MWD +IFR2 +MS +sag (4) 7,099.81 67.81 50.30 4,459.28 4,403.08 3,910.44 1,065.54 6,034,981.75 470,927.10 0.42 3,648.32 MWD +IFR2 +MS +sag (4) 7,194.84 67.46 49.70 4,495.44 4,439.24 3,966.93 1,132.87 6,035,037.96 470,994.64 0.69 3,691.49 MWD +IFR2 +MS +sag (4) 7,290.27 66.41 47.24 4,532.83 4,476.63 4,025.13 1,198.59 6,035,095.89 471,060.60 2.61 3,736.63 MWD +IFR2 +MS +sag (4) 7,385.79 65.53 45.76 4,571.73 4,515.53 4,085.18 1,261.87 6,035,155.68 471,124.12 1.69 3,784.04 MWD +IFR2 +MS +sag (4) 7,480.76 64.78 43.46 4,611.64 4,555.44 4,146.52 1,322.39 6,035,216.77 471,184.88 2.34 3,833.23 MWD +IFR2 +MS +sag (4) 7,577.09 64.17 41.66 4,653.15 4,596.95 4,210.54 1,381.19 6,035,280.54 471,243.93 1.80 3,885.36 MWD +IFR2 +MS +sag (4) 7,671.10 62.47 40.38 4,695.36 4,639.16 4,273.91 1,436.32 6,035,343.68 471,299.31 2.18 3,937.53 MWD +IFR2 +MS +sag (4) 7,766.33 61.94 38.93 4,739.77 4,683.57 4,338.77 1,490.08 6,035,408.31 471,353.33 1.46 3,991.41 MWD +IFR2 +MS +sag (4) 7,862.27 61.80 36.99 4,785.00 4,728.80 4,405.47 1,542.12 6,035,474.79 471,405.63 1.79 4,047.43 MWD +IFR2 +MS +sag (4) 7,957.08 61.46 34.26 4,830.06 4,773.86 4,473.27 1,590.71 6,035,542.39 471,454.49 2.56 4,105.15 MWD +IFR2 +MS +sag (4) 8,052.55 59.95 31.28 4,876.78 4,820.58 4,543.26 1,635.78 6,035,612.18 471,499.84 3.15 4,165.67 MWD +IFR2 +MS +sag (4) 8,148.21 59.28 28.61 4,925.17 4,868.97 4,614.75 1,676.97 6,035,683.50 471,541.32 2.51 4,228.39 MWD +IFR2 +MS +sag (4) 8,241.73 59.42 26.12 4,972.85 4,916.65 4,686.19 1,713.95 6,035,754.79 471,578.58 2.30 4,291.83 MWD +IFR2 +MS +sag (4) 8,336.89 58.89 23.40 5,021.65 4,965.45 4,760.37 1,748.17 6,035,828.82 471,613.09 2.52 4,358.46 MWD+IFR2+MS+sag 4 9O 8,432.34 58.45 20.01 5,071.29 5,015.09 4,836.10 1,778.32 6,035,904.42 471,643.55 3.07 4,427.37 MWD +IFR2 +MS +sag (4) 8,527.43 58.16 16.73 5,121.26 5,065.06 4,912.87 1,803.81 6,035,981.07 471,669.35 2.95 4,498.15 MWD +IFR2 +MS +sag (4) 8,622.99 58.31 13.78 5,171.58 5,115.38 4,991.24 1,825.19 6,036,059.35 471,691.04 2.63 4,571.26 MWD +IFR2 +MS +sag (4) 8,718.51 58.61 9.62 5,221.56 5,165.36 5,070.93 1,841.68 6,036,138.96 471,707.86 3.72 4,646.57 MWD +IFR2 +MS +sag (4) 8,812.82 57.91 5.46 5,271.19 5,214.99 5,150.41 1,852.22 6,036,218.40 471,718.71 3.82 4,722.77 MWD +IFR2 +MS +sag (4) 8,908.88 57.88 1.43 5,322.25 5,266.05 5,231.61 1,857.10 6,036,299.56 471,723.93 3.55 4,801.69 MWD +IFR2 +MS +sag (4) 9,003.97 57.75 357.12 5,372.92 5,316.72 5,312.05 1,856.09 6,036,380.00 471,723.24 3.84 4,880.95 MWD +IFR2 +MS +sag (4) 9,067.50 57.73 356.42 5,406.83 5,350.63 5,365.69 1,853.06 6,036,433.65 471,720.43 0.93 4,934.23 MWD +IFR2 +MS +sag (4) 9,098.00 57.47 356.71 5,423.17 5,366.97 5,391.39 1,851.52 6,036,459.35 471,718.99 1.17 4,959.78 MWD +IFR2 +MS +sag (5) 9,183.61 56.59 355.97 5,469.76 5,413.56 5,463.07 1,846.94 6,036,531.04 471,714.70 1.26 5,031.08 MWD +IFR2 +MS +sag (5) 9,278.09 58.50 353.68 5,520.47 5,464.27 5,542.45 1,839.73 6,036,610.45 471,707.82 2.88 5,110.44 MWD +IFR2 +MS +sag (5) 9,372.49 58.87 354.44 5,569.53 5,513.33 5,622.67 1,831.38 6,036,690.68 471,699.80 0.79 5,190.82 MWD +IFR2 +MS +sag (5) 9,467.98 59.84 354.47 5,618.20 5,562.00 5,704.44 1,823.45 6,036,772.48 471,692.20 1.02 5,272.66 MWD +IFR2 +MS +sag (5) 9,563.17 61.25 352.27 5,665.02 5,608.82 5,786.76 1,813.87 6,036,854.83 471,682.95 2.50 5,355.34 MWD +IFR2 +MS +sag (5) 9,658.60 62.02 349.54 5,710.36 5,654.16 5,869.66 1,800.59 6,036,937.78 471,670.01 2.64 5,439.27 MWD +IFR2 +MS +sag (5) 9,754.27 63.48 348.02 5,754.17 5,697.97 5,953.08 1,784.03 6,037,021.25 471,653.79 2.08 5,524.31 MWD +IFR2 +MS +sag (5) 9,849.34 64.04 346.62 5,796.20 5,740.00 6,036.27 1,765.31 6,037,104.51 471,635.41 1.45 5,609.52 MWD +IFR2 +MS +sag (5) 9,945.34 64.02 345.67 5,838.24 5,782.04 6,120.06 1,744.65 6,037,188.38 471,615.09 0.89 5,695.69 MWD +IFR2 +MS +sag (5) 10,040.82 64.35 344.89 5,879.82 5,823.62 6,203.19 1,722.80 6,037,271.59 471,593.59 0.81 5,781.41 MWD +IFR2 +MS +sag (5) 9/22/2011 2:59:36PM Page 5 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -13 - Slot ODS -13 Project: Oooguruk Development TVD Reference: 42.7 + 13.5' © 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7 + 13.5' © 56.20ft (Nabors 19AC) Well: ODSK -13 North Reference: True Weilbore: ODSK -13 Survey Calculation Method: Minimum Curvature Design: ODSK -13 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N /-S +E/ -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 10,135.81 65.57 342.15 5,920.03 5,863.83 6,285.70 1,698.38 6,037,354.19 471,569.51 2.91 5,867.01 MWD +IFR2 +MS +sag (5) 10,230.64 68.36 340.50 5,957.13 5,900.93 6,368.36 1,670.43 6,037,436.95 471,541.89 3.35 5,953.39 MWD +IFR2 +MS +sag (5) 10,324.60 71.31 338.73 5,989.52 5,933.32 6,451.02 1,639.70 6,037,519.73 471,511.50 3.60 6,040.29 MWD +IFR2 +MS +sag (5) 10,419.20 72.66 336.09 6,018.78 5,962.58 6,534.07 1,605.14 6,037,602.90 471,477.28 3.01 6,128.27 MWD +IFR2 +MS +sag (5) 10,515.14 73.63 333.73 6,046.60 5,990.40 6,617.21 1,566.21 6,037,686.20 471,438.69 2.56 6,217.15 MWD +IFR2 +MS +sag (5) 10,609.34 75.12 331.32 6,071.98 6,015.78 6,697.69 1,524.35 6,037,766.83 471,397.16 2.93 6,303.94 MWD +IFR2 +MS +sag (5) 10,704.81 76.95 328.62 6,095.02 6,038.82 6,777.88 1,477.98 6,037,847.21 471,351.13 3.35 6,391.28 MWD +IFR2 +MS +sag (5) 10,799.78 79.03 326.84 6,114.78 6,058.58 6,856.42 1,428.39 6,037,925.93 471,301.85 2.86 6,477.59 MWD +IFR2 +MS +sag (5) 10,895.18 80.98 326.67 6,131.34 6,075.14 6,934.99 1,376.88 6,038,004.70 471,250.67 2.05 6,564.28 MWD +IFR2 +MS +sag (5) 10,990.23 82.48 325.46 6,145.01 6,088.81 7,013.02 1,324.38 6,038,082.94 471,198.49 2.02 6,650.63 MWD +IFR2 +MS +sag (5) 11,085.22 83.48 324.04 6,156.62 6,100.42 7,090.01 1,269.96 6,038,160.14 471,144.39 1.82 6,736.30 MWD +IFR2 +MS +sag (5) 11,180.95 85.15 322.75 6,166.11 6,109.91 7,166.48 1,213.16 6,038,236.83 471,087.91 2.20 6,821.89 MWD +IFR2 +MS +sag (5) 11,276.55 86.28 321.63 6,173.25 6,117.05 7,241.79 1,154.72 6,038,312.38 471,029.78 1.66 6,906.66 MWD +IFR2 +MS +sag (5) 11,371.57 86.75 320.51 6,179.02 6,122.82 7,315.57 1,095.13 6,038,386.39 470,970.49 1.28 6,990.13 MWD +IFR2 +MS +sag (5) 11,397.45 86.74 320.18 6,180.49 6,124.29 7,335.46 1,078.64 6,038,406.35 470,954.08 1.27 7,012.71 MWD +IFR2 +MS +sag (5) 11,459.07 88.05 321.19 6,183.29 6,127.09 7,383.08 1,039.64 6,038,454.12 470,915.28 2.68 7,066.68 MWD +IFR2 +MS +sag (6) 11,555.52 88.53 318.39 6,186.17 6,129.97 7,456.70 977.40 6,038,527.98 470,853.35 2.94 7,150.47 MWD +IFR2 +MS +sag (6) 11,653.88 87.41 320.61 6,189.66 6,133.46 7,531.44 913.57 6,038,602.97 470,789.83 2.53 7,235.66 MWD +IFR2 +MS +sag (6) 11,704.81 85.05 320.52 6,193.01 6,136.81 7,570.69 881.29 6,038,642.35 470,757.71 4.64 7,280.17 MWD +IFR2 +MS +sag (6) 11,749.40 84.19 318.81 6,197.19 6,140.99 7,604.53 852.56 6,038,676.30 470,729.12 4.28 7,318.71 MWD +IFR2 +MS +sag (6) 11,803.91 85.76 319.40 6,201.96 6,145.76 7,645.57 817.01 6,038,717.48 470,693.74 3.08 7,365.58 MWD +IFR2 +MS +sag (6) 11,847.04 88.45 319.69 6,204.14 6,147.94 7,678.35 789.06 6,038,750.37 470,665.93 6.27 7,402.93 MWD +IFR2 +MS +sag (6) 11,902.39 91.21 320.85 6,204.30 6,148.10 7,720.91 753.69 6,038,793.07 470,630.74 5.41 7,451.27 MWD +IFR2 +MS +sag (6) 11,941.91 91.74 319.19 6,203.29 6,147.09 7,751.18 728.31 6,038,823.44 470,605.48 4.41 7,485.68 MWD +IFR2 +MS +sag (6) 12,038.76 89.19 319.95 6,202.50 6,146.30 7,824.89 665.51 6,038,897.40 470,542.98 2.75 7,569.67 MWD +IFR2 +MS +sag (6) 12,135.28 89.83 319.17 6,203.33 6,147.13 7,898.35 602.90 6,038,971.10 470,480.68 1.05 7,653.38 MWD +IFR2 +MS +sag (6) 12,188.82 91.51 319.22 6,202.70 6,146.50 7,938.87 567.92 6,039,011.76 470,445.87 3.14 7,699.63 MWD +IFR2 +MS +sag (6) 12,232.48 89.30 319.87 6,202.39 6,146.19 7,972.09 539.59 6,039,045.09 470,417.68 5.28 7,737.49 MWD +IFR2 +MS +sag (6) 12,328.76 88.65 318.49 6,204.11 6,147.91 8,044.94 476.67 6,039,118.19 470,355.06 1.58 7,820.65 MWD +IFR2 +MS +sag (6) 12,426.43 89.33 317.85 6,205.84 6,149.64 8,117.70 411.54 6,039,191.21 470,290.23 0.96 7,904.14 MWD +IFR2 +MS +sag (6) 12,521.69 91.13 314.26 6,205.45 6,149.25 8,186.28 345.45 6,039,260.04 470,224.42 4.22 7,983.68 MWD +IFR2 +MS +sag (6) 12,618.14 88.70 313.25 6,205.60 6,149.40 8,252.97 275.79 6,039,327.01 470,155.04 2.73 8,062.03 MWD +IFR2 +MS +sag (6) 12,714.90 88.65 314.32 6,207.83 6,151.63 8,319.91 205.95 6,039,394.22 470,085.48 1.11 8,140.65 MWD +IFR2 +MS +sag (6) 12,810.14 86.91 315.11 6,211.52 6,155.32 8,386.86 138.32 6,039,461.45 470,018.14 2.01 8,218.88 MWD +IFR2 +MS +sag (6) 12,907.07 89.72 322.00 6,214.38 6,158.18 8,459.44 74.24 6,039,534.28 469,954.36 7.67 8,301.99 MWD +IFR2 +MS +sag (6) 13,002.93 87.72 323.95 6,216.52 6,160.32 8,535.95 16.54 6,039,611.01 469,896.97 2.91 8,387.79 MWD +IFR2 +MS +sag (6) 13,099.29 89.46 327.09 6,218.89 6,162.69 8,615.34 -37.99 6,039,690.62 469,842.77 3.72 8,475.85 MWD +IFR2 +MS +sag (6) 13,195.32 88.90 325.08 6,220.26 6,164.06 8,695.02 -91.56 6,039,770.50 469,789.53 2.17 8,564.01 MWD +IFR2 +MS +sag (6) 13,291.24 88.96 322.68 6,222.06 6,165.86 8,772.49 - 148.09 6,039,848.19 469,733.32 2.50 8,650.54 MWD +IFR2 +MS +sag (6) 13,366.77 87.96 323.30 6,224.08 6,167.88 8,832.78 - 193.54 6,039,908.66 469,688.12 1.56 8,718.15 MWD +IFR2 +MS +sag (6) 9/222011 2:59:36PM Page 6 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -13 - Slot ODS -13 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7 + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -13 North Reference: True Wellbore: ODSK -13 Survey Calculation Method: Minimum Curvature Design: ODSK -13 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +N /-S +E / -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 13,387.15 90.29 327.60 6,224.40 6,168.20 8,849.55 - 205.09 6,039,925.48 469,676.64 23.99 8,736.76 MWD +IFR2 +MS +sag (6) 13,485.01 88.64 328.61 6,225.31 6,169.11 8,932.63 - 256.79 6,040,008.76 469,625.28 1.98 8,827.92 MWD +IFR2 +MS +sag (6) 13,581.69 88.84 330.09 6,227.44 6,171.24 9,015.78 - 306.06 6,040,092.10 469,576.35 1.54 8,918.70 MWD +IFR2 +MS +sag (6) 13,637.48 89.90 329.81 6,228.05 6,171.85 9,064.07 - 334.00 6,040,140.49 469,548.61 1.97 8,971.30 MWD +IFR2 +MS +sag (6) 13,678.25 87.70 327.90 6,228.90 6,172.70 9,098.95 - 355.08 6,040,175.46 469,527.68 7.15 9,009.46 MWD +IFR2 +MS +sag (6) 13,772.94 88.78 323.63 6,231.81 6,175.61 9,177.18 - 408.31 6,040,253.89 469,474.77 4.65 9,096.13 MWD +IFR2 +MS +sag (6) 13,869.94 88.84 322.77 6,233.83 6,177.63 9,254.83 - 466.40 6,040,331.77 469,417.00 0.89 9,183.13 MWD +IFR2 +MS +sag (6) 13,965.50 87.22 321.01 6,237.11 6,180.91 9,329.97 - 525.34 6,040,407.14 469,358.37 2.50 9,267.81 MWD +IFR2 +MS +sag (6) 14,060.37 89.03 325.91 6,240.22 6,184.02 9,406.13 - 581.77 6,040,483.52 469,302.25 5.50 9,353.04 MWD +IFR2 +MS +sag (6) 14,156.63 87.84 324.06 6,242.85 6,186.65 9,484.93 - 636.98 6,040,562.54 469,247.37 2.28 9,440.64 MWD +IFR2 +MS +sag (6) 14,165.65 88.52 324.25 6,243.13 6,186.93 9,492.24 - 642.26 6,040,569.87 469,242.12 7.83 9,448.79 MWD +IFR2 +MS +sag (6) 14,194.37 91.54 325.53 6,243.12 6,186.92 9,515.73 - 658.78 6,040,593.42 469,225.70 11.42 9,474.91 MWD +IFR2 +MS +sag (6) 14,253.09 87.57 323.94 6,243.57 6,187.37 9,563.66 - 692.67 6,040,641.49 469,192.01 7.28 9,528.26 MWD +IFR2 +MS +sag (6) 14,350.77 89.53 324.29 6,246.05 6,189.85 9,642.77 - 749.91 6,040,720.82 469,135.10 2.04 9,616.53 MWD +IFR2 +MS +sag (6) 14,447.61 87.60 325.32 6,248.47 6,192.27 9,721.88 - 805.70 6,040,800.15 469,079.63 2.26 9,704.54 MWD +IFR2 +MS +sag (6) 14,513.00 87.60 325.32 6,251.21 6,195.01 9,775.61 - 842.87 6,040,854.02 469,042.68 0.00 9,764.17 PROJECTED to TD 9/22/2011 2:59:36PM Page 7 COMPASS 2003.16 Build 42 4110 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK-13PB2 '-r Sperry Drilling Services • Definitive Survey Report 22 September, 2011 L•' HALLIBURTDN Sperry Drilling Services t , • Pioneer Natural Resources • Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -13 - Slot ODS -13 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -13 North Reference: True Wel lbore: ODSK -13PB2 Survey Calculation Method: Minimum Curvature Design: ODSK -13PB2 Database: EDM Project Oooguruk Development 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 Well ODSK -13 - Slot ODS -13 Well Position +N / -S 0.00 ft Northing: 6,031,076.06 ft Latitude: 70° 29' 45.498 N +E / -W 0.00 ft Easting: 469,845.81 ft Longitude: 150° 14' 47.653 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft Wellbore ODSK -13PB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) ( ?) (nT) User Defined 7/27/2011 20.82 80.97 57,639 Design ODSK -13PB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 3,468.28 Vertical Section: Depth From (TVD) +N / -S +E/ -W Direction (ft) (ft) (ft) ( ?) 42.70 0.00 0.00 9.73 Survey Program Date 9/22/2011 From To Survey (ft) (ft) Survey (Wellbore) Tool Name Description Start Date 100.00 532.00 ODSK -13 Gyro (ODSK- 13PB1) SR- Gyro -SS Fixed:v2:surface readout gyro single shot 01/04/2010 573.71 3,468.28 ODSK -13 MWD (ODSK- 13PB1) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 01/04/2010 3,512.00 4,188.14 ODSK -13PB2 MWD Run 600 (ODSK -13 MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 08/11/2011 4,249.10 9,067.50 ODSK -13PB2 MWD Run 700 (ODSK -13 MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 08/25/2011 9,140.14 11,140.31 ODSK -13PB2 MWD Run 1000 (ODSK -1 MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 09/22/2011 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N /-S +EI -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °l100') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,076.06 469,845.81 0.00 0.00 UNDEFINED 100.00 0.34 221.19 100.00 43.80 -0.13 -0.11 6,031,075.93 469,845.70 0.59 -0.15 SR- Gyro -SS (1) 168.00 0.16 130.95 168.00 111.80 -0.34 -0.17 6,031,075.72 469,845.63 0.55 -0.37 SR- Gyro -SS (1) 259.00 0.70 164.84 259.00 202.80 -0.96 0.07 6,031,075.10 469,845.87 0.63 -0.94 SR- Gyro -SS (1) 350.00 0.37 253.30 349.99 293.79 -1.58 -0.07 6,031,074.48 469,845.73 0.86 -1.57 SR- Gyro -SS (1) 441.00 1.19 307.31 440.99 384.79 -1.09 -1.10 6,031,074.97 469,844.70 1.12 -1.26 SR- Gyro -SS (1) 532.00 1.95 322.83 531.95 475.75 0.71 -2.79 6,031,076.78 469,843.02 0.95 0.23 SR- Gyro -SS (1) 573.71 1.85 317.80 573.64 517.44 1.78 -3.67 6,031,077.85 469,842.15 0.47 1.13 MWD +IFR2 +MS +sag (2) 626.58 3.17 315.66 626.46 570.26 3.45 -5.26 6,031,079.54 469,840.56 2.50 2.51 MWD +IFR2 +MS +sag (2) 671.26 4.30 316.56 671.04 614.84 5.55 -7.28 6,031,081.64 469,838.55 2.53 4.24 MWD +IFR2 +MS +sag (2) 9/22/2011 2:38:48PM Page 2 COMPASS 2003.16 Build 42 r , • Pioneer Natural Resources • Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co -ordinate Reference: Well ODSK -13 - Slot ODS -13 Project: Oooguruk Development TVD Reference: 42.7 + 13.5' © 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7 + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -13 North Reference: True Wellbore: ODSK -13PB2 Survey Calculation Method: Minimum Curvature Design: ODSK -13PB2 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/ -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) (° /100') (ft) Survey Tool Name 763.81 6.86 316.45 763.14 706.94 12.08 -13.47 6,031,088.19 469,832.39 2.77 9.63 MWD +IFR2 +MS +sag (2) 813.54 8.01 316.35 812.46 756.26 16.74 -17.91 6,031,092.87 469,827.97 2.31 13.47 MWD +IFR2 +MS +sag (2) 860.24 8.60 315.98 858.67 802.47 21.61 -22.59 6,031,097.76 469,823.31 1.27 17.48 MWD +IFR2 +MS +sag (2) 909.76 9.51 313.90 907.57 851.37 27.11 -28.11 6,031,103.28 469,817.82 1.95 21.96 MWD +IFR2 +MS +sag (2) 956.78 9.35 312.67 953.95 897.75 32.39 -33.71 6,031,108.58 469,812.23 0.55 26.22 MWD +IFR2 +MS +sag (2) 1,005.95 9.18 310.28 1,002.48 946.28 37.63 -39.64 6,031,113.85 469,806.32 0.86 30.39 MWD +IFR2 +MS +sag (2) 1,049.84 11.17 311.64 1,045.68 989.48 42.72 -45.49 6,031,118.96 469,800.50 4.57 34.42 MWD +IFR2 +MS +sag (2) 1,096.33 13.93 309.80 1,091.05 1,034.85 49.29 -53.16 6,031,125.56 469,792.86 6.00 39.60 MWD +IFR2 +MS +sag (2) 1,145.56 15.24 312.60 1,138.70 1,082.50 57.47 -62.47 6,031,133.77 469,783.58 3.02 46.08 MWD +IFR2 +MS +sag (2) 1,194.22 15.31 310.88 1,185.64 1,129.44 66.00 -72.04 6,031,142.35 469,774.05 0.94 52.88 MWD +IFR2 +MS +sag (2) 1,240.56 16.78 310.92 1,230.17 1,173.97 74.39 -81.72 6,031,150.77 469,764.40 3.17 59.51 MWD +IFR2 +MS +sag (2) 1,289.96 18.95 309.46 1,277.19 1,220.99 84.16 -93.30 6,031,160.59 469,752.86 4.48 67.18 MWD +IFR2 +MS +sag (2) 1,336.79 20.72 308.92 1,321.24 1,265.04 94.19 - 105.62 6,031,170.67 469,740.59 3.80 74.99 MWD +IFR2 +MS +sag (2) 1,384.42 22.51 306.84 1,365.52 1,309.32 104.96 - 119.47 6,031,181.49 469,726.78 4.09 83.25 MWD +IFR2 +MS +sag (2) 1,430.42 23.07 305.99 1,407.93 1,351.73 115.53 - 133.81 6,031,192.12 469,712.48 1.41 91.25 MWD +IFR2 +MS +sag (2) 1,479.83 23.39 304.58 1,453.33 1,397.13 126.79 - 149.72 6,031,203.44 469,696.62 1.30 99.66 MWD +IFR2 +MS +sag (2) 1,525.32 23.94 305.15 1,494.99 1,438.79 137.23 - 164.70 6,031,213.94 469,681.68 1.31 107.42 MWD +IFR2 +MS +sag (2) 1,576.16 24.01 305.92 1,541.45 1,485.25 149.23 - 181.51 6,031,226.01 469,664.92 0.63 116.41 MWD +IFR2 +MS +sag (2) 1,621.34 24.33 306.96 1,582.67 1,526.47 160.22 - 196.39 6,031,237.06 469,650.09 1.18 124.72 MWD +IFR2 +MS +sag (2) 1,671.07 25.79 307.41 1,627.72 1,571.52 172.95 - 213.17 6,031,249.86 469,633.36 2.96 134.44 MWD +IFR2 +MS +sag (2) 1,705.60 25.58 308.15 1,658.83 1,602.63 182.12 - 225.00 6,031,259.07 469,621.57 1.11 141.47 MWD +IFR2 +MS +sag (2) 1,766.84 25.73 308.07 1,714.04 1,657.84 198.48 - 245.86 6,031,275.52 469,600.78 0.25 154.08 MWD +IFR2 +MS +sag (2) 1,811.68 25.57 310.02 1,754.46 1,698.26 210.71 - 260.93 6,031,287.80 469,585.76 1.92 163.58 MWD +IFR2 +MS +sag (2) 1,862.23 25.52 312.44 1,800.07 1,743.87 225.07 - 277.33 6,031,302.23 469,569.43 2.07 174.96 MWD +IFR2 +MS +sag (2) 1,907.09 25.51 313.53 1,840.55 1,784.35 238.25 - 291.46 6,031,315.46 469,555.35 1.05 185.56 MWD +IFR2 +MS +sag (2) 1,958.99 26.92 315.00 1,887.11 1,830.91 254.25 - 307.87 6,031,331.53 469,539.00 2.99 198.56 MWD +IFR2 +MS +sag (2) 1 2,001.97 27.61 317.15 1,925.32 1,869.12 268.43 - 321.53 6,031,345.77 469,525.41 2.80 210.23 MWD +IFR2 +MS +sag (2) 2,097.12 28.74 323.48 2,009.21 1,953.01 302.99 - 350.14 6,031,380.44 469,496.94 3.36 239.46 MWD +IFR2 +MS +sag (2) 1 2,192.69 29.36 331.16 2,092.79 2,036.59 341.99 - 375.13 6,031,419.54 469,472.11 3.95 273.68 MWD +IFR2 +MS +sag (2) 2,241.25 29.14 334.14 2,135.16 2,078.96 363.06 - 386.02 6,031,440.65 469,461.30 3.03 292.60 MWD +IFR2 +MS +sag (2) 2,287.81 29.36 334.80 2,175.78 2,119.58 383.59 - 395.83 6,031,461.22 469,451.58 0.84 311.18 MWD +IFR2 +MS +sag (2) 2,383.06 33.63 338.04 2,256.99 2,200.79 429.21 - 415.65 6,031,506.91 469,431.95 4.82 352.79 MWD +IFR2 +MS +sag (2) 2,477.86 36.61 342.39 2,334.53 2,278.33 480.52 - 434.02 6,031,558.28 469,413.78 4.10 400.25 MWD +IFR2 +MS +sag (2) 2,530.79 38.32 345.12 2,376.55 2,320.35 511.42 - 443.01 6,031,589.22 469,404.92 4.50 429.19 MWD +IFR2 +MS +sag (2) 2,572.80 40.97 347.17 2,408.89 2,352.69 537.44 - 449.42 6,031,615.27 469,398.62 7.03 453.76 MWD +IFR2 +MS +sag (2) 2,619.68 42.07 349.45 2,444.00 2,387.80 567.87 - 455.70 6,031,645.72 469,392.46 3.99 482.69 MWD +IFR2 +MS +sag (2) 2,668.18 44.23 350.62 2,479.38 2,423.18 600.54 - 461.44 6,031,678.41 469,386.86 4.75 513.91 MWD +IFR2 +MS +sag (2) 2,763.56 46.77 352.08 2,546.23 2,490.03 667.79 - 471.65 6,031,745.69 469,376.92 2.88 578.47 MWD +IFR2 +MS +sag (2) 2,857.18 49.32 354.88 2,608.82 2,552.62 736.95 - 479.52 6,031,814.87 469,369.33 3.52 645.30 MWD +IFR2 +MS +sag (2) 2,953.56 52.79 357.15 2,669.40 2,613.20 811.71 -48.4.69 6,031,889.64 469,364.47 4.04 718.11 MWD +IFR2 +MS +sag (2) 9/22/2011 2:38:48PM Page 3 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -13 - Slot ODS -13 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -13 North Reference: True Wellbore: ODSK -13PB2 Survey Calculation Method: Minimum Curvature Design: ODSK -13PB2 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E! -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °1•00') (ft) Survey Tool Name 3,048.04 54.50 358.46 2,725.40 2,669.20 887.74 - 487.59 6,031,965.68 469,361.87 2.13 792.56 MWD +IFR2 +MS +sag (2) 3,143.06 57.30 358.73 2,778.67 2,722.47 966.39 - 489.52 6,032,044.33 469,360.26 2.96 869.75 MWD +IFR2 +MS +sag (2) 3,239.01 61.30 359.87 2,827.65 2,771.45 1,048.87 - 490.51 6,032,126.80 469 359.61 4.29 950.88 MWD+IFR2+MS+sag (2) 3,332.55 64.45 1.07 2,870.29 2,814.09 1,132.10 - 489.82 6,032,210.02 469,360.64 3.56 1,033.03 MWD +IFR2 +MS +sag (2) 3,429.23 64.20 1.45 2,912.18 2,855.98 1,219.21 - 487.90 6,032,297.12 469,362.91 0.44 1,119.22 MWD +IFR2 +MS +sag (2) 3,468.28 63.59 2.08 2,929.36 2,873.16 1,254.26 - 486.82 6,032,332.16 469,364.13 2.13 1,153.95 MWD +IFR2 +MS +sag (2) 3,512.00 63.49 2.41 2,948.84 2,892.64 1,293.37 - 485.29 6,032,371.26 469,365.82 0.71 1,192.75 MWD +IFR2 +MS +sag (3) 3,555.33 62.03 1.18 2,968.67 2,912.47 1,331.88 - 484.08 6,032,409.76 469,367.19 4.21 1,230.91 MWD +IFR2 +MS +sag (3) 3,616.51 64.15 2.52 2,996.36 2,940.16 1,386.40 - 482.31 6,032,464.26 469,369.17 3.98 1,284.94 MWD +IFR2 +MS +sag (3) 3,665.79 64.07 1.46 3,017.88 2,961.68 1,430.71 - 480.77 6,032,508.56 469,370.89 1.94 1,328.87 MWD +IFR2 +MS +sag (3) 3,712.23 63.29 1.97 3,038.47 2,982.27 1,472.31 - 479.53 6,032,550.16 469,372.31 1.95 1,370.09 MWD +IFR2 +MS +sag (3) 3,807.59 63.18 1.37 3,081.42 3,025.22 1,557.42 - 477.05 6,032,635.24 469,375.13 0.57 1,454.39 MWD +IFR2 +MS +sag (3) 3,902.42 63.18 1.51 3,124.20 3,068.00 1,642.02 - 474.92 6,032,719.83 469,377.60 0.13 1,538.14 MWD +IFR2 +MS +sag (3) 3,997.88 62.71 0.22 3,167.62 3,111.42 1,727.02 - 473.63 6,032,804.81 469,379.23 1.30 1,622.13 MWD +IFR2 +MS +sag (3) 4,093.20 62.04 359.94 3,211.82 3,155.62 1,811.48 - 473.51 6,032,889.26 469,379.69 0.75 1,705.39 MWD +IFR2 +MS +sag (3) 4,188.14 63.53 0.20 3,255.24 3,199.04 1,895.90 - 473.41 6,032,973.68 469,380.14 1.59 1,788.62 MWD +IFR2 +MS +sag (3) 4,249.10 63.12 0.16 3,282.61 3,226.41 1,950.37 - 473.24 6,033,028.14 469,380.53 0.68 1,842.34 MWD +IFR2 +MS +sag (4) 4,342.75 62.39 1.86 3,325.48 3,269.28 2,033.62 - 471.78 6,033,111.37 469,382.33 1.79 1,924.63 MWD +IFR2 +MS +sag (4) 4,439.42 63.41 7.57 3,369.55 3,313.35 2,119.33 - 464.69 6,033,197.04 469,389.77 5.36 2,010.31 MWD +IFR2 +MS +sag (4) 4,534.56 63.63 10.80 3,411.98 3,355.78 2,203.38 - 451.09 6,033,281.03 469,403.70 3.05 2,095.45 MWD +IFR2 +MS +sag (4) 4,629.62 63.38 14.09 3,454.39 3,398.19 2,286.44 - 432.77 6,033,364.01 469,422.37 3.11 2,180.41 MWD +IFR2 +MS +sag (4) 4,721.64 63.48 17.57 3,495.56 3,439.36 2,365.60 - 410.32 6,033,443.07 469,445.13 3.38 2,262.23 MWD +IFR2 +MS +sag (4) 4,818.91 63.26 20.75 3,539.17 3,482.97 2,447.73 - 381.79 6,033,525.07 469,473.99 2.93 2,347.99 MWD +IFR2 +MS +sag (4) 4,911.96 63.66 24.62 3,580.76 3,524.56 2,524.51 - 349.69 6,033,601.71 469,506.40 3.75 2,429.09 MWD +IFR2 +MS +sag (4) 5,007.94 63.69 27.95 3,623.33 3,567.13 2,601.62 - 311.60 6,033,678.66 469,544.80 3.11 2,511.54 MWD +IFR2 +MS +sag (4) 5,103.05 63.87 30.03 3,665.36 3,609.16 2,676.25 - 270.25 6,033,753.11 469,586.45 1.97 2,592.08 MWD +IFR2 +MS +sag (4) 5,198.48 63.74 31.88 3,707.49 3,651.29 2,749.68 - 226.21 6,033,826.36 469,630.78 1.74 2,671.89 MWD +IFR2 +MS +sag (4) 5,293.95 64.38 34.93 3,749.26 3,693.06 2,821.33 - 178.94 6,033,897.81 469,678.33 2.95 2,750.51 MWD +IFR2 +MS +sag (4) 5,388.05 64.77 37.53 3,789.66 3,733.46 2,889.88 - 128.72 6,033,966.14 469,728.83 2.53 2,826.55 MWD +IFR2 +MS +sag (4) 5,483.36 65.50 39.43 3,829.74 3,773.54 2,957.56 -74.91 6,034,033.61 469,782.90 1.96 2,902.36 MWD +IFR2 +MS +sag (4) 5,579.29 66.01 42.51 3,869.14 3,812.94 3,023.59 -17.57 6,034,099.40 469,840.51 2.98 2,977.13 MWD +IFR2 +MS +sag (4) 5,673.51 65.72 44.70 3,907.67 3,851.47 3,085.85 41.73 6,034,161.41 469,900.05 2.14 3,048.51 MWD +IFR2 +MS +sag (4) 5,768.88 65.19 47.30 3,947.29 3,891.09 3,146.11 104.12 6,034,221.41 469,962.68 2.54 3,118.45 MWD +IFR2 +MS +sag (4) 5,863.95 66.34 49.90 3,986.32 3,930.12 3,203.43 169.15 6,034,278.45 470,027.93 2.77 3,185.93 MWD +IFR2 +MS +sag (4) 5,959.06 67.46 51.77 4,023.64 3,967.44 3,258.67 236.98 6,034,333.41 470,095.98 2.16 3,251.84 MWD +IFR2 +MS +sag (4) 6,054.68 67.35 52.31 4,060.38 4,004.18 3,312.97 306.58 6,034,387.43 470,165.79 0.53 3,317.13 MWD +IFR2 +MS +sag (4) 6,149.01 67.62 52.84 4,096.50 4,040.30 3,365.93 375.78 6,034,440.10 470,235.20 0.59 3,381.02 MWD +IFR2 +MS +sag (4) 6,244.58 67.61 52.94 4,132.90 4,076.70 3,419.24 446.25 6,034,493.12 470,305.88 0.10 3,445.48 MWD +IFR2 +MS +sag (4) 6,339.78 67.33 52.56 4,169.37 4,113.17 3,472.47 516.25 6,034,546.06 470,376.09 0.47 3,509.77 MWD +IFR2 +MS +sag (4) 6,433.33 67.79 51.93 4,205.08 4,148.88 3,525.41 584.61 6,034,598.72 470,444.66 0.79 3,573.50 MWD +IFR2 +MS +sag (4) 9/22/2011 2:38:48PM Page 4 COMPASS 2003.16 Build 42 . . Pioneer Natural Resources • Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -13 - Slot ODS -13 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -13 North Reference: True Welibore: ODSK -13PB2 Survey Calculation Method: Minimum Curvature Design: ODSK -13PB2 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +El -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °l100') (ft) Survey Tool Name 6,499.89 68.02 51.58 4,230.12 4,173.92 3,563.59 633.05 6,034,636.69 470,493.24 0.60 3,619.32 MWD +IFR2 +MS +sag (4) 6,529.96 67.69 51.89 4,241.46 4,185.26 3,580.84 654.91 6,034,653.85 470,515.18 1.45 3,640.01 MWD +IFR2 +MS +sag (4) 6,625.13 66.73 51.49 4,278.32 4,222.12 3,635.23 723.76 6,034,707.96 470,584.24 1.08 3,705.25 MWD +IFR2 +MS +sag (4) 6,720.41 67.39 51.27 4,315.46 4,259.26 3,689.99 792.32 6,034,762.44 470,653.01 0.72 3,770.82 MWD +IFR2 +MS +sag (4) 6,813.96 67.62 51.79 4,351.25 4,295.05 3,743.76 859.99 6,034,815.93 470,720.89 0.57 3,835.25 MWD +IFR2 +MS +sag (4) 6,910.56 67.95 51.12 4,387.77 4,331.57 3,799.49 929.93 6,034,871.36 470,791.05 0.73 3,902.00 MWD +IFR2 +MS +sag (4) 7,005.87 67.72 50.71 4,423.73 4,367.53 3,855.14 998.44 6,034,926.73 470,859.78 0.47 3,968.42 MWD +IFR2 +MS +sag (4) 7,099.81 67.81 50.30 4,459.28 4,403.08 3,910.44 1,065.54 6,034,981.75 470,927.10 0.42 4,034.27 MWD +IFR2 +MS +sag (4) 7,194.84 67.46 49.70 4,495.44 4,439.24 3,966.93 1,132.87 6,035,037.96 470,994.64 0.69 4,101.33 MWD +IFR2 +MS +sag (4) 7,290.27 66.41 47.24 4,532.83 4,476.63 4,025.13 1,198.59 6,035,095.89 471,060.60 2.61 4,169.80 MWD +IFR2 +MS +sag (4) 7,385.79 65.53 45.76 4,571.73 4,515.53 4,085.18 1,261.87 6,035,155.68 471,124.12 1.69 4,239.68 MWD +IFR2 +MS +sag (4) 7,480.76 64.78 43.46 4,611.64 4,555.44 4,146.52 1,322.39 6,035,216.77 471,184.88 2.34 4,310.37 MWD +IFR2 +MS +sag (4) 7,577.09 64.17 41.66 4,653.15 4,596.95 4,210.54 1,381.19 6,035,280.54 471,243.93 1.80 4,383.40 MWD +IFR2 +MS +sag (4) 7,671.10 62.47 40.38 4,695.36 4,639.16 4,273.91 1,436.32 6,035,343.68 471,299.31 2.18 4,455.18 MWD +IFR2 +MS +sag (4) 7,766.33 61.94 38.93 4,739.77 4,683.57 4,338.77 1,490.08 6,035,408.31 471,353.33 1.46 4,528.19 MWD +IFR2 +MS +sag (4) 7,862.27 61.80 36.99 4,785.00 4,728.80 4,405.47 1,542.12 6,035,474.79 471,405.63 1.79 4,602.72 MWD +IFR2 +MS +sag (4) 7,957.08 61.46 34.26 4,830.06 4,773.86 4,473.27 1,590.71 6,035,542.39 471,454.49 2.56 4,677.76 MWD +IFR2 +MS +sag (4) 8,052.55 59.95 31.28 4,876.78 4,820.58 4,543.26 1,635.78 6,035,612.18 471,499.84 3.15 4,754.36 MWD +IFR2 +MS +sag (4) 8,148.21 59.28 28.61 4,925.17 4,868.97 4,614.75 1,676.97 6,035,683.50 471,541.32 2.51 4,831.78 MWD +IFR2 +MS +sag (4) 8,241.73 59.42 26.12 4,972.85 4,916.65 4,686.19 1,713.95 6,035,754.79 471,578.58 2.30 4,908.45 MWD +IFR2 +MS +sag (4) 8,336.89 58.89 23.40 5,021.65 4,965.45 4,760.37 1,748.17 6,035,828.82 471,613.09 2.52 4,987.34 MWD +IFR2 +MS +sag (4) 8,432.34 58.45 20.01 5,071.29 5,015.09 4,836.10 1,778.32 6,035,904.42 471,643.55 3.07 5,067.08 MWD +IFR2 +MS +sag (4) 8,527.43 58.16 16.73 5,121.26 5,065.06 4,912.87 1,803.81 6,035,981.07 471,669.35 2.95 5,147.05 MWD +IFR2 +MS +sag (4) 8,622.99 58.31 13.78 5,171.58 5,115.38 4,991.24 1,825.19 6,036,059.35 471,691.04 2.63 5,227.90 MWD +IFR2 +MS +sag (4) 8,718.51 58.61 9.62 5,221.56 5,165.36 5,070.93 1,841.68 6,036,138.96 471,707.86 3.72 5,309.24 MWD +IFR2 +MS +sag (4) 8,812.82 57.91 5.46 5,271.19 5,214.99 5,150.41 1,852.22 6,036,218.40 471,718.71 3.82 5,389.36 MWD +IFR2 +MS +sag (4) 8,908.88 57.88 1.43 5,322.25 5,266.05 5,231.61 1,857.10 6,036,299.56 471,723.93 3.55 5,470.21 MWD +IFR2 +MS +sag (4) 9,003.97 57.75 357.12 5,372.92 5,316.72 5,312.05 1,856.09 6,036,380.00 471,723.24 3.84 5,549.33 MWD +IFR2 +MS +sag (4) + 9,067.50 57.73 356.42 5,406.83 5,350.63 5,365.69 1,853.06 6,036,433.65 471,720.43 0.93 5,601.68 MWD + IFR2 MS + sag (4) 9,140.14 57.10 357.11 5,445.95 5,389.75 5,426.79 1,849.61 6,036,494.76 471,717.23 1.18 5,661.32 MWD +IFR2 +MS +sag (5) 9,238.01 57.06 357.02 5,499.14 5,442.94 5,508.84 1,845.40 6,036,576.82 471,713.35 0.09 5,741.48 MWD +IFR2 +MS +sag (5) 9,332.85 56.89 357.65 5,550.83 5,494.63 5,588.27 1,841.70 6,036,656.25 471,709.98 0.59 5,819.14 MWD +IFR2 +MS +sag (5) 9,427.64 57.43 358.35 5,602.23 5,546.03 5,667.86 1,838.92 6,036,735.85 471,707.52 0.84 5,897.12 MWD +IFR2 +MS +sag (5) 9,522.32 57.95 357.95 5,652.84 5,596.64 5,747.84 1,836.34 6,036,815.83 471,705.26 0.66 5,975.51 MWD +IFR2 +MS +sag (5) 9,617.97 58.03 355.52 5,703.55 5,647.35 5,828.81 1,831.72 6,036,896.80 471,700.97 2.16 6,054.53 MWD +IFR2 +MS +sag (5) 9,713.40 58.94 353.21 5,753.43 5,697.23 5,909.76 1,823.72 6,036,977.78 471,693.31 2.27 6,132.97 MWD +IFR2 +MS +sag (5) 9,808.56 57.66 350.42 5,803.44 5,747.24 5,989.89 1,812.21 6,037,057.94 471,682.12 2.83 6,210.00 MWD +IFR2 +MS +sag (5) 9,903.97 55.71 347.52 5,855.85 5,799.65 6,068.13 1,796.98 6,037,136.24 471,667.21 3.26 6,284.54 MWD +IFR2 +MS +sag (5) 9,998.95 56.56 344.86 5,908.79 5,852.59 6,144.70 1,778.15 6,037,212.88 471,648.69 2.49 6,356.83 MWD +IFR2 +MS +sag (5) 10,094.87 56.93 342.38 5,961.39 5,905.19 6,221.65 1,755.53 6,037,289.91 471,626.39 2.20 6,428.85 MWD +IFR2 +MS +sag (5) 9/22/2011 2:38:48PM Page 5 COMPASS 2003.16 Build 42 ,, • Pioneer Natural Resources • Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -13 - Slot ODS -13 Project: Oooguruk Development TVD Reference: 42.7 + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7 + 13.5' © 56.20ft (Nabors 19AC) Well: ODSK -13 North Reference: True Wellbore: ODSK -13PB2 Survey Calculation Method: Minimum Curvature Design: ODSK -13PB2 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N /-S +E/ -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °/1001 (ft) Survey Tool Name 10,190.51 58.17 339.71 6,012.71 5,956.51 6,297.96 1,729.31 6,037,366.32 471,600.48 2.69 6,499.63 MWD +IFR2 +MS +sag (5) 10,285.77 57.44 337.82 6,063.47 6,007.27 6,373.10 1,700.12 6,037,441.57 471,571.59 1.85 6,568.75 MWD +IFR2 +MS +sag (5) 10,380.99 57.29 334.94 6,114.83 6,058.63 6,446.56 1,668.00 6,037,515.15 471,539.77 2.55 6,635.72 MWD +IFR2 +MS +sag (5) 10,474.77 57.27 331.94 6,165.53 6,109.33 6,517.12 1,632.72 6,037,585.84 471,504.79 2.69 6,699.31 MWD +IFR2 +MS +sag (5) 10,569.76 55.53 327.60 6,218.11 6,161.91 6,585.46 1,592.93 6,037,654.34 471,465.28 4.22 6,759.95 MWD +IFR2 +MS +sag (5) 10,665.10 55.14 325.51 6,272.34 6,216.14 6,650.89 1,549.72 6,037,719.94 471,422.34 1.85 6,817.13 MWD +IFR2 +MS +sag (5) 10,759.82 53.90 324.84 6,327.32 6,271.12 6,714.21 1,505.68 6,037,783.43 471,378.56 1.43 6,872.09 MWD +IFR2 +MS +sag (5) 10,855.66 52.88 326.07 6,384.48 6,328.28 6,777.57 1,462.05 6,037,846.96 471,335.19 1.48 6,927.17 MWD +I +MS +sag (5) 10,950.39 52.36 326.67 6,441.99 6,385.79 6,840.24 1,420.36 6,037,909.80 471,293.76 0.74 6,981.90 MWD +IFR2 +MS +sag (5) 11,045.38 50.08 326.61 6,501.48 6,445.28 6,902.09 1,379.64 6,037,971.80 471,253.30 2.40 7,035.97 MWD +I +MS +sag (5) 11,140.31 48.21 327.22 6,563.57 6,507.37 6,962.24 1,340.45 6,038,032.11 471,214.35 2.03 7,088.63 MWD +IFR2 +MS +sag (5) 11,187.00 48.21 327.22 6,594.69 6,538.49 6,991.51 1,321.60 6,038,061.45 471,195.62 0.00 7,114.30 PROJECTED to TD 9/22/2011 2:38:48PM Page 6 COMPASS 2003.16 Build 42 S br r r.as f Well Planning - Pioneer - Oooguruk g g Oooguruk Development is a Oooguruk Drill Site ODSK -13PB1 Permit to Drill: 209 -1460 API: 50- 703 - 20607 -00 2; tvp Sperry Drilling Services Definitive Survey Report 22 September, 2011 p i; r L '!1 nC HALLIBURTON Sperry Drilling Services • Pioneer Natural Resources • Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -13 - Slot ODS -13 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' © 56.20ft (Nabors 19AC) Well: ODSK -13 North Reference: True Wellbore: ODSK -13PB1 Survey Calculation Method: Minimum Curvature Design: ODSK -13PB1 Database: EDM_Alaska Project Oooguruk Development 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 Well ODSK -13 - Slot ODS -13 Well Position +NI-S 0.00 ft Northing: 6,031,076.06 ft Latitude: 70° 29' 45.498 N +E / -W 0.00 ft Easting: 469,845.81 ft Longitude: 150° 14' 47.653 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft Wellbore ODSK -13PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) ( ?) (nT) IGRF200510 12/29/2009 21.99 80.81 57,759 Design ODSK -13PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 42.70 Vertical Section: Depth From (TVD) +NI-S +E/ -W Direction (ft) (ft) (ft) ( ?) 42.70 0.00 0.00 9.73 Survey Program Date 9/19/2011 From To Survey (ft) (ft) Survey ( Wellbore) Tool Name Description Start Date 100.00 532.00 ODSK -13 Gyro (ODSK- 13PB1) SR- Gyro -SS Fixed:v2:surface readout gyro single shot 01/04/2010 573.71 3,468.28 ODSK -13 MWD (ODSK- 13PB1) MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 01/04/2010 3,555.82 9,192.55 ODSK -13 MWD Run 300 (ODSK -13PB1 MWD +IFR2 +MS +sag Fixed:v2:IIFR dec & 3 -axis correction + sag 08/01/2011 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N /-S +E/ -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,076.06 469,845.81 0.00 0.00 UNDEFINED 100.00 0.34 221.19 100.00 43.80 -0.13 -0.11 6,031,075.93 469,845.70 0.59 -0.15 SR- Gyro -SS (1) 168.00 0.16 130.95 168.00 111.80 -0.34 -0.17 6,031,075.72 469,845.63 0.55 -0.37 SR- Gyro -SS (1) 259.00 0.70 164.84 259.00 202.80 -0.96 0.07 6,031,075.10 469,845.87 0.63 -0.94 SR- Gyro -SS (1) 350.00 0.37 253.30 349.99 293.79 -1.58 -0.07 6,031,074.48 469,845.73 0.86 -1.57 SR- Gyro -SS (1) 441.00 1.19 307.31 440.99 384.79 -1.09 -1.10 6,031,074.97 469,844.70 1.12 -1.26 SR- Gyro -SS (1) 532.00 1.95 322.83 531.95 475.75 0.71 -2.79 6,031,076.78 469,843.02 0.95 0.23 SR- Gyro -SS (1) 573.71 1.85 317.80 573.64 517.44 1.78 -3.67 6,031,077.85 469,842.15 0.47 1.13 MWD +IFR2 +MS +sag (2) 626.58 3.17 315.66 626.46 570.26 3.45 -5.26 6,031,079.54 469,840.56 2.50 2.51 MWD +IFR2 +MS +sag (2) 671.26 4.30 316.56 671.04 614.84 5.55 -7.28 6,031,081.64 469,838.55 2.53 4.24 MWD +IFR2 +MS +sag (2) 763.81 6.86 316.45 763.14 706.94 12.08 -13.47 6,031,088.19 469,832.39 2.77 9.63 MWD +IFR2 +MS +sag (2) 813.54 8.01 316.35 812.46 756.26 16.74 -17.91 6,031,092.87 469,827.97 2.31 13.47 MWD +IFR2 +MS +sag (2) 9/22/2011 1:52:47PM Page 2 COMPASS 2003.16 Build 42 • Pioneer Natural Resources S Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -13 - Slot ODS -13 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -13 North Reference: True Welibore: ODSK -13PB1 Survey Calculation Method: Minimum Curvature Design: ODSK -13PB1 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) (° /1001 (ft) Survey Tool Name 860.24 8.60 315.98 858.67 802.47 21.61 -22.59 6,031,097.76 469,823.31 1.27 17.48 MWD +IFR2 +MS +sag (2) 909.76 9.51 313.90 907.57 851.37 27.11 -28.11 6,031,103.28 469,817.82 1.95 21.96 MWD +IFR2 +MS +sag (2) 956.78 9.35 312.67 953.95 897.75 32.39 -33.71 6,031,108.58 469,812.23 0.55 26.22 MWD +IFR2 +MS +sag (2) 1,005.95 9.18 310.28 1,002.48 946.28 37.63 -39.64 6,031,113.85 469,806.32 0.86 30.39 MWD +IFR2 +MS +sag (2) 1,049.84 11.17 311.64 1,045.68 989.48 42.72 -45.49 6,031,118.96 469,800.50 4.57 34.42 MWD +IFR2 +MS +sag (2) 1,096.33 13.93 309.80 1,091.05 1,034.85 49.29 -53.16 6,031,125.56 469,792.86 6.00 39.60 MWD +IFR2 +MS +sag (2) 1,145.56 15.24 312.60 1,138.70 1,082.50 57.47 -62.47 6,031,133.77 469,783.58 3.02 46.08 MWD +IFR2 +MS +sag (2) 1,194.22 15.31 310.88 1,185.64 1,129.44 66.00 -72.04 6,031,142.35 469,774.05 0.94 52.88 MWD +IFR2 +MS +sag (2) 1,240.56 16.78 310.92 1,230.17 1,173.97 74.39 -81.72 6,031,150.77 469,764.40 3.17 59.51 MWD +IFR2 +MS +sag (2) 1,289.96 18.95 309.46 1,277.19 1,220.99 84.16 -93.30 6,031,160.59 469,752.86 4.48 67.18 MWD +IFR2 +MS +sag (2) 1,336.79 20.72 308.92 1,321.24 1,265.04 94.19 - 105.62 6,031,170.67 469,740.59 3.80 74.99 MWD +IFR2 +MS +sag (2) 1,384.42 22.51 306.84 1,365.52 1,309.32 104.96 - 119.47 6,031,181.49 469,726.78 4.09 83.25 MWD +IFR2 +MS +sag (2) 1,430.42 23.07 305.99 1,407.93 1,351.73 115.53 - 133.81 6,031,192.12 469,712.48 1.41 91.25 MWD +IFR2 +MS +sag (2) 1,479.83 23.39 304.58 1,453.33 1,397.13 126.79 - 149.72 6,031,203.44 469,696.62 1.30 99.66 MWD +IFR2 +MS +sag (2) 1,525.32 23.94 305.15 1,494.99 1,438.79 137.23 - 164.70 6,031,213.94 469,681.68 1.31 107.42 MWD +IFR2 +MS +sag (2) 1,576.16 24.01 305.92 1,541.45 1,485.25 149.23 - 181.51 6,031,226.01 469,664.92 0.63 116.41 MWD +IFR2 +MS +sag (2) 1,621.34 24.33 306.96 1,582.67 1,526.47 160.22 - 196.39 6,031,237.06 469,650.09 1.18 124.72 MWD +IFR2 +MS +sag (2) 1,671.07 25.79 307.41 1,627.72 1,571.52 172.95 - 213.17 6,031,249.86 469,633.36 2.96 134.44 MWD +IFR2 +MS +sag (2) 1,705.60 25.58 308.15 1,658.83 1,602.63 182.12 - 225.00 6,031,259.07 469,621.57 1.11 141.47 MWD +IFR2 +MS +sag (2) 1,766.84 25.73 308.07 1,714.04 1,657.84 198.48 - 245.86 6,031,275.52 469,600.78 0.25 154.08 MWD +IFR2 +MS +sag (2) 1,811.68 25.57 310.02 1,754.46 1,698.26 210.71 - 260.93 6,031,287.80 469,585.76 1.92 163.58 MWD +IFR2 +MS +sag (2) 1,862.23 25.52 312.44 1,800.07 1,743.87 225.07 - 277.33 6,031,302.23 469,569.43 2.07 174.96 MWD +IFR2 +MS +sag (2) 1,907.09 25.51 313.53 1,840.55 1,784.35 238.25 - 291.46 6,031,315.46 469,555.35 1.05 185.56 MWD +IFR2 +MS +sag (2) 1,958.99 26.92 315.00 1,887.11 1,830.91 254.25 - 307.87 6,031,331.53 469,539.00 2.99 198.56 MWD +IFR2 +MS +sag (2) 2,001.97 27.61 317.15 1,925.32 1,869.12 268.43 - 321.53 6,031,345.77 469,525.41 2.80 210.23 MWD +IFR2 +MS +sag (2) 2,097.12 28.74 323.48 2,009.21 1,953.01 302.99 - 350.14 6,031,380.44 469,496.94 3.36 239.46 MWD +IFR2 +MS +sag (2) 2,192.69 29.36 331.16 2,092.79 2,036.59 341.99 - 375.13 6,031,419.54 469,472.11 3.95 273.68 MWD +IFR2 +MS +sag (2) 2,241.25 29.14 334.14 2,135.16 2,078.96 363.06 - 386.02 6,031,440.65 469,461.30 3.03 292.60 MWD +IFR2 +MS +sag (2) 2,287.81 29.36 334.80 2,175.78 2,119.58 383.59 - 395.83 6,031,461.22 469,451.58 0.84 311.18 MWD +IFR2 +MS +sag (2) 2,383.06 33.63 338.04 2,256.99 2,200.79 429.21 - 415.65 6,031,506.91 469,431.95 4.82 352.79 MWD +IFR2 +MS +sag (2) 2,477.86 36.61 342.39 2,334.53 2,278.33 480.52 - 434.02 6,031,558.28 469,413.78 4.10 400.25 MWD +IFR2 +MS +sag (2) 2,530.79 38.32 345.12 2,376.55 2,320.35 511.42 - 443.01 6,031,589.22 469,404.92 4.50 429.19 MWD +IFR2 +MS +sag (2) 2,572.80 40.97 347.17 2,408.89 2,352.69 537.44 - 449.42 6,031,615.27 469,398.62 7.03 453.76 MWD +IFR2 +MS +sag (2) 2,619.68 42.07 349.45 2,444.00 2,387.80 567.87 - 455.70 6,031,645.72 469,392.46 3.99 482.69 MWD +IFR2 +MS +sag (2) 2,668.18 44.23 350.62 2,479.38 2,423.18 600.54 - 461.44 6,031,678.41 469,386.86 4.75 513.91 MWD +IFR2 +MS +sag (2) 2,763.56 46.77 352.08 2,546.23 2,490.03 667.79 - 471.65 6,031,745.69 469,376.92 2.88 578.47 MWD +IFR2 +MS +sag (2) 2,857.18 49.32 354.88 2,608.82 2,552.62 736.95 - 479.52 6,031,814.87 469,369.33 3.52 645.30 MWD +IFR2 +MS +sag (2) 2,953.56 52.79 357.15 2,669.40 2,613.20 811.71 - 484.69 6,031,889.64 469,364.47 4.04 718.11 MWD +IFR2 +MS +sag (2) 3,048.04 54.50 358.46 2,725.40 2,669.20 887.74 - 487.59 6,031,965.68 469,361.87 2.13 792.56 MWD +IFR2 +MS +sag (2) 3,143.06 57.30 358.73 2,778.67 2,722.47 966.39 - 489.52 6,032,044.33 469,360.26 2.96 869.75 MWD +IFR2 +MS +sag (2) 9/22/2011 1:52:47PM Page 3 COMPASS 2003.16 Build 42 • Pioneer Natural Resources Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -13 - Slot ODS -13 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -13 North Reference: True Wel!bore: ODSK -13PB1 Survey Calculation Method: Minimum Curvature Design: ODSK -13PB1 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N!-S +E / -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 3,239.01 61.30 359.87 2,827.65 2,771.45 1,048.87 - 490.51 6,032,126.80 469,359.61 4.29 950.88 MWD +IFR2 +MS +sag (2) 3,332.55 64.45 1.07 2,870.29 2,814.09 1,132.10 - 489.82 6,032,210.02 469,360.64 3.56 1,033.03 MWD +IFR2 +MS +sag (2) 3,429.23 64.20 1.45 2,912.18 2,855.98 1,219.21 - 487.90 6,032,297.12 469,362.91 0.44 1,119.22 MWD +IFR2 +MS +sag (2) 3,468.28 63.59 2.08 2,929.36 2,873.16 1,254.26 - 486.82 6,032,332.16 469,364.13 2.13 1,153.95 MWD +IFR2 +MS +sag (2) 3,555.82 63.39 2.74 2,968.43 2,912.23 1,332.53 - 483.53 6,032,410.41 469,367.74 0.71 1,231.64 MWD +IFR2 +MS +sag (3) 3,578.71 62.75 2.28 2,978.80 2,922.60 1,352.92 - 482.63 6,032,430.79 469,368.72 3.32 1,251.89 MWD +IFR2 +MS +sag (3) 3,677.09 61.59 5.97 3,024.74 2,968.54 1,439.67 - 476.39 6,032,517.51 469,375.31 3.52 1,338.45 MWD +IFR2 +MS +sag (3) 3,770.79 62.04 10.47 3,069.02 3,012.82 1,521.38 - 464.58 6,032,599.16 469,387.45 4.26 1,420.98 MWD +IFR2 +MS +sag (3) 3,866.65 62.81 14.30 3,113.40 3,057.20 1,604.35 - 446.35 6,032,682.05 469,406.01 3.63 1,505.83 MWD +IFR2 +MS +sag (3) 3,960.85 62.51 16.53 3,156.67 3,100.47 1,685.01 - 424.11 6,032,762.61 469,428.58 2.13 1,589.09 MWD +IFR2 +MS +sag (3) 4,055.97 63.27 19.06 3,200.02 3,143.82 1,765.62 - 398.24 6,032,843.10 469,454.78 2.50 1,672.91 MWD +IFR2 +MS +sag (3) 4,151.57 63.95 22.84 3,242.53 3,186.33 1,845.57 - 367.62 6,032,922.92 469,485.72 3.61 1,756.89 MWD +IFR2 +MS +sag (3) 4,246.13 64.78 26.99 3,283.45 3,227.25 1,922.86 - 331.70 6,033,000.06 469,521.94 4.05 1,839.14 MWD +IFR2 +MS +sag (3) 4,341.23 64.57 30.27 3,324.14 3,267.94 1,998.30 - 290.52 6,033,075.32 469,563.42 3.13 1,920.45 MWD +IFR2 +MS +sag (3) 4,435.82 64.23 32.53 3,365.01 3,308.81 2,071.10 - 246.09 6,033,147.94 469,608.15 2.18 1,999.72 MWD +IFR2 +MS +sag (3) 4,531.81 63.49 34.47 3,407.31 3,351.11 2,142.96 - 198.53 6,033,219.59 469,655.99 1.97 2,078.58 MWD +IFR2 +MS +sag (3) 4,626.75 63.88 36.82 3,449.40 3,393.20 2,212.11 - 148.94 6,033,288.53 469,705.86 2.26 2,155.11 MWD +IFR2 +MS +sag (3) 4,721.33 64.39 38.83 3,490.66 3,434.46 2,279.32 -96.75 6,033,355.53 469,758.32 1.99 2,230.18 MWD +IFR2 +MS +sag (3) 4,817.23 64.79 41.08 3,531.82 3,475.62 2,345.72 -41.13 6,033,421.69 469,814.20 2.16 2,305.02 MWD +IFR2 +MS +sag (3) 4,912.03 64.23 40.84 3,572.61 3,516.41 2,410.34 14.97 6,033,486.07 469,870.56 0.63 2,378.19 MWD +IFR2 +MS +sag (3) 5,006.90 64.64 41.25 3,613.55 3,557.35 2,474.88 71.17 6,033,550.38 469,927.01 0.58 2,451.31 MWD +IFR2 +MS +sag (3) 64.93 39.96 3 653.82 3 597.62 2 539.80 126.82 6 033 615.07 469 982.92 1.27 2 524.70 MWD+IFR2+MS+sag 3 5,101.42 � 9 ( ) 5,196.84 65.06 40.99 3,694.16 3,637.96 2,605.58 182.95 6,033,680.62 470,039.31 0.99 2,599.02 MWD +IFR2 +MS +sag (3) 5,291.68 64.77 40.39 3,734.37 3,678.17 2,670.71 238.95 6,033,745.51 470,095.57 0.65 2,672.68 MWD +IFR2 +MS +sag (3) 5,386.51 64.54 41.16 3,774.96 3,718.76 2,735.61 294.92 6,033,810.18 470,151.80 0.77 2,746.10 MWD +IFR2 +MS +sag (3) 5,481.66 64.68 41.22 3,815.76 3,759.56 2,800.30 351.53 6,033,874.63 470,208.66 0.16 2,819.43 MWD +IFR2 +MS +sag (3) 5,576.70 64.71 41.47 3,856.38 3,800.18 2,864.80 408.29 6,033,938.90 470,265.68 0.24 2,892.60 MWD +IFR2 +MS +sag (3) 5,670.97 64.95 40.30 3,896.48 3,840.28 2,929.31 464.13 6,034,003.16 470,321.78 1.15 2,965.61 MWD +IFR2 +MS +sag (3) 5,766.10 65.25 38.59 3,936.53 3,880.33 2,995.94 518.95 6,034,069.57 470,376.86 1.66 3,040.55 MWD +IFR2 +MS +sag (3) 5,861.55 65.54 38.12 3,976.27 3,920.07 3,063.99 572.80 6,034,137.39 470,430.98 0.54 3,116.72 MWD +IFR2 +MS +sag (3) 5,956.37 65.14 39.26 4,015.84 3,959.64 3,131.25 626.67 6,034,204.43 470,485.11 1.17 3,192.12 MWD +IFR2 +MS +sag (3) 6,051.38 65.29 38.93 4,055.67 3,999.47 3,198.20 681.06 6,034,271.14 470,539.77 0.35 3,267.29 MWD +IFR2 +MS +sag (3) 6,145.92 65.05 38.54 4,095.37 4,039.17 3,265.12 734.75 6,034,337.85 470,593.72 0.45 3,342.33 MWD +IFR2 +MS +sag (3) 6,241.44 64.90 39.62 4,135.77 4,079.57 3,332.31 789.31 6,034,404.81 470,648.55 1.04 3,417.77 MWD +IFR2 +MS +sag (3) 6,337.01 64.85 40.68 4,176.35 4,120.15 3,398.45 845.10 6,034,470.71 470,704.61 1.01 3,492.39 MWD +IFR2 +MS +sag (3) 6,432.40 64.93 40.88 4,216.83 4,160.63 3,463.85 901.52 6,034,535.88 470,761.28 0.21 3,566.39 MWD +IFR2 +MS +sag (3) 6,526.91 66.06 40.29 4,256.03 4,199.83 3,529.16 957.46 6,034,600.95 470,817.48 1.32 3,640.21 MWD +IFR2 +MS +sag (3) 6,621.96 66.00 40.37 4,294.65 4,238.45 3,595.37 1,013.67 6,034,666.93 470,873.96 0.10 3,714.97 MWD +IFR2 +MS +sag (3) 6,717.88 65.21 38.37 4,334.27 4,278.07 3,662.90 1,069.09 6,034,734.22 470,929.64 2.07 3,790.89 MWD +IFR2 +MS +sag (3) 6,812.62 64.24 37.19 4,374.72 4,318.52 3,730.60 1,121.57 6,034,801.71 470,982.39 1.52 3,866.49 MWD +IFR2 +MS +sag (3) 922/2011 1 :52:47PM Page 4 COMPASS 2003.16 Build 42 � t • Pioneer Natural Resources • Definitive Survey Report Company: Well Planning - Pioneer - Oooguruk Local Co- ordinate Reference: Well ODSK -13 - Slot ODS -13 Project: Oooguruk Development TVD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Well: ODSK -13 North Reference: True Wellbore: ODSK -13PB1 Survey Calculation Method: Minimum Curvature Design: ODSK -13PB1 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N /-S +EI -W Northing Easting DLS Section (ft) ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 6,907.44 64.22 37.11 4,415.94 4,359.74 3,798.67 1,173.14 6,034,869.55 471,034.23 0.08 3,942.29 MWD +IFR2 +MS +sag (3) 7,002.96 63.92 38.41 4,457.71 4,401.51 3,866.58 1,225.74 6,034,937.24 471,087.10 1.26 4,018.11 MWD +IFR2 +MS +sag (3) 7,097.97 64.36 39.31 4,499.15 4,442.95 3,933.15 1,279.38 6,035,003.59 471,141.01 0.97 4,092.79 MWD +IFR2 +MS +sag (3) 7,193.33 62.83 38.02 4,541.56 4,485.36 3,999.83 1,332.75 6,035,070.05 471,194.63 2.01 4,167.54 MWD +IFR2 +MS +sag (3) 7,288.50 62.64 36.54 4,585.16 4,528.96 4,067.14 1,383.99 6,035,137.14 471,246.14 1.40 4,242.54 MWD +IFR2 +MS +sag (3) 7,383.33 62.35 35.16 4,628.96 4,572.76 4,135.31 1,433.25 6,035,205.11 471,295.67 1.33 4,318.05 MWD +IFR2 +MS +sag (3) 7,479.51 61.83 33.70 4,673.98 4,617.78 4,205.41 1,481.30 6,035,275.01 471,344.01 1.45 4,395.27 MWD +IFR2 +MS +sag (3) 7,574.86 61.54 31.91 4,719.21 4,663.01 4,275.96 1,526.78 6,035,345.36 471,389.76 1.68 4,472.49 MWD +IFR2 +MS +sag (3) 7,670.10 61.18 31.24 4,764.86 4,708.66 4,347.17 1,570.54 6,035,416.39 471,433.82 0.72 4,550.07 MWD +IFR2 +MS +sag (3) 7,765.07 60.83 29.78 4,810.90 4,754.70 4,418.74 1,612.72 6,035,487.77 471,476.27 1.39 4,627.73 MWD +IFR2 +MS +sag (3) 7,859.90 60.68 27.85 4,857.23 4,801.03 4,491.23 1,652.60 6,035,560.09 471,516.44 1.78 4,705.92 MWD +IFR2 +MS +sag (3) 7,955.59 61.13 26.66 4,903.76 4,847.56 4,565.56 1,690.88 6,035,634.26 471,555.03 1.18 4,785.65 MWD +IFR2 +MS +sag (3) 8,050.02 60.50 24.71 4,949.81 4,893.61 4,639.85 1,726.62 6,035,708.40 471,591.06 1.92 4,864.91 MWD +IFR2 +MS +sag (3) 8,145.69 60.06 22.42 4,997.24 4,941.04 4,716.00 1,759.83 6,035,784.40 471,624.58 2.13 4,945.58 MWD +IFR2 +MS +sag (3) 8,240.52 59.99 20.69 5,044.63 4,988.43 4,792.39 1,790.01 6,035,860.67 471,655.07 1.58 5,025.97 MWD +IFR2 +MS +sag (3) 8,335.23 59.30 17.78 5,092.50 5,036.30 4,869.54 1,816.94 6,035,937.70 471,682.30 2.75 5,106.56 MWD +IFR2 +MS +sag (3) 8,432.15 58.84 15.07 5,142.32 5,086.12 4,949.27 1,840.45 6,036,017.33 471,706.13 2.44 5,189.12 MWD +IFR2 +MS +sag (3) 8,526.58 58.97 12.58 5,191.09 5,134.89 5,027.78 1,859.77 6,036,095.75 471,725.77 2.26 5,269.77 MWD +IFR2 +MS +sag (3) 8,621.41 58.41 8.92 5,240.39 5,184.19 5,107.36 1,874.88 6,036,175.25 471,741.21 3.35 5,350.75 MWD +IFR2 +MS +sag (3) 8,716.41 57.63 7.17 5,290.70 5,234.50 5,187.14 1,886.17 6,036,254.98 471,752.81 1.77 5,431.30 MWD +IFR2 +MS +sag (3) 8,812.24 57.64 5.02 5,342.01 5,285.81 5,267.62 1,894.76 6,036,335.42 471,761.73 1.90 5,512.07 MWD +IFR2 +MS +sag (3) 8,907.18 57.23 2.25 5,393.11 5,336.91 5,347.46 1,899.84 6,036,415.23 471,767.13 2.50 5,591.62 MWD +IFR2 +MS +sag (3) 9,001.87 55.89 0.36 5,445.30 5,389.10 5,426.45 1,901.64 6,036,494.20 471,769.26 2.19 5,669.77 MWD +IFR2 +MS +sag (3) 9,097.31 55.81 359.30 5,498.87 5,442.67 5,505.43 1,901.41 6,036,573.17 471,769.34 0.92 5,747.58 MWD +IFR2 +MS +sag (3) 9,192.55 56.55 357.79 5,551.88 5,495.68 5,584.52 1,899.40 6,036,652.27 471,767.65 1.53 5,825.20 MWD +IFR2 +MS +sag (3) 9,224.00 56.55 357.79 5,569.22 5,513.02 5,610.74 1,898.39 6,036,678.49 471,766.75 0.00 5,850.87 PROJECTED to TD 9/22/2011 1:52:47PM Page 5 COMPASS 2003.16 Build 42 • 1111 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, September 26, 2011 9:49 AM To: 'Johnson, Vern' Cc: 'Tirpack, Robert'; DOA AOGCC Prudhoe Bay Subject: RE: ODSK 13 (PTD 289 -146): be Vern, We discussed internally and a continued 14 day BOP test cycle is acceptable. Obviously test 7" rams before pulling the tieback liner. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) Original Message From: Schwartz, Guy L (DOA) Sent: Monday, September 26, 2011 9:04 AM To: 'Johnson, Vern' Cc: Tirpack, Robert Subject: RE: ODSK -13 (PTD 209 -146) Update Thanks for the update. I checked with Commissioner Foerster this morning and we agree a "Change of Program" sundry will not be required for this operation since you are not changing the casing program ... just replacing a tieback liner. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) Original Message From: Johnson, Vern [mailto:Vern.Johnson @pxd.com] Sent: Sunday, September 25, 2011 10:45 PM To: Schwartz, Guy L (DOA) Subject: RE: ODSK -13 (PTD 209 -146) Update Guy, As discussed this afternoon, we have changed our plan based on the condition of the -900 ft of 7" BTCM casing we pulled from the well. The many of the casing joints we pulled had loose connections, so we have decided to pull the remainder of the tie -back string. Prior to pulling the string we will pull the test packer assembly, and place a retrievable packer below the tie back, spot sand on top, then spear the tie -back string and pull it. There is lighter mud in the 7" x 11 -3/4 annulus than there is in the 7" casing, so we will circulate out the lighter mud on the rig chokes until the system is balanced, then pull the string, replace it, then retrieve the packer. Let me know if you have any questions. I will call in the morning to discuss. Vern From: Schwartz, Guy L (DOA) [guy.schwartz @alaska.gov] Sent: Saturday, September 24, 2011 10:07 AM 1 To: Johnson, Vern Cc: Tirpack, Robert Subject: Re: ODSK -13 (PTD 209 -146) Vern, You have verbal approval for continuing the operations on ODSK -13 as outlined below. If the operation changes significantly from plan give a call this weekend. Guy Sent from my iPhone On Sep 23, 2011, at 8:40 PM, "Johnson, Vern" <Vern.Johnson @pxd.com> wrote: > Guy, > As discussed, after having problems while running an ESP completion assembly in 7" casing, we performed a casing test with a test packer to confirm integrity. The 7" casing failed, and we are now in the process of repairing the casing string. The steps we have outlined so far are below. Depending on what the failure mode of the casing is, we may have to alter the plan. > 1. Unset test packer. > 2. Flow check well 10 min > 3. POOH 1900 ft (keeping test packer no shallower than 900' MD) (muleshoe- 8400' MD) > 4. Install storm valve > 5. Run in hole 3000 and set test packer at -5800' MD > 6. Test packer to 2000 psi for 10 min > 7. Disconnect from storm valve with right hand rotation > 8. POOH with drillpipe and lay down storm valve running tool > 9. Change rams to 7" and test BOP > 10. Check for OA (7" x 11 -3/4 ") pressure, if zero, pull 7" casing pack off > 11. Pick up landing joint > 12. Back out lock down screws on casing hanger and pull 30000 lb tension to check if 7" casing is parted > 13. If casing pulls free, POOH with 7" casing from 900 ft > 14. Pick up and run in hole with Baker back off tool > 15. Back off 7" casing at - 2100' MD > 16. Pull out of hole with back off tool > 17. Pick up and run in hole with 7" casing spear > 18. Spear 7" casing, pull out of hole and lay down casing and fishing > assembly > 19. Run in hole with triple bushing, 7" TAM port collar and > -2100' of casing 2 > 20. Screw into casing stub, and set 7" casing in slips. > 21. cut casing, set and test packoff, change rams back to variables and test BOPs. > 22. Run in hole with storm valve running tool > 23. Engage storm valve and unset test packer > 24. Pull out of hole with test packer assembly and lay down same. > 25. Pick up new test packer and run in hole. > 26. Test casing from below tie back seals to 3500 psi for 30 min > 27. Pull out of hole and lay down test assembly > 28. Pick up and run in hole with TAM combo tool > 29. Open port collar and displace outer annulus to diesel freeze protection > 30. Pull out of hole with TAM combo tool > 31. Run ESP completion > We will have to react to actual results, but this is our current plan forward. > > Let me know if you have any questions > Vern > 575 -9430 > Statement of Confidentiality: > This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. > 3 r 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Sunday, August 28, 2011 10:30 AM To: Peltier, Brandon Cc: Vaughan, Alex; Johnson, Vem; Tirpack, Robert; OoogurukDrillingSupervisor Subject: Re: ODSK -13 (PTD# 2( 1.46) Pilot Hole Abandonment Summary Brandon, Thanks for the notice. This minor change in equipment is acceptable. Guy Sent from my iPhone On Aug 27, 2011, at 5:38 PM, "Peltier, Brandon" <Brandon.Peltier @pxd.com> wrote: > Guy > There will be a minor change to the plan outlined below. After a discussion at the rig, we have decided to use a 4" drill pipe stinger to place cement, instead of a 3.5 " TC -II stinger. This will allow us to rotate and reciprocate cement off the top of our plug. There are no other changes. > Feel free to call of you have any questions. > Thanks, > Brandon Peltier > 229- 7545(cell) > 344 -0531 (home) > Guy, > The following is a summary of PNR's plans to abandoned the ODSK -13 (PTD# 209 -146) Pilot hole prior to kicking off out of the 9 -5/8" shoe to drill and complete the Kuparuk lateral producer as originally permitted. > 1. Drill 8- 1 /2 <x- apple- data - detectors: / /1 >" Pilot Hole to TD. > 2. Circulate and condition hole. > 3. Perform short trip to 9 -5/8" shoe. > 4. Circulate and condition casing. > 5. RIH to TD and displace mud system to 13.0 ppg to achieve static borehole stability. > 6. RD the MPD bearing assembly and RU MPD trip nipple. > 7. POOH and P/U 3 -1/2" cement stinger on 5" DP. > 8. RIH and set abandonment plugs as per AOGCC regulation 20 AAC 25.112. > • Provide AOGCC with 24 hours notice of plugging operation. > • Set first 15.8 ppg balance plug from TD to 10,435' MD. This will cover the Nechelik, Nuiqsut, and Kuparuk. > • Set second 15.8 ppg balance plug on top of plug 1 to 9,685' MD > • Set 16.4 ppg kick -off balance plug on top of plug 2 to 8,935' MD. This will place the TOC 163' MD inside the 9 -5/8" shoe > 1. POOH & MU 8 -1/2" x 9 -1/2" RSS, MWD /LWD on 5" DP. > 2. RIH to top of kick -off plug at 8,935' MD. > 3. Dress off the top of the kick off plug and set 10,000 psi to > ensure abandonment plug is competent as per AOGCC regulation 20 AAC 25.112 gl 4. RD MPD trip nipple RU the MPD bearing assembly. > 5. Displace mud system to 9.8 -10.0 ppg LNSD (13.0 ppg via MPD) 6. > Kick off at 9,158' MD / 5,455' TVD. > 7. Drill ahead as per original ODSK -13 PTD # 209 -146. 1 r i Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, August 26, 2011 1:59 PM To: 'Vaughan, Alex' Cc: Campoamor, Kathy Subject: RE: ODSK -13 (PTD# 209 -146) Pilot Hole Abandonment Summary Alex, As per our conversation, you need to tag only the very top cement plug at 8935'md. As we discussed make sure the displacement is tracked and documented by the driller Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793 (office) 444 -3433 (cell) From: Vaughan, Alex [mailto:Alex.Vaughan @pxd.com] Sent: Friday, August 26, 2011 12:40 PM To: Schwartz, Guy L (DOA) Cc: Campoamor, Kathy Subject: ODSK -13 (PTD# 209 -146) Pilot Hole Abandonment Summary Guy, The following is a summary of PNR's plans to abandoned the ODSK -13 (PTD# 209 -146) Pilot hole prior to kicking off out of the 9 -5/8" shoe to drill and complete the Kuparuk lateral producer as originally permitted. 1. Drill 8 -1/2" Pilot Hole to TD. 2. Circulate and condition hole. 3. Perform short trip to 9 -5/8" shoe. 4. Circulate and condition casing. 5. RIH to TD and displace mud system to 13.0 ppg to achieve static borehole stability. 6. RD the MPD bearing assembly and RU MPD trip nipple. 7. POOH and P/U 3 -1/2" cement stinger on 5" DP. 8. RIH and set abandonment plugs as per AOGCC regulation 20 AAC 25.112. • Provide AOGCC with 24 hours notice of plugging operation. • Set first 15.8 ppg balance plug from TD to 10,435' MD. This will cover the Nechelik, Nuiqsut, and Kuparuk. • Set second 15.8 ppg balance plug on top of plug 1 to 9,685' MD • Set 16.4 ppg kick -off balance plug on top of plug 2 to 8,935' MD. This will place the TOC 163' MD inside the 9 -5/8" shoe 9. POOH & MU 8 -1/2" x 9 -1/2" RSS, MWD /LWD on 5" DP. 10. RIH to top of kick -off plug at 8,935' MD. 11. Dress off the top of the kick off plug and set 10,000 psi to ensure abandonment plug is competent as per AOGCC regulation 20 AAC 25.112 g1 8/26/2011 Page 2 of 2 r r • 12. RD MPD trip nipple RU the MPD bearing assembly. 13. Displace mud system to 9.8 -10.0 ppg LNSD (13.0 ppg via MPD) 14. Kick off at 9,158' MD / 5,455' TVD. 15. Drill ahead as per original ODSK -13 PTD # 209 -146. I will follow this with a phone call to discuss any concerns you may have. Alex Vaughan Senior Drilling Engineer PIONEER NATURAL RESOURCES 907.343.2186 (office) 907.748.5478 (mobile) Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 8/26/2011 f( • • . PIONEER p-rp Zoe -- 4 NATURAL RESOURCES Gentlemen; Review of H incident at Pioneer Natural Resources Oooguruk project, Well # ODSK -13i, Nabors Rig 19AC. Operations at time of incident; Pumping out of the hole at 7,049' md, 4,478' tvd. At approximately 0100 hrs on 8 -7 -11 the H monitor in the pits showed 10 ppm. Driller picked up off bottom, shutdown pumps to monitor well, well static. Driller instructed floorhand to take a handheld monitor to pits and check for redundant readings to verify pit monitor accuracy. At 0123 hrs while verifying H readings in pits gas units increased to 25 ppm. At this time evacuation alarms automatically activated and all personnel mustered to secondary muster area as per procedure. Tourpusher and floorhand donned Scott Air Packs and shut the well in, observed no SIDPP or SICP. While exiting rig tourpusher a floorhand shut down all pit equipment on their way to the muster area. At 0126 hrs H reading was at 14 ppm. Head count was taken and all personnel accounted for. Pioneer Wellsite Leader, Nabors Toolpusher, Pioneer Safety & ACS Specialist were notified @ 0125 hrs. Pioneer Safety monitored wind direction and H readings at camp in anticipation of camp evacuation. No gas was detected in and around camp area. At 0230 hrs Nabors tourpusher and Pioneer Safety reentered the rig with Pioneer H monitoring equipment. Proceeded to the remote gas monitoring panel to check status of pit area. Remote panel read between 3 & 4 ppm. Proceeded to pit area with hand held monitor and took readings. Hand held read 4 ppm. No H readings throughout rest of rig. At 0300 hrs an All Clear Call was made and personnel returned to their work stations. Upon return to rig floor shut in pressures were 0 psi. Well was opened to atmosphere. Incident Review; Held discussion with pit crew and discovered at ± 1230 hrs they had started to roll the 11.5 ppg mud in pit # 2 in preparation aldicide and caustic treatment. This mud was going to be utilized for the weight up displacement prior to running the 9-5/8" drilling liner. It had been stored in pit #2 for 3 days without movement. Took individual pit H gas readings and discovered the 11.5 ppg mud Pit #2 had turned sour. Pit #3 which we suspected was the pit that had the H gas cut mud was clean. During the process of rolling over the mud it pit #2 the H gas broke out causing the pit monitor to register the high reading. The gas monitor that recorded the high H reading is hard mounted at floor grate level between pits #2 and #3. The 11.5 ppg mud in pit #2 was treated with aldicide, caustic soda & No -Suf (H scavenger) to remove the H gas. Rodney C. Klepzig PNR Senior Drilling Supervisor Page 1 of 2 • • Schwartz, Guy L (DOA) From: Vaughan, Alex [AIex.Vaughan @pxd.com] Sent: Thursday, August 11, 2011 11:42 AM To: Schwartz, Guy L (DOA) Cc: Tirpack, Robert; Campoamor, Kathy Subject: ODSK -13, PNR, H2S Lessons Learned Guy, The following mud pit maintenance procedures will be implemented for future operations. Both of these were in place previous to the H2S incident but were overlooked at the time due to competing demand for attention by rig personnel with the concomitant hole problems. • Rig pits that are not part of the active circulating system will be rolled preferably once every 12 hour period and a minimum of once daily. • The pH will be checked to ensure the fluid is not being affected by bacterial degradation, resulting in the formation of H2S, a minimum of once daily. Further information can be supplied upon request. Alex Vaughan Senior Drilling Engineer PIONEER NATURAL RESOURCES 907.343.2186 (office) 907.748.5478 (mobile) From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, August 08, 2011 4:02 PM To: Vaughan, Alex Cc: Tirpack, Robert; Regg, James B (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: RE: H2S Incident Review Alex, Thank you for the report. I don't think any other follow -up reports are needed for the AOGCC other than documenting what lessons were learned and how will you prevent this occurrence in the future. It appears your drilling contractors responded appropriately. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Vaughan, Alex [mailto:Alex.Vaughan @pxd.com] Sent: Monday, August 08, 2011 9:14 AM To: Schwartz, Guy L (DOA) Cc: Tirpack, Robert Subject: RE: H2S Incident Review 8/11/2011 Page 2 of 2 Guy, As per our phone call this morning please review the attached email. I would be happy to answer any questions you have. This document was sent the doa .aogcc.prudhoe.bay @alaska.gov yesterday. Alex Vaughan Senior Drilling Engineer PIONEER NATURAL RESOURCES 907.343.2186 (office) 907.748.5478 (mobile) From: OoogurukDrillingSupervisor Sent: Sunday, August 07, 2011 2:44 PM To: DOA AOGCC Prudhoe Bay; OoogurukDrillingSupervisor; Rick Bjorhus; Rob Tirpack (Robert.Tirpack @pxd.com); Vaughan, Alex (AIex.Vaughan @pxd.com) Cc: Rodney C. Klepzig (Rod.Klepzig @pxd.com) Subject: H2S Incident Review RoAg C"i• /�ei�(2 f Pioneer Wellsite Leader Pioner Natural Resources Alaska, Inc. Office # 907 - 670 - 6606 CeII # 907 -440 -9994. This email was sent on 8/7/11 at 2:44 PM by klepzigr. Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. This e -mail, including any attached files, may contain confidential and privileged information for the sole use of the intended recipient. Any review, use, distribution, or disclosure by others is strictly prohibited. If you are not the intended recipient (or authorized to receive information for the intended recipient), please contact the sender by reply e -mail and delete all copies of this message. 8/11/2011 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, August 08, 2011 7:02 PM To: Vaughan, Alex Cc: Tirpack, Robert; Daggett, Paul; Campoamor, Kathy; Johnson, Vern; Davies, Stephen F (DOA) Subject: Re: ODSK -13 Torok Log PTD p-r) zo'i -N Alex, As we discussed , the Torok is not a significant hydrocarbon zone. Setting a kickoff plug at the surface shoe is acceptable for abandoning this section of the wellbore. Regards, ("LA__ 4b ca (4 ;41) .54 Guy Schwartz ' Sent from my iPhone 74 On Aug 8, 2011, at 5:27 PM, "Vaughan, Alex" <Alex.Vaughan @pxd.com> wrote: > Guy, > As discussed via telephone and in your office please see attached > ODSK -13 log of the Torok formation. > Alex Vaughan > Senior Drilling Engineer > > 907.343.2186 (office) > 907.748.5478 (mobile) > From: Daggett, Paul > Sent: Monday, August 08, 2011 5:02 PM > To: Vaughan, Alex > Subject: ODSK -13 Torok Log > Alex, > Here's the Torok log for ODSK -13. > Paul > Paul Daggett > Oooguruk Operations Geologist > Pioneer Natural Resources > 700 G Street, Suite 600 1 % V PIONEER Well: OD SK -13 COMPANY: DATUM FOR ELEVATION: 56.2 LOCATION: SURFACE ELEVATION: - LATITUDE: - MEASUREMENT REF.: RKB LONGITUDE: - ELEVATION MEAS. REF.: 56.20 X COORDINATE: 469845.81 DRILLED DEPTH: - TVD FEET LWD_RT.ABG 1 102 38 145 0'. DEPTH LWD RT.SROP 1 LWD RT.R15P 1 FEET 400 m EPEE m m 01E!@2G 100 LWD RT.SGRC_I LWD RT.R39P 1 DIRE. TIONAL.D o. — • .., nHNAA 100 90 ....a BROOK2B MKR — 84(i0 — — � 54 ��_`- • 8500 — - 5 — 8550 8600 8650 TOROK j`' TNUNASS — 8700 263 . - 5300 • - 8800 - 8900 - 5400 — • 9000 B NUNA_SS • . • • Page l of l Regg, James B (DOA) From: Crisp, John H (DOA) PTO ZO? - Sent: Sunday, August 07, 2011 7:25 AM hef &I `"( To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay Subject: Well shut in PNR ODSK 13i Received a page from WSL Rodney Klepzig about 0130 hrs that they had H2S alarm set off in pits & they shut the well in. I didn't know what I could accomplish by contacting the Rig at that time so I went back to sleep. Another contact at 0300 hrs. by WSL Joey Cortez that the well was open & they were CBU as a precaution. I called the Rig at 0600 for more info. Requested an E mail for information, bottom line for PNR is that the sensor was activated by sour gas in a pit next to the active system. Bottom line for AOGCC as I see it is that the State required gas detectors worked as required because they are always tested by State Inspectors. More info on the way from PNR. 8/8/2011 • • Page 1 of 1 Regg, James B (DOA) From: OoogurukDrillingSupervisor [ Oooguruk .DrillingCompanyMan @pxd.com] 1'' b 2,0 T — 4 Sent: Sunday, August 07, 2011 2:44 PM To: DOA AOGCC Prudhoe Bay; OoogurukDrillingSupervisor; Rick Bjorhus; Robert.Tirpack @pxd.com; AIex.Vaughan @pxd.com Cc: Rod.Klepzig @pxd.com Subject: H2S Incident Review Attachments: H2S Incident 8- 7- 11.docx Pioneer Wellsite Leader Pioner Natural Resources Alaska, Inc. Office # 907 - 670 -6606 Cell # 907 - 440 -9994. This email was sent on 8/7/11 at 2:44 PM by klepzigr. Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 8/8/2011 *PIONEER NATURAL RESOURCES Gentlemen; PTO ZO9 — j 4 Review of H incident at Pioneer Natural Resources Oooguruk project, Well # ODSK -13i, Nabors Rig 19AC. Operations at time of incident; Pumping out of the hole at 7,049' md, 4,478' tvd. At approximately 0100 hrs on 8 -7 -11 the H monitor in the pits showed 10 ppm. Driller picked up off bottom, shutdown pumps to monitor well, well static. Driller instructed floorhand to take a handheld monitor to pits and check for redundant readings to verify pit monitor accuracy. At 0123 hrs while verifying H readings in pits gas units increased to 25 ppm. At this time evacuation alarms automatically activated and all personnel mustered to secondary muster area as per procedure. Tourpusher and floorhand donned Scott Air Packs and shut the well in, observed no SIDPP or SICP. While exiting rig tourpusher a floorhand shut down all pit equipment on their way to the muster area. At 0126 hrs H reading was at 14 ppm. Head count was taken and all personnel accounted for. Pioneer Wellsite Leader, Nabors Toolpusher, Pioneer Safety & ACS Specialist were notified @ 0125 hrs. Pioneer Safety monitored wind direction and H readings at camp in anticipation of camp evacuation. No gas was detected in and around camp area. At 0230 hrs Nabors tourpusher and Pioneer Safety reentered the rig with Pioneer H monitoring equipment. Proceeded to the remote gas monitoring panel to check status of pit area. Remote panel read between 3 & 4 ppm. Proceeded to pit area with hand held monitor and took readings. Hand held read 4 ppm. No H readings throughout rest of rig. At 0300 hrs an All Clear Call was made and personnel returned to their work stations. Upon return to rig floor shut in pressures were 0 psi. Well was opened to atmosphere. Incident Review; Held discussion with pit crew and discovered at ± 1230 hrs they had started to roll the 11.5 ppg mud in pit # 2 in preparation aldicide and caustic treatment. This mud was going to be utilized for the weight up displacement prior to running the 9 -5/8" drilling liner. It had been stored in pit #2 for 3 days without movement. Took individual pit H gas readings and discovered the 11.5 ppg mud Pit #2 had turned sour. Pit #3 which we suspected was the pit that had the H gas cut mud was clean. During the process of rolling over the mud it pit #2 the H2S gas broke out causing the pit monitor to register the high reading. The gas monitor that recorded the high H reading is hard mounted at floor grate level between pits #2 and #3. The 11.5 ppg mud in pit #2 was treated with aldicide, caustic soda & No -Suf (H scavenger) to remove the H gas. Rodney C. Klepzig PNR Senior Drilling Supervisor Page 1 of 2 • Schwartz, Guy L (DOA) From: Vaughan, Alex [AIex.Vaughan ©pxd.com] Sent: Monday, August 01, 2011 2:47 PM To: Schwartz, Guy L (DOA) Cc: Tirpack, Robert; Campoamor, Kathy Subject: ODSK -13 (PTD) #209 -146 Notification of Spud Guy, As requested Pioneer is notifying you of the Spud of ODSK -13 intermediate 2 section on July 29 2011. Please contact me if further information is required. Enjoy your vacation. Alex Vaughan Senior Drilling Engineer PIONEER NATURAL RESOURCES 907.343.2186 (office) 907.748.5478 (mobile) From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Friday, July 15, 2011 11:35 AM To: Vaughan, Alex Cc: Tirpack, Robert; Campoamor, Kathy; OoogurukDrillingSupervisor; Johnson, Vern Subject: RE: ODSK -13 (PTD) #209 -146 Alex, Thanks for the email. This will suffice since you are so close to starting up operations again on ODSK -13. As stated below notify by email when you move on the well also. We won't require another 403 in this case. As we discussed I checked into email or written request for renewal of the Op shutdown in lieu of anther Sundry application (see 20 AAC 25.072 (d) ) . The regulations don't give much leeway as the commissioners have to approve the extension so using another 403 sundry is the only way (after the first 12 months are up). We are aware of your drilling season restrictions and understand your time constraints . Can you give me a list of any other Op Shutdown status wells? You mentioned there is one more. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Vaughan, Alex [mailto:Alex.Vaughan @pxd.com] Sent: Friday, July 15, 2011 11:20 AM To: Schwartz, Guy L (DOA) Cc: Tirpack, Robert; Campoamor, Kathy; OoogurukDrillingSupervisor; Johnson, Vern Subject: ODSK -13 (PTD) #209 -146 8/4/2011 Page 2 of 2 Guy, Pioneer is intended to re -enter ODSK -13 (PTD) #209 -146 the week of July 17 (next week). ODSK -13 was under Operations Shutdown due to seasonal restrictions related to drilling through the Kuparuk formation. As requested Pioneer will send a second email when we actually move over ODSK -13 to confirm continuation of operations. Further information can be supplied upon request. Thanks and have a good weekend. Alex Vaughan Senior Drilling Engineer PIONEER NATURAL RESOURCES 907.343.2186 (office) 907.748.5478 (mobile) Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please noti the sender by reply e -mail and delete the message and any attachments. 8/4/2011 r Page 1 of • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, July 15, 2011 11:35 AM To: Vaughan, Alex' Cc: Tirpack, Robert; Campoamor, Kathy; OoogurukDrillingSupervisor; Johnson, Vern Subject: RE: ODSK -13 (PTD) #209 -146 Alex, Thanks for the email. This will suffice since you are so close to starting up operations again on ODSK -13. As stated below notify by email when you move on the well also. We won't require another 403 in this case. As we discussed I checked into email or written request for renewal of the Op shutdown in lieu of anther Sundry application (see 20 AAC 25.072 (d) ) . The regulations don't give much leeway as the commissioners have to approve the extension so using another 403 sundry is the only way (after the first 12 months are up). We are aware of your drilling season restrictions and understand your time constraints . Can you give me a list of any other Op Shutdown status wells? You mentioned there is one more. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Vaughan, Alex [mailto:Alex.Vaughan @pxd.com] Sent: Friday, July 15, 2011 11:20 AM To: Schwartz, Guy L (DOA) Cc: Tirpack, Robert; Campoamor, Kathy; OoogurukDrillingSupervisor; Johnson, Vern Subject: ODSK -13 (PTD) #209 -146 Guy, Pioneer is intended to re -enter ODSK -13 (PTD) #209 -146 the week of July 17 (next week). ODSK -13 was under Operations Shutdown due to seasonal restrictions related to drilling through the Kuparuk formation. As requested Pioneer will send a second email when we actually move over ODSK -13 to confirm continuation of operations. Further information can be supplied upon request. Thanks and have a good weekend. Alex Vaughan Senior Drilling Engineer PIONEER NATURAL RESOURCES 907.343.2186 (office) 907.748.5478 (mobile) 7/15/2011 • [IF n[1=InS / 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 Alex Vaughan Operations Drilling Manager Pioneer Natural Resources 700 G Street Anchorage, Alaska 99501 Re: Oooguruk, Kuparuk Oil Pool, ODSK -13 Pioneer Natural Resources Alaska, Inc. Permit No: 209 -146 (revised) Surface Location: 2960' FSL, 1152' FEL, SEC. 11, T13N, R7E, UM Bottomhole Location: 3414 FSL, 3156' FEL, SEC. 35, T13N, R7E, UM Dear Mr. Vaughan: Enclosed is the approved application for permit to drill the above referenced development well. This permit supersedes and replaces Permit Number 209 -146 previously issued to you on November 23, 2009. 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 ODSK -13 PH and API number 50- 703 - 20607 -70 from records, data and logs acquired for well ODSK -13. 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, Daniel T. Seamount, Jr. h Chair DATED this ? - day of December, 2010 cc: Department of Fish 86 Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA RECEIV . A KA OIL AND GAS CONSERVATION COC SION NOV 1 9 2010 PERMIT TO DRILL F ,�,� �'rCTis- CCiOtY 20 AAC 25.005 *lash Oi. -x'� la. Type of Work: lb. Proposed Well Class: Development - Oil 0 Service - Winj ❑ Single Zone 0 lc. Spe ikteta roposed for: Drill 0 Redrill ❑ Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates 0 Re -entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas 2. Operator Name: 5. Bond: Blanket Ei Single Well ❑ 11. Well Name and Number: ,,//, Pioneer Natural Resources Alaska, Inc. Bond No. 103655283 ODSK -13 (r'(Ev1.Sh-0 3. Address: 700 G Street, Suite 600 6. Proposed Depth: , 12. Field /Pool(s): .. p,•t,4 Efole- Anchorage, AK 99501 MD: 16,172 • TVD: 6,303 4a. Location of Well (Govemmental Section): 7. Property Designation (Lease Number): Oooguruk - Kuparuk Oil Pool . Surface: 2960' FSL, 1152' FEL, Sec. 11, T13N, R7E, UM ADL 355036 / ADL, `` Top of Productive Horizon: 8. Land Use Permit: %•.1) v/ ;j9 ,t' 13. Approximate Spud Date: 4846' FSL, 5153' FEL, Sec. 1, T13N, R7E, UM 417497 December 5, 2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 3414' FSL, 3156' FEL, Sec. 35, T13N, R7E, UM 5760 2124' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 56.2 feet 15. Distance to Nearest Well Open Surface: x- 469845.81 y- 6031076.06 Zone- ASP 4 GL Elevation above MSL: 13.5 feet to Same Pool: ODSK -38 is 4582' away 16. Deviated wells: Kickoff depth: 3,512 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 89.52 degrees Downhole: 3443 a Surface: 2700 • 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 11 -3/4" 9 -5/8" 40# L -80 Hyd 521 5933 3362 2886 9295 5601 472 sx Class 'G' ✓ 8 -1/2" 7" 26# L -80 BTC -M 11059 Surface Surface 11102 6208 339 sx Class 'G' ✓ 6 -1/8" 4 -1/2" 12.6# L -80 Hyd 521 5220 10909 6195 16172 6303 Uncemented ✓ 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural 110' 16" Driven 158' 158' Surface 3475' 11 -3/4" 502 sx PF 'L'; 260 sx Class 'G' 3512' 2949' Intermediate) - DrIg Liner S+ eV SJ / /•3'o •/a Intermediate 2 Liner Perforation Depth MD (ft): N/A Perforation Depth TVD (ft): N/A 20. Attachments: Property Plat El BOP Sketch ❑ Drilling Program 10 Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 11/18/2010 22. I hereby certify that the foregoing is true and correct. Contact Alex Vaughan, 343 -2186 Prepared By: Kathy Campoamor, 343 - 2183 Printed Name Alex Vaughan �� - Title Operations Drilling Engineer S ignate -� ur - Phone 343 -2186 Date 11/18/2010 Commission Use Only Permit to Drill / < API Number: --, /te r / / Permit Ap pr�a l See cover letter for other Number: E a' ! 50- _ L ( '; ) , '_ . , ' 1 i ' ( (_ - Date: y ,Q 3/9 r requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, as hydrates, or gas contained in shales: Er Other: iel Sc 41 ( F Samples req'd: Yes ❑ No g Mud log req'd: Yes ❑ No [K n _ f_ ( �w, ) H measures: Yes ❑ Nod Directional svy req'd: Yes ©' No ❑ 1 7 APPROVED BY THE COMMISSION DAT . , COMMISSIONER 2 .4.1...- _1, 4% ft, /c � r Form 10 (Revised 7/2009) This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) ��� d6mit in Oupliate PIONEER NATURAL RESOURCES ALASKA Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, Alaska 99501 Tel: (907) 277 -2700 Fax: (907) 343 -2190 Thursday 18 2010 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Permit to Drill ODSK -13 Previous Permit # 209 -146 Surface Location: 2960' FSL, 1152' FEL, Sec 11, T13N, R7E, UM X = 469,845.81, Y = 6,031,076.06, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill a development well from the Oooguruk Drill Site (ODS) located within the Oooguruk Unit. The well is designed to be a production well in the Oooguruk - Kuparuk formation. A pilot hole will be drilled into the Nechelik and plugged back for reservoir evaluation purposes. PNRA requests the Permit to Drill based on approved Pool Rules. This well was originally approved as Kuparuk injector under PTD # 209 -146 As indicated in the attachments, the drilling and well construction program includes the following: _ • Pre -Set Surface Hole: ° / 7Z41-'7 o 11 -3/4" casing at 3,512' MD / 2,949' TVD. • Intermediate Hole 1: o Drill 10 -5/8" and under -ream while drilling (UWD) to 11 -3/4" to -9,295' MD / 5,601' TVD. Run and set a 9 -5/8" Drilling Liner. • Nechelik Pilot Hole & Plug Back o Drill 8 -1/2" hole to -- 11,315' MD / 6,756' TVD. Plug back. • Intermediate Hole 2: o Drill 8 -1/2" and under -ream while drilling (UWD) to 9 -1/2" to - 11,102' MD / 6,208' TVD and set a 7" Intermediate casing into the top of the Oooguruk - Kuparuk formation. • ODSK -13 Production Hole: o Drill 6 -1/8" horizontally to -16,172' MD / 6,303' TVD and set a 4 -1/2" solid liner with perforated pups. • Completion: o 3 -1/2" tubing ESP completion string with packer, SSSV & GLM. • • Alaska Oil & Gas Conservation Commission November 18` 2010 Page 2 of 3 PNRA will implement Managed Pressure Drilling technology (MPD) while drilling the Pilot hole, Intermediate 2 and Production hole sections of ODSK -13 as outlined below. • From TD of Intermediate 1 to Plug Back TD o Use -9.8 -10.5 ppg fluid while using MPD to control pressure from the surface to -12.5 ppg EMW at the bottom of the hole. • Open formations: • Kuparuk Sands, -9.8 ppg Pore Pressure ✓ • Nuiqsut Sands, -9.8 ppg Pore Pressure • From TD of Intermediate 1 to Intermediate 2 TD o Use -9.8 -10.5 ppg fluid while using MPD to control pressure from the surface to ✓ -12.5 ppg EMW at the bottom of the hole. • Open formations: • Kuparuk Sands, -9.8 ppg Pore Pressure / • From the Intermediate 2 Shoe to production TD o Use - 7.2 -8.2 ppg fluid while using MPD to control pressure from the surface to -9.8 -10.2 ppg EMW at the bottom of the hole during connections and while tripping Utilizing the MPD process described above allows PNRA to reduce the materials needed for the well, increasing the overall safety of the personnel on the development by handling less material. In addition the lower solids in the production section mud system will reduce formation damage along the sandface of the well. Based on information previously submitted to the AOGCC and included in the AOGCC Oooguruk Field File, PNRA requests an exemption from 20 AAC 25.035 (c) which requires a diverter system be installed on the well while drilling the surface interval. In the future, PNRA may provide information and permitting requesting annular disposal of drilling wastes on this well. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10 -401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) A copy of the proposed drilling program per 20 AAC 25.005 (c) (13) including: a. The drilling fluid program as required by 20 AAC 25.033 b. Complete logging and mud logging operations are planned and descriptions are attached. c. A complete proposed casing and cementing program is attached as per 20 AAC 25.030. d. A summary of the drilling operations. e. A summary of drilling hazards per 20 AAC 25.005 (c) (4). f. A wellbore schematic is also attached visually depicting the proposed well. • Alaska Oil & Gas Conservation Commission • November 18 2010 Page 3 of 3 3) A copy of the Planned Directional Well Path - including traveling cylinder and development layout plots. The following items are on file with the AOGCC: 1) A plat showing the surface location proposed for the well per 20 AAC 25.005 (c) (2). 2) Diagrams and descriptions of the BOP and diverter equipment to be used on Nabors Alaska Rig 19 -AC as required by 20 AAC 25.035 (b) and (c). 3) A description of the procedure for conducting formation integrity tests per 20 AAC 25.035 (c) (5). 4) PNRA does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment as specified in 20 AAC 25.065(1) will be functioning on the rig as standard operating procedure for all wells drilled by d that rig. Products for treating H2S contamination in the drilling mud system will be maintained on the ODS. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Vern Johnson, Drilling Superintendent (20 AAC 25.070) 907.343.2111 vern.johnson @pxd.com 2) Geologic Data and Logs Paul Daggett, Senior Staff Geophysicist (20 AAC 25.071) 907.343.2134 paul.daggett @pxd.com The anticipated spud date for this well is December 5 2010. If you have any questions or require further information, please contact Alex Vaughan at 907.343.2186. Sincerely, Alex Va - . n Operations Drilling Engineer Attachments: Form 10 -401 Supporting permit information cc: ODSK -13 Well File • Permit to Drill Well Plan Summary ODSK -13 Oooguruk – Kuparuk Multi - Lateral Production Well Pre -Set Surface Casing @ 3,512' MD / 2,949' TVD : r ' M5-5 /0. Intermediate 1 TD @ 9,295' MD / 5,601' TVD Pilot Hole TD @ 11,315' MD / 6,756' TVD Intermediate TD @ 11,102' MD / 6,208' TVD ODSK -13 Lateral TD @ 16,172' MD / 6,303' TVD Surface Location: 2960' FSL, 1152' FEL, Sec 11, T13N, R7E, UM - ASP 4 (NAD27) projection X = 469,845.81 1 Y = 6,031,076.06 1 Pilot Hole 4815' FSL, 5194' FEL, Sec. 1, T13N, R7E, Umiat X = 471098.2 1 Y = 6038205.00 1 6756' TVDrkb Target: Oooguruk - Nuiqsut 4846' FSL, 5153' FEL, Sec. 1, T13N, R7E, Umiat X = 471139.44 1 Y = 6038235.86 1 6208 TVDrkb Bottom Hole Location ODSK -13 3414' FSL, 3156' FEL, Sec.35, T13N, R7E, Umiat X = 467878.10 1 Y = 6042096.98 1 6303' TVDrkb AFE Number: TBA Est. Start Date: Dec 5 2010 1 Rig: Nabors 19AC Operating days: 36 days to Drill and Complete Objective & Well Type Kuparuk Development Well Well Design: Modified Slimhole (11 -3/4" x 9 -5/8" liner x 7" x 4 -1/2" liner) Single Lateral Current Mechanical Condition: Well Bay Footing / ODS Ground Level: Elevation above MSL: 13.5' RKB to Ground Level: 42.66' Rig Elevation: RKB + MSL = 56.16' Conductor: 158' MDrkb Pioneer Natural Resources Last Revised: November 18 2010 ODSK -13 Permit To Drill Page 1 of 12 • • Well Control: Well Section Pressure Depth Basis psi TVD 14 -1/2" Surface Section Maximum anticipated 1319 2949 Based on seawater gradient of 0.4472 psi /f BHP Maximum surface 994 Surface (Based on BHP and a full column of gas from TD pressure @ 0.11 psi /ft) 10 -5/8" x 11 -3/4" Intermediate 1 Hole Section Maximum anticipated 2505 5601 (Based on seawater gradient of 0.4472 psi /ft) BHP Maximum surface 1889 Surface Based on BHP and a full column of gas from TD pressure @ 0.11 psi /ft) 8 -1/2" Pilot Hole Maximum anticipated 3443 6756 Based on 9.8 ppg Oooguruk- Kuparuk pore 7 BHP pressure) Maximum surface 2700 Surface Based on BHP and a full column of gas from TD pressure @ 0.11 psi /ft) 8 -1/2" x 9 -1/2" Intermediate 2 Hole Section Maximum anticipated 3164 6208 Based on 9.8 ppg Oooguruk - Kuparuk pore BHP pressure) Maximum surface 2481 Surface Based on BHP and a full column of gas from TD pressure @ 0.11 psi /ft) 6 -1/8" ODSK -13 Production Liner Hole Section Maximum anticipated 3212 6203 Based on 9.8 ppg Oooguruk - Kuparuk pore BHP pressure) Maximum surface 2519 Surface Based on BHP and a full column of gas from TD pressure @ 0.11 psi /ft) Pioneer Natural Resources Last Revised: November 18 2010 ODSK -13 Permit To Drill Page 2 of 12 • • Maximum casing pressure: 4500 psi @ surface Planned BOP test pressure: 4500 psi (annular to 2500 psi) Due to required 4500 psi casing pressure test. Planned completion fluid: 10.2 ppg Brine /6.8 ppg Diesel Diverter (see attached schematic) - Note: Requesting Diverter Exemption on a Well by Well Basis): Hydril 21 -1/4" 2M annular BOP 1 16" full opening knife gate valve, hydraulically actuated 16" diverter line 5000 psi BOP stack (see attached schematic): Hydril GK 11" 5M annular BOP Hydril 11" 5M single ram BOP w/ studded connections Hydril 11" 5M single ram BOP w/ studded connections Drilling cross 11" 5M x 11" 5M with 2 ea. 3 -1/8" 5M side outlets w /flanged connections 2 ea. 3 -1/8" 5M full opening inner manual gate valves mounted on drilling cross 2 ea. 3 -1/8" 5M full opening outer remote hydraulic controlled gate valves mounted on inner gate valves. Hydril 11" 5M single ram BOP w/ studded connections Formation Integrity Testing Requirements: Test Point Depth Test Type Minimum EMW 11 -3/4" Surface Shoe Rathole + 20' to 50' from shoe LOT 12.5 ppg 9 -5/8" Drilling Liner Shoe Rathole + 20' from shoe FIT 13.5 ppg 7" Intermediate Shoe Rathole + 20' from shoe FIT 12.5 ppg Drilling Fluids Program: Intermediate 1 Hole Mud Properties: 10 -5/8" x 11 -3/4" hole LSND Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial to TD 9.8 ppg . 40 - 60 15 - 25 12 - 20 < 12 8 - 10 Pilot Hole & Intermediate 2 Hole Mud Properties: 8 -1/2" x 9 -1/2" hole LSND Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial to TD 9.8 - 10.5 ppg 50 - 70 15 - 25 15 - 25 < 10 3 - 5 ( -12.5 ppg via (8 -10 HTHP) ✓ MPD) Production Hole Mud Properties: 6 -1/8" hole MOBM Interval Density (ppg) Viscosity (secs) YP PV ES HTHP 0 / W Initial to TD 7.2 - 8.2 ppg 55 - 80 12 - 25 10 - 20 800 -2000 <6 94 / 6 (-9.8 ppg via MPD) Pioneer Natural Resources Last Revised: November l8 2010 ODSK -13 Permit To Drill Page 3 of 12 • • Formation Markers: Formation Tops MD (ft) TVDrkb (ft) Pore Press. EMW Comments (psi) (ppg) Brook 2B 6822 4386 1973 8.65 Top Torok Sand 8494 5172 Base Torok Sand 9047 5471 Torok Shale 1 5596 9 -5/8" casing point 9295 5601 Top HRZ 9839 5902 Base HRZ 10077 6028 Kalubik Mkr 10333 6160 Top Kup C 10423 6205 3162 9.8 Production Zone / Base Kup C (LCU) 10446 6217 BCU 10674 6340 Top Nuiqsut 10761 6391 3257 9.8 Base Nuiqsut 10906 6481 Top Nechelik 11014 6551 Base Nechelik 11313 6756 Pioneer Natural Resources Last Revised: November 18 2010 ODSK -13 Permit To Drill Page 4 of 12 • • Logging Program: 10 -5/8" x 11 -3/4" Section: Intermediate 1 Drilling: Dir / GR Open Hole: N/A Cased Hole: N/A 8 -1/2" Section: Pilot Hole Drilling: Mud Logging Dir / GR / Res /Az Den / Neut / PE / BAT Sonic Open Hole: N/A Cased Hole: 8 -1/2" Section: Intermediate 2 Drilling: Mud Logging Dir /GR /Res /PWD Open Hole: N/A Cased Hole: 6 -1/8" Section: Production Lateral Drilling: Mud logging ABI / Dir / GR / AzRes / AzDens / Neut / PE / PWD Open Hole: N/A Cased Hole: N/A Pioneer Natural Resources Last Revised: November 18 2010 ODSK -13 Permit To Drill Page 5 of 12 • • ODSK -13 Casing Program: Hole Casing / Weight Grade Conn. Casing Csg/Tbg Hole Btm Size Tubing Length Top MDrkb/TVDrkb MDrkb 24" 16" 109# H -40 Welded 115 Surface 158 158 14-1/2" 11 -3/4" 60# L -80 Hydril 521 3469 Surface 3512 2949 11 -3/4" 9 -5/8" 40# L -80 Hydril 521 5933 3362 9295 5601 8 -1/2" 7" 26# L -80 BTC -M 11059 Surface 11102 6208 6 -1/8" 4 -1/2" 12.6# L -80 Hydril 521 5220 10909 16172 6303 Tubing 3 -1/2" 9.3# L -80 IBT -M 10859 Surface 10902 6194 Casing Properties Size Weight Grade ID Drift Conn. Internal Collapse Tensile Strength ID Yield (psi) (psi) Joint Body 16" 109# H -40 14.67" 14.5" Welded Conductor casing 11 -3/4" 60# L -80 10.772" 10.62" Hydril 521 5830 3180 1384M 1384M 9 -5/8" 40# L -80 8.835' 8.75" Hydril 521 5750 3090 916 M 916 M 7" 26# L -80 6.276" 6.151 Hydril 511 7240 5410 604 M 604 M 7" 26# L -80 6.276" 6.151 BTC -M 7240 5410 604 M 604 M 4 -1/2" 12.6# L -80 3.958" 3.833" Hydril 521 na na 289 M 289 M Pioneer Natural Resources Last Revised: November 18 2010 ODSK -13 Permit To Drill Page 6 of 12 i Cement Calculations: Casing Size: 1 9 -5/8" Intermediate 1 - Drilling Liner - single stage Basis: TOC: 7994' MD - The greater of 500' MD of open hole or 500' above top of Torok 60% excess, plus 85' shoe track Total Cement Volume: Preflush 10 bbl water Spacer 60 bbl 10 ppg Dual Spacer Primary 98 bbls / 472 sx Premium "G" + adds. 1.17 cf /sk Displ 503 bbls mud Temp BHST - 135° F, BHCT -110° F Casing Size: 1 7" Intermediate 2 - single stage Basis: TOC: - 9900'MD - 500' MD above the top of the Kuparuk & 200' above 67° 40% excess, plus 85' shoe track Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 12.5 ppg Dual Spacer Primary 71 bbls / 339 sx Premium "G" + adds. 1.17 cf /sk Displ 422 bbls mud Temp BHST - 165° F, BHCT -135° F This well is outside the 1/2 mile radius around the disposal well at the intersection with the Torok disposal zone. Disposal: Annular Iniection: Currently not requested, but may be requested in the future. Cuttings Handling: All Class 2 solids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1 -44. Fluid Handling: All Class 1 and Class 2 fluids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1 -44. Pioneer Natural Resources Last Revised: November 18 2010 ODSK -13 Permit To Drill Page 7 of 12 • • Pioneer Natural Resources Well Plan Summary Drilling Operations Pre -Rig Work 1. 16" Conductors have been set and the Well Bay modules have been placed. 2. 11 -3/4" Surface casing has been set and cemented. Rig Activity: Drill and Complete 1. MIRU Nabors 19AC over pre - installed surface casing. 2. NU Drilling Spool and BOPE and test. Test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 3. MU 10 -5/8" x 11 -3/4" RSS, MWD /LWD (BHA will be a 10 -5/8" pilot hole opened to 11 -3/4" while drilling). 4. RIH and cleanout casing to landing collar. Displace well over to Intermediate 1 drilling fluid.' 5. Drill through surface shoe, rathole + 20' of new hole and perform LOT to a minimum of 12.5 ppg! • Note: The surface casing was pressure tested to 3500 psi for 30 minutes on 1/7/2010 6. Drill 10 -5/8" x 11 -3/4" Intermediate 1 to casing point. 7. Change one set of pipe rams to 9 -5/8" and test BOPE as required' 8. Run 9 -5/8" drilling liner on 5" DP. Set liner hanger, release from liner and cement 9. Bump the plug, increase pressure to 3500 psi and hold pressure for 5 minutes • This will provide a quick integrity test of the 9 -5/8" liner • Note the pressure test in the morning report 10. Release pressure and ensure floats are holding • This will check the integrity of the floats to ensure there isn't a flow path through the liner shoe 11. Set liner top packer and test the liner top to 3500 psi for 5 minutes • This will check the integrity of the liner top packer to ensure isolation between the liner and the surface casing • Note the pressure test of the liner top in the morning report 12. POOHw /5 "DP. 13. ND BOPE, ND Drilling spool, NU Mulitbowl Wellhead, & NU BOPE and test to 250/4500 psi - Notify AOGCC 48 hours in advance of test. • Ensure integrity of the liner and the liner top has been verified by a pressure test prior to performing this step 14. MU 8 -1/2" RSS, MWD /LWD on 5" DP. RU MPD trip nipple. ' 15. RIH and cleanout casing to landing collar. 16. Close pipe rams and combo pressure test the Drilling Liner and the Surface Casing to 3500 psi for 30 minutes -- chart and send to ODE. 17. Drill through drilling liner shoe + 20' of new hole and perform FIT to 13.5 ppg, 18. RD MPD trip nipple and RU bearing assembly. Drill 8 -1/2" Pilot Hole to TD. 19. Circulate and condition hole to pump abandonment plugs. RD the MPD bearing assembly and RU MPD trip nipple. POH. /20. RIH with cement stinger and set abandonment plugs across the Nechelik, Nuiqsut, Kuparuk, and below the intermediate 1 shoe as a kick -off plug as per AOGCC regulations. POH 21. MU 8 -1/2" x 9 -1/2" RSS, MWD /LWD on 5" DP. RU MPD trip nipple 22. RD MPD trip nipple and RU bearing assembly. Drill 8 -1/2" Intermediate 2 to casing point. Pioneer Natural Resources Last Revised: November 1 8th, 2010 ODSK -13 Permit To Drill Page 8 of 12 • • 23. Circulate and condition the well to run 7" intermediate casing. Displace the well over to -12.5 ppg mud for shale stability. RD the MPD bearing assembly and RU MPD trip nipple. POH. 24. Change one set of pipe rams to 7" and test BOPE as required. Note: Intermediate casing string may be run as a 7 ,> 7" long string or as a 7 liner with a 7" tieback string to surface depending on drilling conditions. Both options have been - provided below: Option #1: 7" Longstring 25. Run and cement the 7 "26# L -80 BTC -M intermediate casing. 26. Bump the plug and bring the pressure up to 3500 psi —hold for 5 minute pressure test. Release pressure and ensure floats are holding. 27. LD5 "DP Option #2: 7" Liner with Tie -Back Option 28. Run 7 ", 26# L -80 Hydril 511 intermediate liner on 5" DP. Set liner hanger, release from liner and cement. Bump the plug and bring the pressure up to 3500 psi —hold for 5 minute pressure test. • This will provide a quick integrity test of the 7" liner. • Note the pressure test in the morning report. 29. Release pressure and ensure floats are holding. • This will check the integrity of the floats to ensure there isn't a flow path through the liner shoe. 30. Set liner top packer and test the 9 -5/8" liner and 7" liner top packer to 3500 psi for 30 minutes. • This will check the integrity of the 7" liner top packer to ensure isolation between the 7" liner and the 9 -5/8 "drilling liner. • Note the pressure test of the liner top in the morning report 31. Run 7 ", 26# L -80 BTC intermediate tie -back to 7" liner- hanger seal bore and space out. 32. Displace diesel freeze protection down 7" annulus to 2,000' tvd with annular preventer closed. 33. Strip through annular preventer and sting into 7" liner- hanger seal bore and land tie -back casing. 34. Pressure test seal assembly to 3500 psi —hold & chart for 30 minutes. 35. Pressure test 7" tie back annulus 3500 psi —hold and chart for 30 minutes. 36. Set and test 7" pack -off. 37. RU MPD trip nipple & PU 4" DP as needed to TD the Production hole section. , 38. RIH to landing collar and w/ 4" DP & mill tooth cleanout bit. 39. Change pipe rams to 4" and test BOPE to 250/4500 psi — Notify AOGCC 48 hours in advance of test. 40. Pressure test casing to 3500 psi — chart and hold for 30 minute pressure test unless previously done in Option #2. Send chart to ODE. 41. Drill through Intermediate 2 shoe and POH w/ cleanout assembly. 42. MU 6 -1/8" RSS, MWD /LWD drilling assembly on 4" DP and RIH. -- 43. RD MPD trip nipple and RU bearing assembly. 44. Displace to drill -in -fluid for production lateral. 45. Drill rathole + 20' of new hole and perform FIT to 12.5 ppg. 46. Drill 6 -1/8" lateral production hole to TD. Pioneer Natural Resources Last Revised: November 18 2010 ODSK -13 Permit To Drill Page 9 of 12 • 47. Circulate and condition hole to run liner. 48. POH to intermediate shoe and set heavy weight balance brine pill. Cont POH to surface. 49. Change one set of pipe rams to 4 -1/2" and test BOPE as required. 50. RIH w/ 4 -1/2" solid production liner w/ perforated pups from 150' inside the intermediate shoe to TD. 51. Release from the liner and set the liner top packer. Displace the well over to 10.2 ppg Brine and POOH. 52. MU and RIH w/ 3 -1/2" production completion w/ ESP, packer, GLM, SSSV. 53. Space out, Land the tubing and RILDS. Install TWC. 54. ND BOPE, NU tree and test to 5,000 psi. 55. Pull TWC and reverse circulate corrosion inhibited brine and diesel to freeze protect the well to —2000' TVD and allow to u -tube. 56. Drop ball and rod and allow to seat. Pressure test the tubing to 3,500 psi — chart and hold for 30 minutes. Bleed off pressure and then pressure test the annulus to 3,500 psi — chart and hold for 30 minutes. Bleed off pressure. 57. RDMO to next well. Post-Rig Work 6 1. RU Slickline and pull the ball and rod. Pull the RHC -m plug. 2. RD Slickline. Pioneer Natural Resources Last Revised: November 18 2010 ODSK -13 Permit To Drill Page 10 of 12 • • Casing Shoe Leak Off Test Procedure: 1. After testing BOPE, pick up the drilling assembly and RIH to the float collar. Circulate to consistent mud weight and rheology. 2. Shut in with the pipe rams and test the casing to the required test pressure. Record the volume of mud required and the corresponding pressures in 1 /4 bbl increments. When the design pressure is reached shut in the well and record the shut in pressure for 30 minutes. 3. Bleed off pressure while taking returns to a calibrated tank and record volume recovered. 4. Drill out the shoe track. Drill 20 ft of new hole and circulate the hole clean with consistent mud weight in /out. Pull up into the casing shoe. 5. Perform a Leak Off Test (or Formation Integrity Test): • Calculate the required test pressure to reach leak off (or formation integrity test limit) with the actual mud weight and the estimated fracture EMW. • Plot the casing test data and the calculated leak off on appropriate scale coordinate paper. As a guide, use the data from the casing test to determine the approximate volume of mud required to reach the calculated LOT /FIT. • Shut the well in. R/U the test pump. • Bring the pump on line at 0.25 — 0.50 bpm. Maintain a constant rate. • Record the pressure for every 1 /4 of a bbl pumped. • Continue pumping until the pressure vs. volume curve breaks over indicating leak off. Note: For FIT, do not take to leak off • Discontinue pumping and shut in the well. Record the shut in pressure in 1 minute increments for 10 minutes or until pressure shows stabilization. • Bleed off the pressure and record the volume of mud recovered. • Plot the data to determine the LOT /FIT pressure at the shoe as EMW. • Submit the test results to the Pioneer drilling engineer for distribution as required. Pioneer Natural Resources Last Revised: November 18 2010 ODSK -13 Permit To Drill Page 11 of 12 • • ODSK -13 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • Prior to drilling into the Kuparuk, hold a pre - reservoir meeting to outline heightened awareness for kick detection and lost circulation. o Following the Kuparuk penetration, pick up off bottom, shut off the pumps and perform a flow check to verify there isn't any overpressure. Hydrates and Shallow gas • No hydrates are expected in this area. ✓ Lost Circulation /Breathing /Formation Stability /Stuck Pipe Events • Breathing may be seen while drilling the Hue shale. Minimizing swab and surge on the • formation is critical to reducing the impact of breathing in the wellbore. Breathing was seen in the ODSN -40 well, but only after substantial time in trying to solve the lost circulation problems in the fault seen in and below the Torok Sands. • Lost Circulation was seen in drilling the ODSN -36 across this same interval. Review the DOB2C pill procedure prior to penetrating the Kuparuk. Follow the Lost Circulation Decision Tree and combat losses accordingly • During the attempt to retrieve a fish from the ODSK -33 well, an un- centralized BHA got stuck from differential sticking across the Torok due to the increase in mud weight needed to hold back the shales below. Differential sticking indications were not noted with the drilling BHA and drill pipe. • There is a small section of formation above the Top of the HRZ that is volcanic in nature . (TUFFS) and can either have "glassy" material, swelling clays or both while drilling, which produced a pack off on ODSK -33 and ODSN -45. Kick Tolerance /Integrity Testing Kick Tolerance / Integrity Testing Summary Table Casing set / Maximum Mud Weight Exp Pore Min LOT / FIT Interval Influx Volume Press 11 -3/4" Surface / 762 bbls 9.8 ppg 2505 12.5 ppg (LOT) 10 -5/8" x 11 -3/4" 9 -5/8" Drilling Liner / Infinite 9.8 -10.5 ppg 3164 13.5 ppg (FIT), • 8 -1/2" x 9 -1/2" (12.5 EMW w /MPD) ODSK -13 7.2-8.2 ppg 7" Intermediate / Infinite (g 8_10.2 EMW w /MPD) 3212 12.5 ppg (FIT) 6 -1/8" NOTE: All LOT / FIT will be taken with a minimum of 20 -ft and a maximum of 50 -ft of new hole drilled outside of the previous casing string Hydrogen Sulfide • The Oooguruk Drill Site is not designated as an H site, however Standard Operating Procedures for H precautions should be followed at all times. Faults • Seismic faults with expected throws of 20 -35' may be encountered around 11,700' - 13,300' MD. Losses may be associated with these faults. • Consult the ODS data sheet for additional information (still in development) Pioneer Natural Resources Last Revised: November 18 2010 ODSK -13 Permit To Drill Page 12 of 12 STATE OF ALASKA ALOIA OIL AND GAS CONSERVATION COM ION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work: 1b. Proposed Well Class: Development - Oil CI Service - Winj ❑ Single Zone 151 lc. Specify if well is proposed for: Drill ei Redrill ❑ 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: Blanket El Single Well ❑ 11. Well Name and Number: Pioneer Natural Resources Alaska, Inc. Bond No. 103655283 ODSK - 3. Address: 700 G Street, Suite 600 6. Proposed Depth: 12. Field /Pool(s): Anchorage, AK 99501 MD: 16,172 TVD: 6,303 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Oooguruk - Kuparuk Oil Pool Surface: 2960' FSL, 1152' FEL, Sec. 11, T13N, R7E, UM ADL 355036 / ADL 355038 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4846' FSL, 5153' FEL, Sec. 1, T13N, R7E, UM 417497 December 5, 2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 3414' FSL, 3156' FEL, Sec. 35, T13N, R7E, UM 5760 2124' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 56.2 feet 15. Distance to Nearest Well Open Surface: x - 469845.81 y - 6031076.06 Zone- ASP 4 GL Elevation above MSL: 13.5 feet to Same Pool: ODSK -38 is 4582' away 16. Deviated wells: Kickoff depth: 3,512 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 89.52 degrees Downhole: 3443 Surface: 2700 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 1 11 -3/4" 9 -5/8" 40# L -80 Hyd 521 5933 3362 2886 9295 5601 472 sx Class 'G' 8 -1/2" 7" 26# L -80 BTC -M 11059 Surface Surface 11102 6208 339 sx Class 'G' 6 -1/8" 4 -1/2" 12.6# L -80 Hyd 521 5220 10909 6195 16172 6303 Uncemented 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural 110' 16" Driven 158' 158' Surface 3475' 11 -3/4" 502 sx PF 'L'; 260 sx Class 'G' 3512' 2949' Intermediate) - Drip Liner Intermediate 2 Liner Perforation Depth MD (ft): N/A Perforation Depth TVD (ft): N/A 20. Attachments: Property Plat Ei BOP Sketch ❑ Drilling Program el Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 11/18/2010 22. I hereby certify that the foregoing is true and correct. Contact Alex Vaughan, 343 -2186 Prepared By: Kathy Campoamor, 343 - 2183 Printed Name Alex Vaughan Title Operations Drilling Engineer Signature Phone 343 -2186 Date 11/18/2010 . Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: 50- Date: 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: ❑ Other: Samples req'd: Yes ❑ No❑ Mud log req'd: Yes ❑ No ❑ H measures: Yes ❑ No Directional svy req'd: Yes ❑ No ❑ APPROVED BY THE COMMISSION DATE: , COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid for 24 months from the date of approval (20 AAC 25.005(9)) Submit in Duplicate STATE OF ALASKA ALIOA OIL AND GAS CONSERVATION COMMINION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work: 1 b. Proposed Well Class: Development - Oil 0 Service - Winj ❑ Single Zone 0 lc. Specify if well is proposed for: Drill 0 Redrill ❑ Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ ❑ Re -entry El Exploratory El Service - WAG ❑ Service - Disp El Shale Gas 2. Operator Name: 5. Bond: Blanket is Single Well ❑ 11. Well Name and Number: Pioneer Natural Resources Alaska, Inc. Bond No. 103655283 ODSK - 3. Address: 700 G Street, Suite 600 6. Proposed Depth: 12. Field /Pool(s): Anchorage, AK 99501 MD: 16,172 TVD: 6,303 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Oooguruk - Kuparuk Oil Pool ' Surface: 2960' FSL, 1152' FEL, Sec. 11, T13N, R7E, UM ADL 355036 / ADL 355038 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4846' FSL, 5153' FEL, Sec. 1, T13N, R7E, UM 417497 December 5, 2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 3414' FSL, 3156' FEL, Sec. 35, T13N, R7E, UM 5760 2124' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 56.2 feet 15. Distance to Nearest Well Open Surface: x- 469845.81 y- 6031076.06 Zone- ASP 4 GL Elevation above MSL: 13.5 feet to Same Pool: ODSK -38 is 4582' away 16. Deviated wells: Kickoff depth: 3,512 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 89.52 degrees Downhole: 3443 Surface: 2700 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 11 - 3/4" 9 -5/8" 40# L -80 Hyd 521 5933 3362 2886 9295 5601 472 sx Class 'G' 8 -1/2" 7" 26# L -80 BTC -M 11059 Surface Surface 11102 6208 339 sx Class 'G' 6 -1/8" 4 -1/2" 12.6# L -80 Hyd 521 5220 10909 6195 16172 6303 Uncemented 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural 110' 16" Driven 158' 158' Surface 3475' 11 -3/4" 502 sx PF 'L'; 260 sx Class 'G' 3512' 2949' Intermediate) - Drlg Liner Intermediate 2 Liner Perforation Depth MD (ft): N/A Perforation Depth TVD (ft): N/A 20. Attachments: Property Plat 0 BOP Sketch ❑ Drilling Program Ei Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program IO 20 AAC 25.050 requirements ❑ 21. Verbal Approval: Commission Representative: Date 11/18/2010 22. I hereby certify that the foregoing is true and correct. Contact Alex Vaughan, 343 - 2186 Prepared By: Kathy Campoamor, 343 -2183 Printed Name Alex Vaughan Title Operations Drilling Engineer Signature Phone 343 2186 Date 11/18/2010 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: 50- Date: 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: ❑ Other: Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No ❑ H measures: Yes ❑ No Directional svy req'd: Yes ❑ No ❑ APPROVED BY THE COMMISSION DATE: , COMMISSIONER Form 10 - 401 (Revised 7/2009) This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Submit in Duplicate ODSK -13 As -Built Well Head: 11 -3/4 ", 5K, VetcoGray Tree: 2 -7/8 ", 5K, Horizontal 16" Conductor 153' MDrkb / 153' TVDrkb 3 -1/2 ", 9.3# L -80 TCII �► 11 -3/4 ", 60# L -80 BTC, 10.772" ID 3512' MDrkb / 2949' TVDrkb P10 R Date: Revision By: Comments N E E 12/15/2009 James Franks Proposed Completion 12/28/2009 Vern Johnson Revised with 11-%" surface csg NATURAL RESOURCES ^ /^ ODSK -13 NAT IRAL RESOURCES ALASKA 11/18/2010 Alex Vaughan As -Built Version 2.1 • • ODSK -13 Ivik Fault Block Kuparuk Production Well Well Head: 11 -3/4 ", 5K, VetcoGray Casing Tree: 3 -1/2 ", 5K, Horizontal Item # Item MD (ft) ND (ft) A 16" Conductor 158 158 B 11 -3/4" 60# L -80 Hydril 521, 10.772" ID 3512 2949 C 9 -5/8" 40# L -80 Hydril 521, 8.835" ID * 9295 5601 D 7" 26# L-80 BTC-M, 6.276" ID ** 11102 6208 E 4 -1/2" 12.6# IBT -M Slotted 3.958" ID w/ torque rings 16172 6303 F 3 -1/2" 9.3# L-80 IBT -M 10902 6471 A pilot hole will be drilled and plugged back to the 9 -5/8" casing prior to landing at the 7" TD 1 VetcoGray Tubing Hanger 34 34 O 2 2 -7/8" Wellstar Tubing Retreivable ScSSSV 2,000 1,924 3 GLM #1 - 2 -7/8" x 1 -1/2" (min. 3 jts above top X nipple) 2,500 2,350 \ 2 -7/8" X Nipple 2.313" ID. (min. 2 jts aboe Gas Vent 4 Vale Packer) 2,620 2,444 5 WFT 7" x 2 -7/8" Gas Vent Vale Packer 2,700 2,500 6 GLM #2 - 2 -7/8" x 1 -1/2" (min. 2 jts aboe X nipple) 9,820 5,875 2 -7/8" X Nipple, 2.313" ID (max. icl. 67 deg) w/ RHC-M 7 Plug Body 9,900 5,915 8 Automatic Divert VaIe (ADV) 10,000 5,960 =� © 9 ESP (Pump, Motor, and Jewelry) 10,010 5,965 End of Assembly 10,100 6,005 ' Upper Completion `1 MDrkb (ft) TVDrkb (ft) © 10 WFT 7" x 3 -1/2" Retrievable Packer 10,874 6,192 11 WFT3 -1/2" Sliding Sleeve 10,899 6,194 12 WFT 3 -1/2" Formation Saver Valve 10,924 6,196 3 WLEG 10,934 6,196 End of Assembly 10,936 6,196 • © • 13 WFT PBR Tie Back Sleeve 15ft 10936 6196 ' 14 WFT "NTH" Liner Top Pkr 10949 6197 O 15 WFT "PHR" Rotating Hyd Set Liner Hanger 10952 6197 CD 16 4 -1/2" 12.6# L-80 IBT -M Slotted Liner w/ torque rings 0 17 WFT Eccentric Solid Alum Shoe 16172 6303 t" -e TD 16174 6303 • v r ,,J,:::,:vi,•:,.., �� � , 1 . .• .4, 41 •• •• .. •• 11 11 •• , •• • •• 11 11 •• ••• 11 •• OE . +_ 11 11 •• 11 •• •• •S 11 4. to .„ 16,172' MDrkb / 6,303' NDrkb • >s.g �� � 11,315' MDrkb /6,756'NDrkb Date: Revision By: Comments PIONEER 12/15/2008 James Franks Proposed Completion NATURAL RESOURCES p ,^ 8/25/2010 Alex Vaughan Proposed Completion ODSK -13 Producer NATURAL RESOURCESAIAS(A 11/18/2010 Alex Vaughan Update to wp 6 # wp 14 Well Schematic Version 3.1 • • 3 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -13i - Slot ODS -13 ODSK -13i KupH Plan: ODSK -13 PK1 PH wp06 Standard Proposal Report 18 November, 2010 HALLIBURTON Sperry Drilling Services A ■ E '�■ ■!`f�A� WELL DETAILS: ODSK -13i REFERENCE INFORMATION 3 F'l i�im R.f Pf !.� A Co- ordinate (N/E) Reference: Well ODSK -13i - Slot ODS -13, True North Vertical (T Ground Level: 13.5 (TVD) Reference: 42.T + 13.5' @ 56.2ft (Nabors 19AC) i 9 a "` Sperry Cirii Bin +N / -S +E/ -W Northing Easting Latittude Longitude Slot Measured Depth Reference: 42.T + 13.5 @ 56.2ft (Nabors 19AC) , 0.0 0.0 6031076.06 469845.81 70° 29' 45.498 N 150° 14' 47.653 W ODS -13 Cakulaton Method: Minimum Curvature WELLBORE TARGET DETAILS (MAP CO - ORDINATES) COMPANY DETAILS: Well Planning - Pioneer - Oooguruk N ame ND +N / - S +E! - W Northing Easting Shape Project: Oooguruk Development Calculation Method: Minimum Curvature KupHi Curve 3000.0 1397.0 -506.7 6032474.92 469344.86 Point Site: Oooguruk Drill Site PK1 K1v2 v2 Curve e 2 2 5238.3 5119.9 1576.6 6036188.97 471443.04 Point Error System: ISCWSA Well: ODSK -131 PK1 v2 Curve 5269.2 5174.0 1563.0 6036243.16 471429.63 Point Er Methoe: Erapt CylConi North KupHi v7 Ti 5990.2 4575.0 - 3321.7 6035664.00 466543.00 Circle (Radius: 200.0) Erro o r Surface: Elliptical Conic Wellbore: ODSK -131 KupH PK1 v2 Heel 6151.2 6623.0 1565.5 6037692.00 471438.00 Point Warning Method: Rules Based Plan: ODSK -13 PK1 PH wp06 PK1 v3 Heel 6151.2 7566.3 1106.6 6038637.00 470983.00 Point PK1 v3 Lateral Toe 6151.2 10937.7 - 2075.4 6042021.00 467815.00 Point --- _ PK1 v3 mid 6151.2 8100.4 388.4 6039174.00 470267.00 Point 11 PH PK1 v6T1 6205.2 6556.1 1589.8 6037625.00 471462.00 Point CASING DETAILS • PK1 Heel 6206.2 6728.2 877.0 6037800.00 470750.00 Point PH PK1 v3 T1 6210.2 6706.9 1507.1 6037776.10 471379.90 Point TVD MD Name Size 0- I? PH PK1 v5T1 6210.2 6640.9 1545.4 6037710.00 471418.00 Point 29483512.0 11 3/4" 11.750 -_ ODSN -13 Nuiq Take Pgj0136.2 7213.3 386.0 6038287.00 470261.00 Point 56019294.6 9 5/8" 9.625 PH PK1 v3 T2 6395.2 6911.0 1364.1 6037980.80 471237.80 Point PH PK1 v5T2 6395.2 6911.0 1364.1 6037980.80 471237.80 Point 600 • - 5? SECTION DETAILS - 10? 1200 Sec MD Inc Azi TVD +N / -S +E/ -W DLeg TFace VSec Target 1 3512.0 63.59 2.08 2948.8 1293.4 -485.4 0.00 0.00 1192.7 2 3572.0 63.59 2.08 2975.5 1347.1 -483.4 0.00 0.00 1246.0 2 5? 3 4718.8 64.90 40.39 3489.3 2284.1 -117.3 3.00 96.49 2231.4 1800 4 7253.5 64.90 40.39 4564.4 4032.4 1370.2 0.00 0.00 4206.0 5 10432.3 60.00 327.67 6205.2 6556.1 1589.8 2.00 - 112.57 6730.5 PH PK1 v6T1 6 11314.7 42.35 327.67 6756.2 7134.7 1223.6 2.00 180.00 7238.8 30 Kop: 3512' MD, 2948.8' TVD E 2400- y n• Z o - Hue 2 Tuff o , o - Start Dir 3 °/100': 3572' MD, 2975.5'TVD: 96.51° RT TF 3000- - - - - ' Brook 26 co End Dir: 4718' MD, 3489.1' ND _ 11 _ 0 3600- / / c � i - Top Torok Ss � 4 1 DDI = 6.45 r > 4200- ,' Base Torok Ss Start Dir 2 °/100': 7254.6' MD, 4565.79 CD - ' - 2 - i - -- H - 4800- ,' Torok Shale 1 Top HRZ i 5400 -,' , - Base HRZ ° PH PK1 v6T1 Kaluhik Mkr 9 5/8 "_ - - 6000- - __ - - - - KupC -g5n. Base Kup C (LCU) 6600 --.'�;,;- BCU ^ . �� Nuigsut B Nuigsut 7200- Nechelik ODSK -13i /ODSK -13 PK1 PH wp06 B Necholik 7800- - SURVEY PROGRAM 11 r I I I I I I I I I I I I I j I I I I I I I I I I I I I I I I I I I I I I I i j I I I I I I I 1 1 I i I I I I I FT I J I I I I HI Date: 2010-08-26700:00:00 Validated: Yes Version: - 300 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 Depth From Depth To Survey /Plan Tool 100.0 532.0 ODSK -13 Gyro (ODSK -13i KupH) SR- Gyro -SS Vertical Section at 9.73° (1500 ft/in) 573.7 3512.0 ODSK -13 MWD (ODSK -13i KupH) MWD +IFR2 +MS +ssg 3512.0 11314.7 ODSK -13 PK1 PH wo06 (ODSK -13i Ku0l41WD +IFR2 +MS +ssg L g �. I. WELL DETAILS: ODSK -13i REFERENCE INFORMATION • : H1 LL- MURTON r ..._. Ground Level: 13.5 Co-ordinate (N /E) Reference: Well ODSK -13i - Slot ODS -13, True North r Sperry Aril €ine +N / -S +E / -W Northing Easting Latittude Longitude Slot vertical (TVD) Reference: 42.7'+ 13.5' (4) 56.25 (Nabors 19AC) „, 0.0 0.0 6031076.06 469845.81 70° 29' 45.498 N 150° 14' 47.653 W ODS -13 Measured Depth Reference: 42.7'+ 13.5' @ 56.2ft (Nabors 19AC) Calculation Method: Minimum Curvature SECTION DETAILS Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target COMPANY DETAILS: Well Planning - Pioneer - Oooguruk 1 3512.0 63.59 2.08 2948.8 1293.4 -485.4 0.00 0.00 1192.7 Calculation Method: Minimum Curvature Project: Oooguruk Development 2 3572.0 63.59 2.08 2975.5 1347.1 -483.4 0.00 0.00 1246.0 Error System: ISCWSA Site: 000 uruk Drill Site 3 4718.8 64.90 40.39 3489.3 2284.1 -117.3 3.00 96.49 2231.4 Scan Method: Tray. Cylinder North g 4 7253.5 64.90 40.39 4564.4 4032.4 1370.2 0.00 0.00 4206.0 Error Surface: Elliptical Conic Well: ODSK -131 5 10432.3 60.00 327.67 6205.2 6556.1 1589.8 2.00 - 112.57 6730.5 PH PK1 v6T' Warning Method: Rules Based , 6 11314.7 42.35 327.67 6756.2 7134.7 1223.6 2.00 180.00 7238.8 Wellbore: ODSK 13i KupH Plan: ODSK -13 PK1 PH wp06 SURVEY PROGRAM CASING DETAILS Date: 2010 -08- 261 Validated: Yes Version: 7800 - TVD MD Name Size Depth From Depth To Survey /Plan Tool - 2948.8 3512.0 11 3/4" 11.750 ODSK - 13i /ODSK - 13 PK1 PH wp06 100.0 532.0 ODSK -13 Gyro SR- Gyro -SS - 5601.0 9294.6 9 5/8" 9.625 573.7 3512.0 ODSK -13 MWD MWD +IFR2 +MS +sag 3512.0 11314.7 ODSK -13 PK1 PH wp06 MWD +IFR2 +MS +saq 7200- - 6 = 65 p0 IPH PKI v6Tl1 WELLBORE TARGET DETAILS (MAP CO- ORDINATES) ame TVD +N / -S +E / -W Northing Easting Shape I - - 6600- _ :-... K pHiPB1 SCP 3000.0 1397.0 -506.7 6032474.92 469344.86 Point FK1 v2 Curve 2 5238.3 5119.9 1576.6 6036188.97 471443.04 Point I 471429 63 Point � F K1 v2 Curve 5269.2 5174.0 1563.0 6036243.16 hupHiv7 T1 5990.2 4575.0 - 3321.7 6035664.00 466543.00 Circle (Radius: 200.0) F K1 v2 Heel 6151.2 6623.0 1565.5 6037692.00 471438.00 Point 6000- F K1 v3 Heel 6151.2 7566.3 1106.6 6038637.00 470983.00 Point P :1 v3 Lateral Toe 6151.2 10937.7 - 2075.4 6042021.00 467815.00 Point P1(1 v3 mid 6151.2 8100.4 388.4 6039174.00 470267.00 Point 9 5 /8" P 5500 F PK1 v6T1 6205.2 6556.1 1589.8 6037625.00 471462.00 Point 5400- PK1 Heel 6206.2 6728.2 877.0 6037800.00 470750.00 Point - P-I PK1 v3 T1 6210.2 6706.9 1507.1 6037776.10 471379.90 Point DDI = 6.45 F-I PK1 v5T1 6210.2 6640.9 1545.4 6037710.00 471418.00 Point = ODSN -13 Nuiq Take Point 1 6386.2 7213.3 386.0 6038287.00 470261.00 Point 4800 - P I P1(1 v3 T2 6395.2 6911.0 1364.1 6037980.80 471237.80 Point w S000 P-I PK1 v5T2 6395.2 6911.0 1364.1 6037980.80 471237.80 Point 0 rn - 4200 - + - C y s � Start Dir 2 "/100': 7254.6' MD, 4565.77VD O - 3600- - cn • 3000 ' • End Dir: 4718' MD, 3489.1' TVD 2400- - ,?s et) 11 3/4" 1800 - v ,3808 Start Dir 3° /100': 3572' MD, 2975.5'TVD: 96.51° RT TF 1200 - - - - Kop MD, 2948.8' TVD 600- 2500 ` 0- - I I I I I I I I I I I I I I I I I 1 I I I I I 1 1 1 I I 1 I I I i I i I I I I I I 1 I 1 I I I I I I I I . i I I 1 1 1 1 I 1: 1 1 1 I i i i I I I I I I 1 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 I I I I I I I I I I I I I I I -4800 -4200 -3600 -3000 -2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 West( - )/East( +) (1500 ft/in) 0 ill Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co - ordinate Reference: Well ODSK -13i - Slot ODS -13 Company: ` Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True . Well: ODSK -13i Survey Calculation Method: Minimum Curvature • Wetibore: ODSK -13i KupH Design: ODSK -13 PK1 PH wp06 Project Oooguruk Development 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 Oooguruk Drill Site Site Position: Northing: 6,031,151.32ft Latitude: 70° 29' 46.242 N From: Map Easting: 469,920.45ft Longitude: 150° 14' 45.465 W Position Uncertainty: 0.0 ft Slot Radius: in Grid Convergence: -0.23 ? Well ODSK -13i - Slot ODS -13 Well Position +N/-S 0.0 ft Northing: 6,031,076.06 ft • Latitude: 70° 29' 45.498 N +E / -W 0.0 ft Easting: 469,845.81 ft Longitude: 150° 14' 47.653 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft Weilbore ODSK -13i KupH Magnetics • Model Name Sample Date Declination Dip Angle Field Strength t ?) ( ?) (nT) IGRF200510 12/29/2009 21.99 80.81 57,759 Design ODSK -13 PK1 PH wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 3,512.0 Vertical Section: Depth From (ND) +N /S +EI.W Direction (ft) (ft) (ft) ( ?) 42.7 0.0 0.0 9.73 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +NIS +E/ -W Rate Rate Rate Tool Face (ft) (7) ( ?) (ft) ft (ft) (ft) ( ?/1 OOft) MOON) ( ? /100ft) ( ?) 3,512.0 63.59 2.08 2,948.8 2,892.6 1,293.4 -485.4 0.00 0.00 0.00 0.00 3,572.0 63.59 2.08 2,975.5 2,9 1,347.1 ' -483.4 0.00 0.00 0.00 0.00 4,718.8 64.90 40.39 3,489.3 3,433.1 2,284.1 -117.3 3.00 0.11 3.34 96.49 7,253.5 64.90 40.39 4,564.4 4,508.2 4,032.4 1,370.2 0.00 0.00 0.00 0.00 10,432.3 60.00 327.67 6,205.2 6,149.0 6,556.1 1,589.8 2.00 -0.15 -2.29 - 112.57 11,314.7 42.35 327.67 6,756.2 6,700.0 7,134.7 1,223.6 2.00 -2.00 0.00 180.00 11/18/2010 7 :23 :52AM Page 2 COMPASS 2003.16 Build 428 i s • Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -13i - Slot ODS -13 KUP C lateral PK1 Plan: ODSK -13 PK1 wp14 S,+ Standard Proposal Report 17 November, 2010 HALLIBURTON Sperry Drilling Services 1(R ' a a. 1 r P a , • HALUEURTON WELL DETAILS: ODSK -I3i REFERENCE INFORMATION ; ^' di (N /E) Reference: Well OD K 3I Slot ODS-13, True N tam;. ,.-.._ '• _ -• il .: Ground Level: 13.5 Co-ordinate erence: : e I S -1 - of - rue ort h ............... " "" """ "Orii inig "' ............. Vertical (TVD) Reference: 42.7' + 13 5' @ 56.25 (Nabors 19AC) , frY+rry CyritItr +N / -S +E / -W Northing Easting Latittude Longitude Slot 0.0 0.0 6031076.06 469845.81 70° 29' 45.498 N 150° 14' 47.653 W ODS -13 Measured Depth Reference: 42.7' + 13.5 @ 56.20 (Nabors 19AC) Calculation Method: Minimum Curvature SECTION DETAILS Sec MD Inc Azi TVD ON/ +E / - DLeg TFace VSec Target COMPANY DETAILS: Well Planning - Pioneer - Oooguruk 1 9294.6 56.76 354.19 5601.0 5654.6 1905.5 0.00 0.00 5220.0 Calculation Method: Minimum Curvature Project: Oooguruk Development 2 9354.6 54.80 355.88 5634.7 5704.1 1901.2 4.00 145.00 5269.4 Error System: ISCWSA Site: Oooguruk Drill Site 3 9709.7 61.16 345.78 5823.3 6000.4 1852.4 3.00 -56.19 5569.7 Scan Method: Tray. Cylinder North g 4 9916.1 61.16 345.78 5922.8 6175.7 1808.0 0.00 0.00 5750.0 Error Surface: Elliptical Conic Well: ODSK -131 5 10861.1 86.00 322.77 6191.2 6974.4 1410.1 3.50 -45.60 6607.3 PK1 v11 T1 Warning Method: Rules Based Wellbore: KUP C lateral PK1 6 11305.5 86.00 322.77 6222.2 7327.4 1141.8 0.00 0.00 7002.8 7 11405.5 89.00 322.77 6226.6 7406.9 1081.4 3.00 0.00 7091.9 Plan: ODSK -13 PK1 wp14 8 11618.9 89.52 316.39 6229.3 7569.3 943.1 3.00 -85.43 7276.5 9 12367.7 89.52 316.39 6235.7 8111.4 426.6 0.00 0.00 7902.6 SURVEY PROGRAM 10 12662.7 89.11 325.23 6239.2 8339.8 240.4 3.00 92.67 8160.8 PK1 v14 T2 CASING DETAILS 11 12674.7 89.12 325.59 6239.4 8349.7 233.6 3.00 88.99 8171.7 Date: 2010- 11- 17T00:00:00 Validated: Yes Version: 12 13657.2 89.12 325.59 6254.5 9160.2 -321.6 0.00 0.00 9068.8 TVD MD Name Size 13 13823.7 89.03 320.59 6257.2 9293.2 -421.6 3.00 -91.02 9217.6 PK1 v14 T3 Depth From Depth To Survey /Plan Tool 2948.8 3512.0 11 3/4" 11.750 14 13851.0 89.07 321.41 6257.7 9314.5 -438.7 3.00 87.29 9241.6 100.0 532.0 ODSK -13 Gyro SR- Gyro -SS 12600- _ 5601.0 9294.6 9 5/8" 9.625 15 14755.7 89.07 321.41 6272.3 10021.5 - 1002.9 0.00 0.00 10038.6 573.7 3512.0 ODSK -13 MWD MWD +IFR2 +MS +sag 6208.0 11101.9 7" 7.000 16 15008.8 88.72 313.83 6277.2 10208.3 - 1173.3 3.00 -92.72 10252.9 PK1 v14 T4 3512.0 9294.6 ODSK -13 PK1 PH wp06 MWD +IFR2 +MS +sag - 6303.2 16172.5 4 1/2" 4,500 17 16172.5 88.72 313.83 6303.2 11014.0 - 2012.7 0.00 0.00 11196.4 PK1 v14 T5 9294.6 16172.5 ODSK -13 PK1 wp14 MWD +IFR2 +MS +sag 12000- - WELLBORE TARGET DETAILS (MAP CO- ORDINATES) - Total Depth: 16172.5' MD, 6303.2' TVD ODSK I3i /f - 13 PKI wp14 N TVD ON/-S +E / -W Northing Easting Shape 11400 - ., - 6623.0 i CAC C _ PK1 v2 Heel 6151.2 . 5 6037692.00 471438.00 Point I In P ,.7-- End Dir: 15008.8' MD, 6277.2' TVD F K1 v2 Lateral Toe 6151.2 10706.7 - 1834.4 6041789.00 468055.00 Point K1 v3 Heel 6151.2 7566'3 1106.6 6038637.00 470983.00 Point - 4 1/2" I+ F K1 v3 Lateral Toe 6151.2 10937'7 - 2075.4 6042021.00 467815.00 Point 10800- /1 • *K• v3 mid 6151.2 8100.4 388.4 6039174.00 470267.00 Point / Start Dir 37100': 14755.7' MD, 6272.3TVD PK1 v11 T1 6191.2 6974.4 1410.1 6038044.00 471284.00 Point // PK1 v14 T1 6205.0 7053.8 1349.7 6038123.62 471223.97 Point PKI v14 T - 1 PK1 Heel 6206.2 6728'2 877.0 6037800.00 470750.00 Point - 10200- ( _ , t , I- End Dir. 13851 MD, 6257.7 TVD PK1 v9 T1 6214.2 7100.6 1457.5 6038170.00 471332.00 Point /' I PK1 v6 T1 6226.2 7567.3 1106.6 6038638.00 470983.00 Point - PK1 v6 T2 6237.2 8410.1 310.9 6039484.00 470190.75 Point 9600- I ' P1(1 v14 T2 6239.2 8339.8 240.4 6039414.00 470120.00 Point w 9600- PKI v14 T " Start Dir 3" /100': 13657.2' MD 6254 PK1 v6 T3 6254.2 9253.0 -484.9 6040330.00 469398.50 Point o I - I - - - PK1 v14 T3 6257.2 9293.2 -421.6 6040370.00 469462.00 Point o _ � . - , - - PK1 v14 T4 6277.2 10208.3 - 1173.3 6041288.00 468714.00 Point - / I End Dir: 12674.7' MD, 6239.4' TVD PK1 v6 T4 6277.2 10095.8 - 1280.7 6041176.00 468606.25 Point 9000 - PK1 v14T5 6303.2 11014.0 - 2012.7 6042097.00 467878.00 Point + __ PK1 v6 T5 6304.2 10938.7 - 2076.4 6042022.00 467814.00 Point - - IPKIvI4T3I 7 - I ' Start Dir 3" /100': 12367.7' MD, 6235.7'TVD 8400 ! i_ , _ /1'. -- End Di r: 11618.9' MD, 6229.3' TVD DDI = 6.65 s_ • V 1 7800- 1 PKI v14 T21 / _ _ Start Dir 3" /100': 1 1305.5' MD, 6222.2TVD v / 7200 - 1 ODSK - 13i /ODSK - 13 PKI PH wp06 ' v I - End Dir: 10861.1' MD, 6191.2' TVD _ I - 6600 Start Dir 3.5" /100': 9916.1' MD, 5922.8TVD - IPK1 v14 T11 // 6000 PKI v11 T11 _ _ _ _ _ End Dir: 9709.7' MD, 5823.3' TVD - _ - Start Dir 3" /100': 9354.6' MD, 5634.7TVD - _ "5500 - - - 5400 KOP: 4 ° /l00' 145 °RHTF 9294.6' MD, 5601' TVD 4800 - 1 HiiiiiII IHIII HIIIIIIIIIIIIIIIIIIHIIII ,IIIjIII,IIIII IIIH: III:IIHIIIIIIIIIIIIIIII:IIIIIIIiIiiir m iliiiIIIIIIII:F -4800 -4200 -3600 -3000 -2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 West( - )/East( +) (1500 ft/in) ,° , REFERENCE INFORMATION HA LLIB R T +O 13i N WELL DETAILS: ODSK - Co-ordinate (N/E) Reference: Well ODSK -13i - Slot ODS -13, True North ..' .... Ground Level: 13.5 Vertical (TVD) Reference: 42.7' + 13 5' Cat 56.2ft (Nabors 19AC) ""qS 2 31yt�, 7 , _ S• perry Drill €ng +N / -S +E/ -W Northing Easting Latittude Longitude Slot Measured Depth Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) ,, "" am ... 0.0 0.0 6031076.06 469845.81 70° 29' 45.498 N 150° 14' 47.653 W ODS -I3 Calculation Method: Minimum Curvature WELLBORE TARGET DETAILS (MAP CO - ORDINATES) COMPANY DETAILS: Well Planning - Pioneer - Oooguruk Project: Oooguruk Development Name TVD +N / -S +E / -W Northing Easting Shape Oooguruk PK1 v2 Heel PK1 v2 Lateral Toe 6151.2 10706.7 - 1834.4 6623.0 1565.5 6037692.00 471438.00 Point Calculation Method: Minimum Curvature 6151.2 Site: Ooo k Drill Site 6041789.00 468055.00 Point Scan Me Error 1SCWSA g Weil: ODSK -13i PK1 v3 Heel 6151.2 7566.3 1106.6 6038637.00 470983.00 Point Scan Method: Ellie Cylinder North PK1 v3 Lateral Toe 10937.7 - 2075.4 6042021.00 467815.00 Point Error Surface: Elliptical Conic Wellbore: KUP C lateral PK1 PK1 v3 mid 6151.2 8100.4 388.4 6039174.00 470267.00 Point Warning Method: Rules Based Plan: ODSK -13 PK1 wp14 PK1 v11 T1 6191.2 6974.4 1410.1 6038044.00 471284.00 Point PK1 v14 T1 6205.0 7053.8 1349.7 6038123.62 471223 97 Point PK1 Heel 6206.2 6728.2 877.0 6037800.00 470750.00 Point PK1 Toe 6206.2 9567.0 - 1962.8 6040650.00 467922.00 Point CASING DETAILS PK1 v9 T1 6214.2 7100.6 1457.5 6038170.00 471332.00 Point PK1 v6 T1 6226.2 7567.3 1106.6 6038638.00 470983.00 Point ND MD Name Size _ PK1 v6 T2 6237.2 8410.1 310.9 6039484.00 470190.75 Point 2948.8 3512.0 11 3/4" 11.750 PK1 v14 T2 6239.2 8339.8 240.4 6039414.00 470120.00 Point 5601.0 9294.6 9 5/8" 9.625 PK1 v6 T3 6254,2 9253.0 -484.9 6040330.00 469398.50 Point 6208.0 11101.9 7" 7.000 1760 PK1 v14T3 6257.2 9293.2 -421.6 6040370.00 469462.00 Point 6303.2 16172.5 41/2" 4.500 - PK1 v14 T4 6277.2 10208.3 - 1173.3 6041288.00 468714.00 Point DDI = 6.45 PK1 6277.2 10095.8 - 1280.7 6041176.00 468606.25 Point • PK1 v14 T5 6303.2 11014.0 - 2012.7 6042097.00 467878.00 Point 2200 PK1 v6 T5 6304.2 10938.7 - 2076.4 6042022.00 467814.00 Point - SECTION DETAILS SURVEY PROGRAM Sec MD Inc Azi ND +N / -S +E/ -W DLeg TFace VSec Target 2640- Date: 2010 -11- 17700:00:00 Validated: Yes Version: 1 9294 56.76 354.19 5601.0 5654.6 1905.5 0.00 0.00 5220.0 - 2 9354.6 54.80 355.88 5634.7 5704.1 1901.2 4.00 145.00 5269.4 - Depth From Depth To Survey /Plan Tool 3 9709.7 61.16 345.78 _ Gyro ODSK -13i KupH) SR-Gyro-SS 5823.3 6000.4 1852.4 3.00 -56.19 5569.7 100.0 532.0 ODSK -13 G Y ( P ) y 4 9916.1 61.16 345.78 5922.8 6175.7 1808.0 0.00 0.00 5750.0 3080 573.7 3512.0 ODSK -13 MWD (ODSK -13i KupH) MWD +IFR2 +MS +sa3 5 10861.1 86.00 322.77 6191,2 6974.4 1410.1 3.50 -45.60 6607.3 PK1 v11 T1 - 3512.0 9294.6 ODSK -13 PK1 PH wp06 (ODSK -13i KupH) MWD +IFR2 +MS +sa3 6 11305.5 86.00 322.77 6222.2 7327.4 1141.8 0.00 0.00 7002.8 - 9294.6 16172.5 ODSK -13 PK1 wp14 (KUP C lateral PK1) NIWD +IFR2 +MS +sue 7 11405.5 89.00 322.77 6226.6 7406.9 1081.4 3.00 0.00 7091.9 8 11618.9 89.52 316.39 6229.3 7569.3 943.1 3.00 -85.43 7276.5 3520 9 12367.7 89.52 316.39 6235.7 8111.4 426.6 0.00 0.00 7902.6 c - 10 12662.7 89.11 325.23 6239.2 8339.8 240.4 3.00 92.67 8160.8 PK1 v14 T2 Z _ 11 12674.7 89.12 325.59 6239.4 8349.7 233.6 3.00 88.99 8171.7 0 KOP: 4 °/100' 145 °RHTF 9294.6' MD, 5601' TVD 12 13657.2 89.12 325.59 6254.5 9160.2 -321.6 0.00 0.00 9068.8 13 13823.7 89.03 320.59 6257.2 9293.2 -421.6 3.00 -91.02 9217.6 PK1 v14 T3 3960 I 14 13851.0 89.07 321.41 6257.7 9314.5 -438.7 3.00 87.29 9241.6 Start Dir 3 °/100': 9354.6' MD, 5634.7'TVD 15 14755.7 89.07 321.41 6272.3 10021.5 - 1002.9 0.00 0.00 10038.6 L End Dir: 11618.9' MD, 6229.3' TVC 16 15008.8 88.72 313.83 6277.2 10208.3 - 1173.3 3.00 -92.72 10252.9 P1<1 v14 T4 Q i 17 16172.5 88.72 313.83 6303.2 11014.0 - 2012.7 0.00 0.00 11196.4 PK1 v14 T5 4400 End Dir: 9709.7' MD, 5823.3' TVD ' o I ,' Start Dir 3 °/100': 12367.7' MD, 6235.7'TVD ' Start Dir 3.5 °/100': 9916.1' MD, 5922.8'TVD ' o 4840 9 5/8 , End Dir: 12674.7' MD, 6239.4' TVD End Dir: 10861.1' MD, 6191.2' TVD I-- a) 5280 ` ' Start Dir 3 °/100': 13657.2' MD, 6254.5'TVD �. Start Dir 3 °/100': 11305.5' MD, 6222 TVD I y� �' End Dir: 13851' MD, 6257.7' TVD Top HRZ rp0 ' i 5720 �. _ Start Dir 3 °/100': 14755.7' MD, 6272.3'TVD Base HRZ co . 7" __ - - r. ' ts• t i .. _ Kalubik Mkr eo ; o m o). - _ Q; - " End Dir: 15008.8' MD, 6277.2' TVD 6160 -- - - - ' ' • cn - _ - co ao ' _ _ _ - - - K `a 4 Total Depth: 16172.5' MD, 6303.2' TVD p - Base Kup C (LCU) 6600 I4 1/2" ODSK- 13i /ODSK -13 PK1 wp14 \ \ . BCU PK1 v11 T1 PK1 v14 T2 PK1 v14 T3 PK1 v14 T4 PK1 v14 T5 ` Nuigsut I R Nuiqsut l 7040 , Nechelik ODSK- 13i /ODSK -13 PK1 PH wp06 B Nechelik 1 1 1 I 1 I I I 1 1 1 1 1 1 1 1 1 1 1 1 I I 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 I l 1 1 1 1 I 1 l 1 l 1 1 1 1 1 l 1 l 1 I 1 1 1 1 l 1 l I 1 1 1 1 l 1 l l 1 1 1 1 1 4400 4840 5280 5720 6160 6600 7040 7480 7920 8360 8800 9240 9680 10120 10560 11000 11440 11880 12320 12760 13200 13640 14080 14520 Vertical Section at 349.64? (1100 ft/in) 0 • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -13i - Slot ODS -13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7 + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -13i Survey Calculation Method: Minimum Curvature Welibore: KUP C lateral PK1 Design: ODSK -13 PK1 wp14 Project Oooguruk Development 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 Oooguruk Drill Site Site Position: Northing: 6,031,151.32ft Latitude: 70° 29' 46.242 N From: Map Easting: 469,920.45ft Longitude: 150° 14' 45.465 W Position Uncertainty: 0.0 ft Slot Radius: in Grid Convergence: -0.23 ? Well ODSK -13i - Slot ODS -13 Well Position +N / -S 0.0 ft Northing: 6,031,076.06 ft Latitude: 70° 29' 45.498 N +E / -W 0.0 ft Easting: 469,845.81 ft Longitude: 150° 14' 47.653 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5 ft Wei!bore KUP C lateral PK1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) ( ?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSK -13 PK1 wp14 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,294.6 Vertical Section: Depth From (TVD) +N /-S +Etal11 Direction (ft) (ft) (ft) ( ?) 42.7 0.0 0.0 349.64 11/17/2010 4:31:00PM Page 2 COMPASS 2003.16 Build 428 • • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -13i - Slot ODS -13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -13i Survey Calculation Method: Minimum Curvature Wel!bore: KUP C lateral PK1 Design: ODSK -13 PK1 wp14 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/ -W Rate Rate Rate Tool Face (ft) {?) ( ?) (ft) ft (ft) (ft) (7/100ft) (7 /100ft) (7 /100ft) ( ?) 9,294.6 56.76 354.19 5,601.0 5,544.8 5,654.6 1,905.5 0.00 0.00 0.00 0.00 9,354.6 54.80 355.88 5,634.7 5,578.5 5,704.1 1,901.2 4.00 -3.26 2.81 145.00 9,709.7 61.16 345.78 5,823.3 5,767.1 6,000.4 1,852.4 3.00 1.79 -2.84 -56.19 9,916.1 61.16 345.78 5,922.8 5,866.6 6,175.7 1,808.0 0.00 0.00 0.00 0.00 10,861.1 86.00 322.77 6,191.2 6,135.0 6,974.4 1,410.1 3.50 2.63 -2.43 -45.60 11,305.5 86.00 322.77 6,222.2 6,166.0 7,327.4 1,141.8 0.00 0.00 0.00 0.00 11,405.5 89.00 322.77 6,226.6 6,170.4 7,406.9 1,081.4 3.00 3.00 0.00 0.00 11,618.9 89.52 316.39 6,229.3 6,173.1 7,569.3 943.1 3.00 0.24 -2.99 -85.43 12,367.7 89.52 316.39 6,235.7 6,179.5 8,111.4 426.6 0.00 0.00 0.00 0.00 12,662.7 89.11 325.23 6,239.2 6,183.0 8,339.8 240.4 3.00 -0.14 3.00 92.67 12,674.7 89.12 325.59 6,239.4 6,183.2 8,349.7 233.6 3.00 0.05 3.00 88.99 13,657.2 89.12 325.59 6,254.5 6,198.3 9,160.2 -321.6 0.00 0.00 0.00 0.00 13,823.7 89.03 320.59 6,257.2 6,201.0 9,293.2 -421.6 3.00 -0.05 -3.00 -91.02 13,851.0 89.07 321.41 6,257.7 6,201.5 9,314.5 -438.7 3.00 0.14 3.00 87.29 14,755.7 89.07 321.41 6,272.3 6,216.1 10,021.5 - 1,002.9 0.00 0.00 0.00 0.00 15,008.8 88.72 313.83 6,277.2 6,221.0 10,208.3 - 1,173.3 3.00 -0.14 -3.00 -92.72 16,172.5 88.72 313.83 6,303.2 6,247.0 11,014.0 - 2,012.7 0.00 0.00 0.00 0.00 11/17/2010 4:31 :00PM Page 3 COMPASS 2003.16 Build 42B • • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -13i - Slot ODS -13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site; Oooguruk Drill Site North Reference: True Well: ODSK -13i Survey Calculation Method: Minimum Curvature Wei!bore: • ODSK -13i KupH Design: ODSK -13 PK1 PH wp06 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +Et W , Northing Easting DLS Vert Section (ft) ( ?) (7) (ft) ft (ft) (ft) (ft) (ft) 2,892.61 3,512.0 63.59 2.08 2,948.8 2,892.6 1,293.4 - 485.4 6,032,371.28 469,365.71 0.00 1,192.74 Kop: 3512' MD, 2948,8' TVD - 11 3/4" 3,572.0 63.59 2.08 2,975.5 2,919.3 1,347.1 - 483.4 6,032,424.97 469,367.88 0.00 1,246.00 Start Dir 3 °1100': 3572' MD, 2975.57VD: 96.51° RT TF 3,600.0 63.50 3.01 2,988.0 2,931.8 1,372.1 -482.3 6,032,450.01 469,369.09 3.00 1,270.87 3,700.0 63.22 6.35 3,032.8 2,976.6 1,461.2 -475.0 6,032,539.04 469,376.75 3.00 1,359.89 3,800.0 63.02 9.71 3,078.0 3,021.8 1,549.5 -462.6 6,032,627.28 469,389.56 3.00 1,449.02 3,900.0 62.90 13.08 3,123.5 3,067.3 1,636.8 -445.0 6,032,714.49 469,407.50 3.00 1,538.04 4,000.0 62.86 16.45 3,169.1 3,112.9 1,722.9 -422.3 6,032,800.44 469,430.52 3.00 1,626.68 4,100.0 62.90 19.82 3,214.7 3,158.5 1,807.4 -394.6 6,032,884.89 469,458.56 3.00 1,714.71 4,200.0 63.02 23.18 3,260.2 3,204.0 1,890.3 -362.0 6,032,967.60 469,491.53 3.00 1,801.89 4,224.3 63.06 24.00 3,271.2 3,215.0 1,910.2 -353.3 6,032,987.44 469,500:29 3.00 1,822.95 Hue 2 Tuff 4,300.0 63.22 26.54 3,305.4 3,249.2 1,971.2 -324.5 6,033,048.36 469,529.35 3.00 1,887.98 4,400.0 63.50 29.88 3,350.2 3,294.0 2,049.9 -282.2 6,033,126.93 469,571.91 3.00 1,972.74 4,500.0 63.86 33.20 3,394.6 3,338.4 2,126.3 -235.4 6,033,203.11 469,619.10 3.00 2,055.94 4,600.0 64.29 36.50 3,438.3 3,382.1 2,200.1 -184.0 6,033,276.68 469,670.78 3.00 2,137.36 4,700.0 64.80 39.78 3,481.3 3,425.1 2,271.1 -128.2 6,033,347.44 469,726.82 3.00 2,216.76 4,718.3 64.90 40.38 3,489.1 3,432.9 2,283.8 -117.5 6,033,360.07 469,737.54 3.00 2,231.05 End Dir: 4718' MD, 3489.1' TVD 4,718.8 64.90 40.39 3,489.3 3,433.1 2,284.1 -117.3 6,033,360.42 469,737.84 3.00 2,231.45 i 4,800.0 64.90 40.39 3,523.7 3,467.5 2,340.1 -69.6 6,033,416.22 469,785.70 0.00 2,294.70 4,900.0 64.90 40.39 3,566.1 3,509.9 2,409.1 -10.9 6,033,484.95 469,844.66 0.00 2,372.59 5,000.0 64.90 40.39 3,608.6 3,552.4 2,478.1 47.8 6,033,553.67 469,903.62 0.00 2,450.49 5,100.0 64.90 40.39 3,651.0 3,594.8 2,547.1 106.4 6,033,622.40 469,962.57 0.00 2,528.39 5,200.0 64.90 40.39 3,693.4 3,637.2 2,616.0 165.1 6,033,691.13 470,021.53 0.00 2,606.29 5,300.0 64.90 40.39 3,735.8 3,679.6 2,685.0 223.8 6,033,759.85 470,080.49 0.00 2,684.19 5,400.0 64.90 40.39 3,778.2 3,722.0 2,754.0 282.5 6,033,828.58 470,139.44 0.00 2,762.09 5,500.0 64.90 40.39 3,820.6 3,764.4 2,822.9 341.2 6,033,897.31 470,198.40 0.00 2,839.99 5,600.0 64.90 40.39 3,863.1 3,806.9 2,891.9 399.9 6,033,966.03 470,257.35 0.00 2,917.89 5,700.0 64.90 40.39 3,905.5 3,849.3 2,960.9 458.5 6,034,034.76 470,316.31 0.00 2,995.78 5,800.0 64.90 40.39 3,947.9 3,891.7 3,029.9 517.2 6,034,103.49 470,375.27 0.00 3,073.68 5,900.0 64.90 40.39 3,990.3 3,934.1 3,098.8 575.9 6,034,172.21 470,434.22 0.00 3,151.58 6,000.0 64.90 40.39 4,032.7 3,976.5 3,167.8 634.6 6,034,240.94 470,493.18 0.00 3,229.48 6,100.0 64.90 40.39 4,075.1 4,018.9 3,236.8 693.3 6,034,309.67 470,552.13 0.00 3,307.38 6,200.0 64.90 40.39 4,117.6 4,061.4 3,305.7 752.0 6,034,378.39 470,611.09 0.00 3,385.28 6,300.0 64.90 40.39 4,160.0 4,103.8 3,374.7 810.6 6,034,447.12 470,670.05 0.00 3,463.18 6,400.0 64.90 40.39 4,202.4 4,146.2 3,443.7 869.3 6,034,515.85 470,729.00 0.00 3,541.08 6,500.0 64.90 40.39 4,244.8 4,188.6 3,512.7 928.0 6,034,584.57 470,787.96 0.00 3,618.98 6,600.0 64.90 40.39 4,287.2 4,231.0 3,581.6 986.7 6,034,653.30 470,846.91 0.00 3,696.87 6,700.0 64.90 40.39 4,329.6 4,273.4 3,650.6 1,045.4 6,034,722.03 470,905.87 0.00 3,774.77 6,800.0 64.90 40.39 4,372.1 4,315.9 3,719.6 1,104.0 6,034,790.75 470,964.83 0.00 3,852.67 6,833.3 64.90 40.39 4,386.2 4,330.0 3,742.6 1,123.6 6,034,813.66 470,984.47 0.00 3,878.63 Brook 2B 6,900.0 64.90 40.39 4,414.5 4,358.3 3,788.5 1,162.7 6,034,859.48 471,023.78 0.00 3,930.57 11/18/2010 7 :23:52AM Page 3 COMPASS 2003.16 Build 428 • • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -13i - Slot ODS -13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7 + 13.5 @ 56.2ft (Nabors 19AC) Project:. Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Weil ODSK -13i Survey Calculation Method: Minimum Curvature Welibore: ODSK -13i KupH Design: ODSK -13 PK1 PH wp06 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/.S +E(W Northing Easting DLS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) 4,400.70 7,000.0 64.90 40.39 4,456.9 4,400.7 3,857.5 1,221.4 6,034,928.21 471,082.74 0.00 4,008.47 7,100.0 64.90 40.39 4,499.3 4,443.1 3,926.5 1,280.1 6,034,996.93 471,141.69 0.00 4,086.37 7,200.0 64.90 40.39 4,541.7 4,485.5 3,995.5 1,338.8 6,035,065.66 471,200.65 0.00 4,164.27 7,253.5 64.90 40.39 4,564.4 4,508.2 4,032.4 1,370.2 6,035,102.44 471,232.20 0.00 4,205.96 7,256.6 64.88 40.33 4,565.7 4,509.5 4,034.5 1,372.0 6,035,104.55 471,234.01 2.00 4,208.35 Start Dir 2 °/100': 7254.6' MD, 4565.7'TVD 7,300.0 64.55 39.44 4,584.3 4,528.1 4,064.6 1,397.2 6,035,134.56 471,259.30 2.00 4,242.29 7,400.0 63.81 37.38 4,627.8 4,571.6 4,135.1 1,453.1 6,035,204.86 471,315.50 2.00 4,321.25 7,500.0 63.10 35.29 4,672.5 4,616.3 4,207.2 1,506.1 6,035,276.69 471,368.79 2.00 4,401.23 7,600.0 62.42 33.17 4,718.3 4,662.1 4,280.7 1,556.1 6,035,349.98 471,419.09 2.00 4,482.13 7,700.0 61.77 31.03 4,765.1 4,708.9 4,355.6 1,603.1 6,035,424.64 471,466.35 2.00 4,563.84 1 7,800.0 61.16 28.86 4,812.9 4,756.7 4,431.7 1,646.9 6,035,500.56 471,510.51 2.00 4,646.28 7,900.0 60.58 26.67 4,861.6 4,805.4 4,509.0 1,687.6 6,035,577.68 471,551.52 2.00 4,729.33 8,000.0 60.04 24.45 4,911.1 4,854.9 4,587.3 1,725.1 6,035,655.88 471,589.31 2.00 4,812.90 8,100.0 59.54 22.21 4,961.4 4,905.2 4,666.7 1,759.3 6,035,735.07 471,623.86 2.00 4,896.88 8,200.0 59.07 19.95 5,012.5 4,956.3 4,746.9 1,790.2 6,035,815.16 471,655.12 2.00 4,981.18 8,300.0 58.65 17.67 5,064.2 5,008.0 4,827.9 1,817.8 6,035,896.04 471,683.04 2.00 5,065.69 8,400.0 58.26 15.37 5,116.5 5,060.3 4,909.6 1,842.1 6,035,977.63 471,707.60 2.00 5,150.30 8,500.0 57.92 13.04 5,169.4 5,113.2 4,991.9 1,862.9 6,036,059.82 471,728.76 2.00 5,234.92 8,505.3 57.90 12.92 5,172.2 5,116.0 4,996.2 1,863.9 6,036,064.18 471,729.79 2.00 5,239.39 Top Torok Ss 8,600.0 57.62 10.71 5,222.7 5,166.5 5,074.6 1,880.3 6,036,142.51 471,746.50 2.00 5,319.44 8,700.0 57.36 8.35 5,276.5 5,220.3 5,157.8 1,894.3 6,036,225.60 471,760.80 2.00 5,403.76 8,800.0 57.15 5.99 5,330.6 5,274.4 5,241.2 1,904.8 6,036,308.98 471,771.64 2.00 5,487.77 8,900.0 56.98 3.62 5,385.0 5,328.8 5,324.8 1,911.8 6,036,392.57 471,779.01 2.00 5,571.38 9,000.0 56.86 1.23 5,439.6 5,383.4 5,408.5 1,915.4 6,036,476.25 471,782.90 2.00 5,654.48 9,057.8 56.80 359.85 5,471.2 5,415.0 5,457.0 1,915.8 6,036,524.65 471,783.55 2.00 5,702.27 Base Torok Ss 9,100.0 56.78 358.85 5,494.3 5,438.1 5,492.2 1,915.4 6,036,559.92 471,783.29 2.00 5,736.97 9,200.0 56.75 356.45 5,549.1 5,492.9 5,575.8 1,912.0 6,036,643.49 471,780.20 2.00 5,818.74 9,285.9 56.75 354.40 5,596.2 5,540.0 5,647.4 1,906.3 6,036,715.09 471,774.77 2.00 5,888.33 Torok Shale 1 9,294.6 56.76 354.19 5,601.0 5,544.8 5,654.7 1,905.5 6,036,722.38 471,774.07 2.00 5,895.39 9 5/8" I 9,300.0 56.76 354.06 5,603.9 5,547.7 5,659.1 1,905.1 6,036,726.84 471,773.63 2.00 5,899.71 9,400.0 56.82 351.67 5,658.7 5,602.5 5,742.1 1,894.7 6,036,809.88 471,763.58 2.00 5,979.77 9,500.0 56.92 349.29 5,713.4 5,657.2 5,824.7 1,880.8 6,036,892.51 471,750.07 2.00 6,058.82 9,600.0 57.07 346.91 5,767.8 5,711.6 5,906.8 1,863.5 6,036,974.63 471,733.11 2.00 6,136.77 9,700.0 57.27 344.54 5,822.1 5,765.9 5,988.2 1,842.8 6,037,056.13 471,712.73 2.00 6,213.53 9,800.0 57.51 342.18 5,876.0 5,819.8 6,068.9 1,818.7 6,037,136.92 471,688.94 2.00 6,288.99 9,848.9 57.64 341.04 5,902.2 5,846.0 6,108.1 1,805.7 6,037,176.16 471,676.07 2.00 6,325.42 Top HRZ 9,900.0 57.79 339.84 5,929.5 5,873.3 6,148.8 1,791.2 6,037,216.89 471,661.78 2.00 6,363.07 10,000.0 58.12 337.51 5,982.5 5,926.3 6,227.7 1,760.4 6,037,295.96 471,631.28 2.00 6,435.67 11/18/2010 7 :23 :52AM Page 4 COMPASS 2003.16 Build 42B • • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK - 13i - Slot ODS - 13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -13i Survey Calculation Method: Minimum Curvature Weilbore: ODSK -13i KupH Design: ODSK -13 PK1 PH wp06 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-g +B/-W Northing Basting . DLS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) 5,972.00 10,086.8 58.44 335.51 6,028.2 5,972.0 6,295.5 1,731.0 6,037,363.81 471,602.12 2.00 6,497.45 Base HRZ 10,100.0 58.49 335.20 6,035.1 5,978.9 6,305.7 1,726.3 6,037,374.02 471,597.48 2.00 6,506.71 10,200.0 58.90 332.91 6,087.1 6,030.9 6,382.5 1,688.9 6,037,450.98 471,560.42 2.00 6,576.11 10,300.0 59.35 330.64 6,138.4 6,082.2 6,458.1 1,648.3 6,037,526.75 471,520.14 2.00 6,643.77 10,342.9 59.55 329.67 6,160.2 6,104.0 6,490.1 1,629.9 6,037,558.88 471,501.89 2.00 6,672.26 Kalubik Mkr 10,400.0 59.83 328.39 6,189.0 6,132.8 6,532.4 1,604.6 6,037,601.23 471,476.70 2.00 6,709.62 10,432.3 60.00 327.67 6,205.2 6,149.0 6,556.1 1,589.8 6,037,625.00 471,462.00 2.00 6,730.49 Kup C - PH PK1 v6T1 10,456.1 59.52 327.67 6,217.2 6,161.0 6,573.5 1,578.8 6,037,642.44 471,451.06 2.00 6,745.77 Base Kup C (LCU) 10,500.0 58.65 327.67 6,239.7 6,183.5 6,605.3 1,558.6 6,037,674.32 471,431.06 2.00 6,773.71 10,600.0 56.65 327.67 6,293.3 6,237.1 6,676.7 1,513.5 6,037,745.87 471,386.18 2.00 6,836.43 10,683.6 54.97 327.67 6,340.2 6,284.0 6,735.1 1,476.5 6,037,804.41 471,349.47 2.00 6,887.74 BCU 10,700.0 54.65 327.67 6,349.7 6,293.5 6,746.4 1,469.3 6,037,815.80 471,342.32 2.00 6,897.72 10,770.5 53.24 327.67 6,391.2 6,335.0 6,794.6 1,438.8 6,037,864.10 471,312.03 2.00 6,940.05 Nuigsut 10,800.0 52.65 327.67 6,409.0 6,352.8 6,814.5 1,426.2 6,037,884.01 471,299.54 2.00 6,957.51 10,900.0 50.65 327.67 6,471.0 6,414.8 6,880.7 1,384.3 6,037,950.44 471,257.87 2.00 7,015.72 10,916.0 50.33 327.67 6,481.2 6,425.0 6,891.2 1,377.7 6,037,960.91 471,251.30 2.00 7,024.90 B Nuigsut 10,931.6 50.01 327.67 6,491.2 6,435.0 6,901.3 1,371.3 6,037,971.07 471,244.93 2.00 7,033.81 Nechelik 11,000.0 48.65 327.67 6,535.7 6,479.5 6,945.1 1,343.6 6,038,014.98 471,217.39 2.00 7,072.30 11,023.3 48.18 327.67 6,551.2 6,495.0 6,959.8 1,334.2 6,038,029.73 471,208.14 2.00 7,085.22 B Nechelik 11,100.0 46.65 327.67 6,603.1 6,546.9 7,007.6 1,304.0 6,038,077.58 471,178.12 2.00 7,127.16 11,200.0 44.65 327.67 6,673.0 6,616.8 7,068.0 1,265.8 6,038,138.14 471,140.14 2.00 7,180.24 11,300.0 42.65 327.67 6,745.4 6,689.2 7,126.3 1,228.9 6,038,196.60 471,103.47 2.00 7,231.48 11,314.6 42.35 327.67 6,756.2 6,700.0 7,134.7 1,223.6 6,038,204.97 471,098.22 2.00 7,238.82 Total Depth: 11313,2' MD, 6756.2' TVD . 11,314.7 42.35 327.67 6,756.2 6,700.0 7,134.7 1,223.6 6,038,205.00 471,098.20 2.00 7,238.84 11/18/2010 7 :23 :52AM Page 5 COMPASS 2003.16 Build 428 • • Halliburton Company HALLIBURTON Standard Proposal Report • Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK - 13i - Slot ODS - 13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: • 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: • 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: ' Oooguruk Drill Site North Reference: True Welk ODSK -13i Survey Calculation Method: Minimum Curvature Welibore: ODSK -13i KupH Design: ODSK -13 PK1 PH wp06 Targets Target Name - hit/miss target Dip Angle Dip Dlr. TVD +NI-S +E/-W Northing Easting - Shape ( ?) ( (ft) (ft) (ft) (ft) (ft) PK1 v2 Curve 0.00 0.00 5,269.2 5,174.0 1,563.0 6,036,243.16 471,429.63 - plan misses by 330.1ft at 8663.3ft MD (5256.7 TVD, 5127.2 N, 1889.6 E) - Point PH PK1 v5T2 0.00 0.00 6,395.2 6,911.0 1,364.1 6,037,980.80 471,237.80 - plan misses by 81.8ft at 10881.5ft MD (6459.3 TVD, 6868.6 N, 1392.0 E) - Point PK1 v2 Heel 0.00 0.00 6,151.2 6,623.0 1,565.5 6,037,692.00 471,438.00 - plan misses by 83.1ft at 10464.2ft MD (6221.3 TVD, 6579.4 N, 1575.0 E) - Point PK1 v3 mid 0.00 0.00 6,151.2 8,100.4 388.4 6,039,174.00 470,267.00 - plan misses by 1412.9ft at 11314.7ft MD (6756.2 TVD, 7134.7 N, 1223.6 E) - Point ODSN -13 Nuiq Take Point 1 0.00 0.00 6,386.2 7,213.3 386.0 6,038,287.00 470,261.00 - plan misses by 919.1ft at 11314.7ft MD (6756.2 TVD, 7134.7 N, 1223.6 E) - Point KupHi v7 T1 0.00 0.00 5,990.2 4,575.0 - 3,321.7 6,035,664.00 466,543.00 - plan misses by 4603.6ft at 5479.2ft MD (3811.8 TVD, 2808.6 N, 329.0 E) - Circle (radius 200.0) KupHi PB1 SCP 0.00 0.00 3,000.0 1,397.0 -506.7 6,032,474.92 469,344.86 - plan misses by 25.8ft at 3625.7ft MD (2999.5 TVD, 1395.1 N, -481.0 E) - Point PH PK1 v6T1 0.00 0.00 6,205.2 6,556.1 1,589.8 6,037,625.00 471,462.00 - plan hits target - Point PK1 v3 Lateral Toe 0.00 0.00 6,151.2 10,937.7 - 2,075.4 6,042,021.00 467,815.00 - plan misses by 5070.7ft at 11314.7ft MD (6756.2 TVD, 7134.7 N, 1223.6 E) - Point PK1 Heel 0.00 0.00 6,206.2 6,728.2 877.0 6,037,800.00 470,750.00 - plan misses by 589.7ft at 10847.4ft MD (6438.0 TVD, 6846.1 N, 1406.2 E) - Point PH PK1 v5T1 0.00 0.00 6,210.2 6,640.9 1,545.4 6,037,710.00 471,418.00 - plan misses by 45.3ft at 10515.6ft MD (6247.9 TVD, 6616.5 N, 1551.5 E) - Point PH PK1 v3 T1 0.00 0.00 6,210.2 6,706.9 1,507.1 6,037,776.10 471,379.90 - plan misses by 86.0ft at 10580.0ft MD (6282.3 TVD, 6662.5 N, 1522.4 E) - Point PK1 v3 Heel 0.00 0.00 6,151.2 7,566.3 1,106.6 6,038,637.00 470,983.00 - plan misses by 738.8ft at 11197.1ft MD (6671.0 TVD, 7066.3 N, 1266.9 E) - Point PH PK1 v3 T2 0.00 0.00 6,395.2 6,911.0 1,364.1 6,037,980.80 471,237.80 - plan misses by 81.8ft at 10881.5ft MD (6459.3 TVD, 6868.6 N, 1392.0 E) - Point PK1 v2 Curve 2 0.00 0.00 5,238.3 5,119.9 1,576.6 6,036,188.97 471,443.04 - plan misses by 307.4ft at 8593.1ft MD (5219.1 TVD, 5068.9 N, 1879.2 E) - Point 11/18/2010 7:23 :52AM Page 6 COMPASS 2003.16 Build 428 • • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -13i - Slot ODS -13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: _ Oooguruk Drill Site North, Reference: True Well: ODSK -13i • Survey Calculation Method: Minimum Curvature Welibore: ODSK -13i KupH Design: ODSK -13 PK1 PH wp06 Casing Points Measured Vertical Casing NOW Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 3,512.0 2,948.8 11 3/4" 11.750 14.500 9,294.6 5,601.0 9 5/8" 9.625 11.750 Formations Measured . Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (T) (7) 10,432.3 6,205.2 Kup C 0.00 10,770.5 6,391.2 Nuiqsut 0.00 10,342.9 6,160.2 Kalubik Mkr 0.00 10,456.1 6,217.2 Base Kup C (LCU) 0.00 10,931.6 6,491.2 Nechelik 0.00 8,505.3 5,172.2 Top Torok Ss 0.00 10,683.6 6,340.2 BCU 0.00 4,224.3 3,271.2 Hue 2 Tuff 0.00 9,285.9 5,596.2 Torok Shale 1 0.00 9,848.9 5,902.2 Top HRZ 0.00 9,057.8 5,471.2 Base Torok Ss 0.00 10,916.0 6,481.2 B Nuiqsut 0.00 10,086.8 6,028.2 Base HRZ 0.00 6,833.3 4,386.2 Brook 2B 0.00 11,023.3 6,551.2 B Nechelik 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth iN /-S +0-W (ft) (ft) (ft) (ft) Comment 3,512.0 2,948.8 1,293.4 -485.4 Kop: 3512' MD, 2948.8' TVD 3,572.0 2,975.5 1,347.1 -483.4 Start Dir 3 °/100': 3572' MD, 2975.5'TVD: 96.51° RT TF 4,718.3 3,489.1 2,283.8 -117.5 End Dir: 4718' MD, 3489.1' TVD 7,256.6 4,565.7 4,034.5 1,372.0 Start Dir 2 °/100': 7254.6' MD, 4565.7'TVD 11,314.6 6,756.2 7,134.7 1,223.6 Total Depth: 11313.2' MD, 6756.2' TVD 11/18/2010 7 :23 :52AM Page 7 COMPASS 2003.16 Build 42B Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -13i ODSK -13i KupH 50- 703 - 20607 -00 ODSK -13 PK1 PH wp06 • Sperry i l l ire Services Clearance Summary Anticollision Report 17 November, 2010 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - ODSK -13i KupH - ODSK -13 PK1 PH wp06 Well Coordinates: 6,031,076.06 N, 469,845.81 E (70° 29' 45.50" N, 150° 14' 47.65" W) Datum Height: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Scan Range: 3,512.0 to 11,314.7 ft. Measured Depth. Scan Radius is 1,327.2 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42B Scan Type: GLOBAL FILTER APPLIED: All welipaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLJE3URTON I I I I Sperry Drilling Services SURVEY PROGRAM ANTI- COLLISION SETTINGS late: 2 10 26T00:00:00 Validated: Yes Version: Interpolation Method: MD, interval: 25.0 Depth Range From: 3512.0 To 11314.7 Depth From Depth To Survey/Plan Tool Results Limited By: Centre Distance: 1327.2 100.0 532.0 ODSK - 13 Gyro (ODSK - 131 KupH) SR Gyro Reference: Plan: ODSK -13 PK1 PH wp06 (ODSK -13i /ODSK -131 KupH) 573.7 3512.0 ODSK - 13 MWD (ODSK - 13i KupH) MWD+IFR2 +MS+sag Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 10011000 of reference 3512.0 11314.7 ODSK - 13 PK1 PH wp06 (ODSK - 13i Ku()1I1VD+IFR2 +MS+sag 0 KUP C lateral PK" KUP C lateral PK' 330 t su - _,..-x`",,30 a • 0, ,, From Color To MD 21 330 0 11 30 I 300 en / 0 250 ODSK -13i Kupl �,- „�.° 0 250 500 ' ' f'` ` ~`"° -a,` 500 750 1 ( 1 n �, I ' 1! .\ p 750 1000 300 , K \ 60 1000 - " ' 1250 ' r °`ice T. ,25U ,566 270 - A 90 • ■ 1 ` i ,750 \ 1500 1750 11.W ® 2000 \ ! ,�{ 2000 2250 2 ""`•..5 \ t 2250 2500 1 2500 2750 1 1 2750 3000 240 120 270 .-- 90 3000 4000 4000 5000 2Q. 5000 6000 6000 ' 7000 7000 8000 210 - 150 8000 """ -- 9000 30 O DSK -13I Kup 180 9000 10000 10000 11000 240 511.... 120 11000 12000 12000 13000 13000 ' 14000 Travelling Cylinder Azimuth (TFO+AZI) 1 ?1 vs Centre to Centre Separation [20 ft/ l 14000 - ' -' 15000 75 15000 16000 16000 17000 210 150 17000 18000 18000 19000 101 19000 20000 180 20000 ""- 21000 SECTION DETAILS Travelling Cylinder Azimuth (TFO+AZI) ( ?] vs Centre to Centre Separation 150 ft/in] Sec MD no AS 48 8 41 4E/-W Meg TFace Vsec Target 1 3512.0 63.59 208 29488 12934 -4854 000 000 11923 2 35720 6359 208 29755 13471 -483.4 000 8 1246.0 3 4718.8 6490 4039 34893 2284.1 -1173 3.00 9649 2231.4 4 7253.5 6490 4039 45644 40324 1370.2 000 000 42066 5 10432.3 6.00 32767 62052 65561 1589.9 2.00 -11257 673135 PM PK1 v6T1 REFERENCE INFORMATION Well Planning - Pioneer - Oooguruk 6 11314.7 4235 32767 67562 7134.7 12236 2.00 180.00 7236.8 Co-ordinate (N /E) Reference: Well ODSK -13i - Slot ODS -13, True North Calculation Method: Minimum Curvature Vertical (TVD) Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Error System: ISCWSA Section (VS) Reference: Slot - ODS- 13(0.0N, 0.0E) S can Method: Tray. Cylinder North Measured Depth Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Y Calculation Method: Minimum Curvature Error Surface: Elliptical Conic Warning Method: Rules Based NAD 27 ASP Zone 4 : WELL DETAILS: ODSK -13i Ground Level: 13.5 +N /-S +E/ -W Northing Easting Latittude Longitude Slot 0.0 0.0 6031076.06 469845.81 70° 29' 45.498 N 150° 14' 47.653 W ODS -13 Well Planning - Pioneer - Oooguruk HALLIEURTDN Oooguruk Development Anticollision Report for ODSK -13i - ODSK -13 PK1 PH wp06 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - ODSK -13i KupH - ODSK -13 PK1 PH wp06 Scan Range: 3,512.0 to 11,314.7 ft. Measured Depth. Scan Radius is 1,327.2 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Welibore Name - Design (ft) (ft) (ft) (ft) ft Oooguruk Drill Site • ODSK -13i - KUP C lateral PK1 - ODSK -13 PK1 wp15 ODSK -13i - ODSK -13i KupH - ODSK -13i KupH =MN IIIIIIMI ORM MMES... ODSN -1 - ODSN -1 - ODSDW2 -1 Disposal wp05 3,821.2 333.9 3,821.2 267.2 3,525.0 5.004 Clearance Factor Pass - Major Risk ODSN -1 - ODSN -1 - ODSDW2 -1 Disposal wp05 3,890.9 332.1 3,890.9 268.6 3,600.0 5.229 Centre Distance Pass - Major Risk ODSN -19 - ODSDW2 -19 Disposal - ODSDW2 -19 Disp 3,514.3 380.3 3,514.3 312.1 3,725.0 5.572 Clearance Factor Pass - Major Risk ODSN -29i - ODSN -29i IN4 - ODSN -29i IN4 wp06 11,300.0 1,158.0 11,300.0 899.3 14,850.0 4.475 Clearance Factor Pass - Major Risk ODSN -30 - ODSN -30 PN5 - ODSN -30 PN5 wp05 10,901.0 552.9 10,901.0 304.1 13,500.0 2.222 Centre Distance Pass - Major Risk ODSN -30 - ODSN -30 PN5 - ODSN -30 PN5 wp05 10,975.5 557.2 10,975.5 299.0 13,600.0 2.158 Clearance Factor Pass - Major Risk ODSN -3i - ODSDW -2 Wp01 - ODSDW -2 wp01 4,229.1 104.0 4,229.1 26.4 4,050.0 1.340 Clearance Factor Pass - Major Risk ODSN -3i - ODSDW -2 Wp01 - ODSDW -2 wp01 4,268.7 98.1 4,268.7 32.6 4,100.0 1.498 Centre Distance Pass - Major Risk ODSN -3i - ODSN -3i IS2 - ODSN -3i IS2 wp08 7,367.9 1,244.1 7,367.9 1,067.2 6,675.0 7.033 Centre Distance Pass - Major Risk ODSN -3i - ODSN -3i IS2 - ODSN -3i IS2 wp08 7,454.9 1,245.3 7,454.9 1,065.6 6,800.0 6.929 Clearance Factor Pass - Major Risk ODSN -4 - ODSN -4 PS3 - ODSN -4 PS3 wp07 7,294.0 577.7 7,294.0 401.8 6,875.0 3.284 Centre Distance Pass - Major Risk ODSN -4 - ODSN -4 PS3 - ODSN -4 PS3 wp07 7,400.0 580.1 7,400.0 399.5 7,000.0 3.212 Clearance Factor Pass - Major Risk ODSN -5i - ODSN -5i IS4 - ODSN -5i IS4 wp08 8,080.5 609.3 8,080.5 449.5 7,900.0 3.812 Centre Distance Pass - Major Risk ODSN -5i - ODSN -5i IS4 - ODSN -5i IS4 wp08 8,169.1 611.0 8,169.1 446.1 8,000.0 3.705 Clearance Factor Pass - Major Risk • ODSN -6 - ODSN -6 PS5 - ODSN -6 PS5 wp09 3,521.9 626.9 3,521.9 562.2 3,600.0 9.691 Clearance Factor Pass - Major Risk ODSN -8 - ODSN -8 PS8 - ODSN -8 PS8 wp08 - 8K' Ho 3,515.0 674.0 3,515.0 621.0 3,750.0 12.730 Clearance Factor Pass - Major Risk ODSN -9i - ODSN -9i IS9 - ODSN -9i IS9 wp11 - 8K' Hor 3,521.5 1,118.6 3,521.5 1,059.0 4,125.0 18.777 Clearance Factor Pass - Major Risk 17 November, 2010 - 10:49 Page 2 of 5 COMPASS Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -13i - ODSK -13 PK1 PH wp06 Survey tool program From To Survey /Plan Survey Tool (ft) (ft) 100.0 532.0 SR- Gyro -SS 573.7 3,512.0 MWD +IFR2 +MS +sag 3,512.0 11,314.7 ODSK -13 PK1 PH wp06 MWD +IFR2 +MS +sag Ellipse error terms are correlated across survey tool tie -on points. • Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. • 17 November, 2010 - 10:49 Page 3 of 5 COMPASS • • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -13i - Slot ODS -13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -13i Survey Calculation Method: Minimum Curvature Wel!bore: KUP C lateral PK1 Design: ODSK -13 PK1 wp14 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/ W Northing Easting DLS Veil Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) " 5,544.80 9,294.6 56.76 354.19 5,601.0 5,544.8 5,654.7 1,905.5 6,036,722.38 471,774.07 1.99 • 5,220.00 KOP: 4 6 /100' 145°RHTF 9294.6' MD, 560V TVD - 9 5/8" 9,300.0 56.58 354.34 5,603.9 5,547.7 5,659.1 1,905.1 6,036,726.84 471,773.64 4.03 5,224.47 9,354.6 54.80 355.88 5,634.7 5,578.5 5,704.1 1,901.2 6,036,771.78 471,769.97 4.00 5,269.36 Start Dir 3 °1100': 9354.6' MD, 5634.7'TVD 9,400.0 55.57 354.50 5,660.6 5,604.4 5,741.2 1,898.1 6,036,808.93 471,767.00 3.00 5,306.46 9,500.0 57.31 351.57 5,715.9 5,659.7 5,823.9 1,888.0 6,036,891.66 471,757.21 3.00 5,389.62 9,600.0 59.11 348.75 5,768.6 5,712.4 5,907.6 1,873.4 6,036,975.43 471,743.01 3.00 5,474.60 9,700.0 60.97 346.04 5,818.6 5,762.4 5,992.1 1,854.5 6,037,060.03 471,724.43 3.00 5,561.16 9,709.7 61.16 345.78 5,823.3 5,767.1 6,000.4 1,852.4 6,037,068.27 471,722.40 3.00 5,569.63 End Dir: 9709.7' MD, 5823.3' TVD 9,800.0 61.16 345.78 5,866.8 5,810.6 6,077.1 1,833.0 6,037,145.02 471,703.27 0.00 5,648.55 9,873.4 61.16 345.78 5,902.2 5,846.0 6,139.3 1,817.2 6,037,207.36 471,687.74 0.00 5,712.66 Top HRZ 9,900.0 61.16 345.78 5,915.1 5,858.9 6,162.0 1,811.5 6,037,230.00 471,682.10 0.00 5,735.94 9,916.1 61.16 345.78 5,922.8 5,866.6 6,175.6 1,808.0 6,037,243.69 471,678.69 0.00 5,750.01 Start Dir 3.5 °/100': 9916.1' MD, 5922.8'TVD . 10,000.0 63.23 343.43 5,962.0 5,905.8 6,247.2 1,788.3 6,037,315.29 471,659.26 3.50 5,823.93 10,100.0 65.75 340.74 6,005.0 5,948.8 6,333.0 1,760.5 6,037,401.25 471,631.83 3.50 5,913.38 10,158.1 67.24 339.22 6,028.2 5,972.0 6,383.1 1,742.3 6,037,451.40 471,613.79 3.50 5,965.92 Base HRZ 10,200.0 68.32 338.15 6,044.0 5,987.8 6,419.2 1,728.2 6,037,487.56 471,599.85 3.50 6,003.98 10,300.0 70.93 335.66 6,078.9 6,022.7 6,505.4 1,691.4 6,037,573.91 471,563.42 3.50 6,095.39 10,400.0 73.56 333.24 6,109.3 6,053.1 6,591.3 1,650.3 6,037,659.97 471,522.70 3.50 6,187.28 10,500.0 76.23 330.89 6,135.4 6,079.2 6,676.6 1,605.1 6,037,745.43 471,477.82 3.50 6,279.30 10,600.0 78.92 328.60 6,156.9 6,100.7 6,760.9 1,555.9 6,037,829.95 471,428.96 3.50 6,371.11 10,617.4 79.39 328.20 6,160.2 6,104.0 6,775.5 1,546.9 6,037,844.54 471,420.07 3.50 6,387.03 Kalubik Mkr 10,700.0 81.62 326.34 6,173.8 6,117.6 6,844.0 1,502.9 6,037,913.24 471,376.31 3.50 6,462.36 10,800.0 84.34 324.12 6,186.1 6,129.9 6,925.5 1,446.3 6,037,994.97 471,320.05 3.50 6,552.72 10,861.1 86.00 322.77 6,191.2 6,135.0 6,974.4 1,410.1 6,038,044.00 471,284.00 3.50 6,607.33 End Dir: 10861.1' MD, 6191.2' TVD - PK1 vii T1 10,900.0 86.00 322.77 6,193.9 6,137.7 7,005.3 1,386.6 6,038,075.00 471,260.64 0.00 6,641.96 11,000.0 86.00 322.77 6,200.9 6,144.7 7,084.8 1,326.2 6,038,154.67 471,200.61 0.00 6,730.94 11,061.8 86.00 322.77 6,205.2 6,149.0 7,133.8 1,288.9 6,038,203.88 471,163.53 0.00 6,785.92 Kup C 11,100.0 86.00 322.77 6,207.9 6,151.7 7,164.2 1,265.9 6,038,234.33 471,140.59 0.00 6,819.92 11,101.9 86.00 322.77 6,208.0 6,151.8 7,165.7 1,264.7 6,038,235.86 471,139.44 0.00 6,821.63 7" 11,200.0 86.00 322.77 6,214.8 6,158.6 7,243.6 1,205.5 6,038,313.99 471,080.56 0.00 6,908.91 11,233.8 86.00 322.77 6,217.2 6,161.0 7,270.5 1,185.1 6,038,340.93 471,060.27 0.00 6,938.99 Base Kup C (LCU) 11,300.0 86.00 322.77 6,221.8 6,165.6 7,323.0 1,145.1 6,038,393.66 471,020.54 0.00 6,997.89 11,305.5 86.00 322.77 6,222.2 6,166.0 7,327.4 1,141.8 6,038,398.04 471,017.24 0.00 7,002.78 Start Dir 3 °1100': 11305.5' MD, 6222.2'TVD 11/17/2010 4:31:00PM Page 4 COMPASS 2003.16 Build 428 • 0 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK - 13i - Slot ODS - 13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: ' 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK - 13i Survey Calculation Method: Minimum Curvature Wel'bore: KUP C lateral PK1 Design: ODSK -13 PK1 wp14 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/.$ +E/-W Northing Easting DLS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) 6,176.26 11,400.0 88.84 322.77 6,226.5 6,170.3 7,402.6 1,084.7 6,038,473.42 470,960.44 3.00 7,086.98 11,405.5 89.00 322.77 6,226.6 6,170.4 7,406.9 1,081.4 6,038,477.80 470,957.14 3.00 7,091.88 11,500.0 89.23 319.94 6,228.0 6,171.8 7,480.7 1,022.4 6,038,551.84 470,898.43 3.00 7,175.09 11,600.0 89.47 316.95 6,229.2 6,173.0 7,555.6 956.1 6,038,626.92 470,832.43 3.00 7,260.61 11,618.9 89.52 316.39 6,229.3 6,173.1 7,569.3 943.1 6,038,640.72 470,819.52 3.00 7,276.47 End Dir: 11618.9' MD, 6229.3' TVD 11,700.0 89.52 316.39 6,230.0 6,173.8 7,628.0 887.2 6,038,699.65 470,763.82 0.00 7,344.28 11,800.0 89.52 316.39 6,230.9 6,174.7 7,700.4 818.2 6,038,772.32 470,695.15 0.00 7,427.90 11,900.0 89.52 316.39 6,231.7 6,175.5 7,772.8 749.2 6,038,844.99 470,626.47 0.00 7,511.52 12,000.0 89.52 316.39 6,232.6 6,176.4 7,845.2 680.2 6,038,917.66 470,557.80 0.00 7,595.14 12,100.0 89.52 316.39 6,233.4 6,177.2 7,917.6 611.3 6,038,990.34 470,489.12 0.00 7,678.76 12,200.0 89.52 316.39 6,234.2 6,178.0 7,990.0 542.3 6,039,063.01 470,420.45 0.00 7,762.37 12,300.0 89.52 316.39 6,235.1 6,178.9 8,062.4 473.3 6,039,135.68 470,351.77 0.00 7,845.99 12,367.7 89.52 316.39 6,235.7 6,179.5 8,111.4 426.6 6,039,184.87 470,305.28 0.00 7,902.60 Start Dir 3° 1100': 12367.7' MD, 6235.7'TVD 12,400.0 89.47 317.35 6,235.9 6,179.7 8,135.0 404.5 6,039,208.53 470,283.29 3.00 7,929.76 12,500.0 89.33 320.35 6,237.0 6,180.8 8,210.3 338.7 6,039,284.08 470,217.82 3.00 8,015.65 12,600.0 89.20 323.35 6,238.3 6,182.1 8,288.9 277.0 6,039,362.95 470,156.39 3.00 8,104.10 12,662.7 89.11 325.23 6,239.2 6,183.0 8,339.8 240.4 6,039,414.00 470,120.00 3.00 8,160.75 PK1 v14 T2 12,674.7 89.12 325.59 6,239.4 6,183.2 8,349.7 233.6 6,039,423.90 470,113.23 3.00 8,171.69 End Dir: 12674.7' MD, 6239.4' TVD 12,700.0 89.12 325.59 6,239.8 6,183.6 8,370.6 219.3 6,039,444.82 470,099.02 0.00 8,194.79 12,800.0 89.12 325.59 6,241.3 6,185.1 8,453.1 162.8 6,039,527.53 470,042.86 0.00 8,286.09 12,900.0 89.12 325.59 6,242.9 6,186.7 8,535.5 106.3 6,039,610.24 469,986.69 0.00 8,377.40 13,000.0 89.12 325.59 6,244.4 6,188.2 8,618.0 49.8 6,039,692.95 469,930.52 0.00 8,468.70 13,100.0 89.12 325.59 6,245.9 6,189.7 8,700.5 -6.7 6,039,775.66 469,874.36 0.00 8,560.01 13,200.0 89.12 325.59 6,247.5 6,191.3 8,783.0 -63.2 6,039,858.38 469,818.19 0.00 8,651.31 13,300.0 89.12 325.59 6,249.0 6,192.8 8,865.5 -119.8 6,039,941.09 469,762.03 0.00 8,742.61 13,400.0 89.12 325.59 6,250.6 6,194.4 8,948.0 -176.3 6,040,023.80 469,705.86 0.00 8,833.92 13,500.0 89.12 325.59 6,252.1 6,195.9 9,030.5 -232.8 6,040,106.51 469,649.69 0.00 8,925.22 13,600.0 89.12 325.59 6,253.6 6,197.4 9,113.0 -289.3 6,040,189.22 469,593.53 0.00 9,016.53 13,657.2 89.12 325.59 6,254.5 6,198.3 9,160.2 -321.6 6,040,236.53 469,561.40 0.00 9,068.75 Start Dir 3 °1100': 13657.2' MD, 6254.5'TVD 13,700.0 89.10 324.31 6,255.2 6,199.0 9,195.2 -346.2 6,040,271.65 469,536.97 3.00 9,107.63 13,800.0 89.04 321.31 6,256.8 6,200.6 9,274.8 -406.6 6,040,351.53 469,476.86 3.00 9,196.84 13,823.7 89.03 320.59 6,257.2 6,201.0 9,293.2 -421.6 6,040,370.00 469,462.00 3.00 9,217.63 PK1 v14 T3 13,851.0 89.07 321.41 6,257.7 6,201.5 9,314.4 - 438.7 6,040,391.27 469,444.92 3.00 9,241.58 End Dir: 13851' MD, 6257.7' ND 13,900.0 89.07 321.41 6,258.4 6,202.2 9,352.7 -469.3 6,040,429.69 469,414.52 0.00 9,284.75 14,000.0 89.07 321.41 6,260.1 6,203.9 9,430.9 -531.6 6,040,508.09 469,352.48 0.00 9,372.84 14,100.0 89.07 321.41 6,261.7 6,205.5 9,509.1 -594.0 6,040,586.49 469,290.44 0.00 9,460.93 14,200.0 89.07 321.41 6,263.3 6,207.1 9,587.2 -656.4 6,040,664.89 469,228.40 0.00 9,549.02 14,300.0 89.07 321.41 6,264.9 6,208.7 9,665.4 -718.7 6,040,743.29 469,166.36 0.00 9,637.12 11/17/2010 4 :31 :00PM Page 5 COMPASS 2003.16 Build 428 • • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK - 13i - Slot ODS - 13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK - 13i Survey Calculation Method: Minimum Curvature Weilbore: KUP C lateral PK1 Design: ODSK -13 PK1 wp14 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss 4.N/-S .1.E./-W Northing Easting . DLS Vert Section {ft) (T) (7) {ft) ft (ft) (ft) (ftI (ft) 6,210.35 14,400.0 89.07 321.41 6,266.5 6,210.3 9,743.5 -781.1 6,040,821.69 469,104.32 0.00 9,725.21 14,500.0 89.07 321.41 6,268.2 6,212.0 9,821.7 -843.5 6,040,900.09 469,042.29 0.00 9,813.30 14,600.0 89.07 321.41 6,269.8 6,213.6 9,899.8 -905.8 6,040,978.49 468,980.25 0.00 9,901.39 14,700.0 89.07 321.41 6,271.4 6,215.2 9,978.0 -968.2 6,041,056.89 468,918.21 0.00 9,989.49 14,755.7 89.07 321.41 6,272.3 6,216.1 10,021.5 - 1,002.9 6,041,100.55 468,883.65 0.00 10,038.56 Start Dir 3°I100': 14755.7' MD, 6272.3'TVD 14,800.0 89.01 320.09 6,273.1 6,216.9 10,055.8 - 1,030.9 6,041,134.96 468,855.77 3.00 10,077.33 14,900.0 88.87 317.09 6,274.9 6,218.7 10,130.8 - 1,097.1 6,041,210.20 468,789.95 3.00 10,162.97 15,000.0 88.73 314.09 6,277.0 6,220.8 10,202.2 - 1,167.0 6,041,281.88 468,720.29 3.00 10,245.80 15,008.8 88.72 313.83 6,277.2 6,221.0 10,208.3 - 1,173.3 6,041,288.00 468,714.00 2.99 10,252.92 End Dir: 150080 MD, 6277.2' TVD - PK1 v14 T4 15,100.0 88.72 313.83 6,279.2 6,223.0 10,271.5 - 1,239.1 6,041,351.41 468,648.47 0.00 10,326.88 15,200.0 88.72 313.83 6,281.5 6,225.3 10,340.7 - 1,311.3 6,041,420.93 468,576.63 0.00 10,407.95 15,300.0 88.72 313.83 6,283.7 6,227.5 10,409.9 - 1,383.4 6,041,490.45 468,504.80 0.00 10,489.02 15,400.0 88.72 313.83 6,285.9 6,229.7 10,479.1 - 1,455.5 6,041,559.96 468,432.96 0.00 10,570.08 15,500.0 88.72 313.83 6,288.2 6,232.0 10,548.4 - 1,527.6 6,041,629.48 468,361.12 0.00 10,651.15 15,600.0 ____88_72 313.83 6,290.4 6,234.2 10,617.6 - 1,599.8 6,041,699.00 468,289.29 0.00 10,732.22 15,700.0 88.72 313.83 6,292.6 6,236.4 10,686.8 - 1,671.9 6,041,768.51 468,217.45 0.00 10,813.29 15,800.0 88.72 313.83 6,294.9 6,238.7 10,756.1 - 1,744.0 6,041,838.03 468,145.61 0.00 10,894.36 15,900.0 88.72 313.83 6,297.1 6,240.9 10,825.3 - 1,816.1 6,041,907.55 468,073.78 0.00 10,975.43 16,000.0 88.72 313.83 6,299.3 6,243.1 10,894.5 - 1,888.3 6,041,977.06 468,001.94 0.00 11,056.50 16,100.0 88.72 313.83 6,301.6 6,245.4 10,963.8 - 1,960.4 6,042,046.58 467,930.10 0.00 11,137.57 1 16,172.4 88.72 313.83 6,303.2 6,247.0 11,013.9 - 2,012.6 6,042,096.91 467,878.10 0.00 11,196.26 Total Depth: 16172.5' MD, 6303.2' TVD • 16,172.5 88.72 313.83 6,303.2 • 6,247.0 11,014.0 - 2,012.7 6,042,096.98 467,878.02 0.00 11,196.34 4 112" - PK1 v14 T5 11/17/2010 4 :31 :00PM Page 6 COMPASS 2003.16 Build 428 • • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK - 13i - Slot ODS - 13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site Oooguruk Drill Site North Reference: True Well: ODSK - 13i Survey Calculation Method: Minimum Curvature Weilbore: KUP C lateral PK1 Design: ODSK -13 PK1 wp14 Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +NI-S W Northing . Easting - Shape ( ?) ( ?) (ft) (ft) (ft) {ft) (ft) PK1 v14 T4 0.00 0.00 6,277.2 10,208.3 - 1,173.3 6,041,288.00 468,714.00 - plan hits target - Point PK1 v2 Heel 0.00 0.00 6,151.2 6,623.0 1,565.5 6,037,692.00 471,438.00 - plan misses by 64.5ft at 10476.3ft MD (6129.6 TVD, 6656.5 N, 1616.2 E) - Point PK1 v14 T2 0.00 0.00 6,239.2 8,339.8 240.4 6,039,414.00 470,120.00 - plan hits target - Point PK1 v3 mid 0.00 0.00 6,151.2 8,100.4 388.4 6,039,174.00 470,267.00 - plan misses by 91.7ft at 12385.0ft MD (6235.8 TVD, 8124.0 N, 414.7 E) - Point PK1 v14 T3 0.00 0.00 6,257.2 9,293.2 -421.6 6,040,370.00 469,462.00 - plan hits target - Point PK1 v14 T5 0.00 0.00 6,303.2 11,014.0 - 2,012.7 6,042,097.00 467,878.00 - plan hits target - Point PK1 v11 T1 0.00 0.00 6,191.2 6,974.4 1,410.1 6,038,044.00 471,284.00 - plan hits target - Point PK1 Toe 0.00 0.00 6,206.2 9,567.0 - 1,962.8 6,040,650.00 467,922.00 - plan misses by 1012.0ft at 15132.6ft MD (6280.0 TVD, 10294.1 N, - 1262.7 E) - Point PK1 v6 T5 0.00 0.00 6,304.2 10,938.7 - 2,076.4 6,042,022.00 467,814.00 - plan misses by 98.4ft at 16166.4ft MD (6303.1 TVD, 11009.7 N, - 2008.3 E) - Point PK1 v3 Lateral Toe 0.00 0.00 6,151.2 10,937.7 - 2,075.4 6,042,021.00 467,815.00 - plan misses by 180.9ft at 16161.6ft MD (6303.0 TVD, 11006.4 N, - 2004.8 E) - Point PK1 v6 T3 0.00 0.00 6,254.2 9,253.0 -484.9 6,040,330.00 469,398.50 - plan misses by 74.6ft at 13832.2ft MD (6257.3 TVD, 9299.8 N, -426.9 E) - Point PK1 Heel 0.00 0.00 6,206.2 6,728.2 877.0 6,037,800.00 470,750.00 - plan misses by 573.4ft at 10988.3ft MD (6200.1 ND, 7075.5 N, 1333.3 E) - Point PK1 v6 T4 0.00 0.00 6,277.2 10,095.8 - 1,280.7 6,041,176.00 468,606.25 - plan misses by 155.4ft at 15008.0ft MD (6277.2 ND, 10207.7 N, - 1172.8 E) - Point PK1 v3 Heel 0.00 0.00 6,151.2 7,566.3 1,106.6 6,038,637.00 470,983.00 - plan misses by 142.2ft at 11507.3ft MD (6228.1 TVD, 7486.3 N, 1017.7 E) - Point PK1 v6 T2 0.00 0.00 6,237.2 8,410.1 310.9 6,039,484.00 470,190.75 - plan misses by 97.9ft at 12680.8ft MD (6239.5 ND, 8354.8 N, 230.1 E) - Point PK1 v2 Lateral Toe 0.00 0.00 6,151.2 10,706.7 - 1,834.4 6,041,789.00 468,055.00 - plan misses by 174.6ft at 15827.8ft MD (6295.5 ND, 10775.3 N, - 1764.1 E) - Point PK1 v9 T1 0.00 0.00 6,214.2 7,100.6 1,457.5 6,038,170.00 471,332.00 - plan misses by 115.6ft at 10934.3ft MD (6196.3 ND, 7032.5 N, 1365.9 E) 11/17/2010 4:31:00PM Page 7 COMPASS 2003.16 Build 428 • 0 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK -13i - Slot ODS -13 Company: • Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -13i Survey Calculation Method: Minimum Curvature Weilbore: KUP C lateral PK1 Design: ODSK -13 PK1 wp14 - Point PK1 v6 T1 0.00 0.00 6,226.2 7,567.3 1,106.6 6,038,638.00 470,983.00 - plan misses by 120.2ft at 11508.9ft MD (6228.1 TVD, 7487.5 N, 1016.7 E) - Point PK1 v14 T1 0.00 0.00 6,205.0 7,053.8 1,349.7 6,038,123.62 471,223.97 - plan misses by 6.8ft at 10961.5ft MD (6198.2 TVD, 7054.2 N, 1349.4 E) - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter: Diameter (ft) (ft) Name (in) (in) 3,512.0 2,948.8 11 3/4" 11.750 14.500 9,294.6 5,601.0 9 5/8" 9.625 11.750 11,101.9 6,208.0 7" 7.000 8.500 16,172.5 6,303.2 4 1/2" 4.500 6.125 Formations Measured Vertical Vertical . Dip Depth Depth Depth SS Dip • Direction (ft) (ft) ft Name Lithology (7) (7) 9,285.9 5,596.2 Torok Shale 1 0.00 9,057.8 5,471.2 Base Torok Ss 0.00 11,233.8 6,217.2 Base Kup C (LCU) 0.00 8,505.3 5,172.2 Top Torok Ss 0.00 10,158.1 6,028.2 Base HRZ 0.00 6,833.3 4,386.2 Brook 2B 0.00 9,873.4 5,902.2 Top HRZ 0.00 11,061.8 6,205.2 Kup C 0.00 6,391.2 Nuiqsut 0.00 6,551.2 B Nechelik 0.00 6,340.2 BCU 0.00 4,222.1 3,270.2 Hue 2 Tuff 0.00 6,481.2 B Nuiqsut 0.00 10,617.4 6,160.2 Kalubik Mkr 0.00 6,491.2 Nechelik 0.00 11/17/2010 4 :31:00PM Page 8 COMPASS 2003.16 Build 42B 0 0 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSK -13i - Slot ODS -13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7 + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -13i Survey Calculation Method: Minimum Curvature Weilbore: KUP C lateral PK1 Design: ODSK -13 PM wp14 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NiS ;V-W , (ft) (ft) (ft) (ft) Comment 9,294.6 5,601.0 5,654.6 1,905.5 KOP: 4 °/100' 145 °RHTF 9294.6' MD, 5601' TVD 9,354.6 5,634.7 5,704.1 1,901.2 Start Dir 3 °/100': 9354.6' MD, 5634.7'TVD 9,709.7 5,823.3 6,000.4 1,852.4 End Dir: 9709.7' MD, 5823.3' TVD 9,916.1 5,922.8 6,175.6 1,808.0 Start Dir 3.5 °/100': 9916.1' MD, 5922.8'TVD 10,861.1 6,191.2 6,974.4 1,410.0 End Dir: 10861.1' MD, 6191.2' TVD 11,305.5 6,222.2 7,327.4 1,141.8 Start Dir 3 °/100': 11305.5' MD, 6222.2'TVD 11,618.9 6,229.3 7,569.3 943.1 End Dir: 11618.9' MD, 6229.3' TVD 12,367.7 6,235.7 8,111.4 426.6 Start Dir 3 °/100': 12367.7' MD, 6235.7'TVD 12,674.7 6,239.4 8,349.7 233.6 End Dir: 12674.7' MD, 6239.4' TVD 13,657.2 6,254.5 9,160.2 -321.6 Start Dir 3 °/100': 13657.2' MD, 6254.5'TVD 13,851.0 6,257.7 9,314.4 -438.7 End Dir: 13851' MD, 6257.7' TVD 14,755.7 6,272.3 10,021.5 - 1,002.9 Start Dir 3 °/100': 14755.7' MD, 6272.3'TVD 15,008.8 6,277.2 10,208.3 - 1,173.4 End Dir: 15008.8' MD, 6277.2' TVD 16,172.4 6,303.2 11,013.9 - 2,012.6 Total Depth: 16172.5' MD, 6303.2' TVD I 11/17/2010 4:31:00PM Page 9 COMPASS 2003.16 Build 42B Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -13i KUP C lateral PK1 50- 703 - 20607 -00 ODSK -13 PK1 wp14 • Sperry rilling Services Clearance Summary Anticollision Report 17 November, 2010 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - KUP C lateral PK1 - ODSK -13 PK1 wp14 • Well Coordinates: 6,031,076.06 N, 469,845.81 E (70° 29' 45.50" N, 150° 14' 47.65" W) Datum Height: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Scan Range: 9,294.6 to 16,172.5 ft. Measured Depth. Scan Radius is 1,813.0 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42B Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference r,. Scan Type: 25.00 HALLIBURTON Sperry Drilling Services SURVEY PROGRAM ANTI- COLLISION SETTINGS late: 2 10 11 17700:00:00 Validated: Yes Version: Interpolation Method: MD, interval: 25.0 Depth Range From: 9294.6 To 16172.5 Depth From Depth To Survey/Plan Tool Results Limited By: Centre Distance: 1813.0 100.0 532.0 ODSK - 13 Gyro (ODSK - 13i KupH) SR Gyro Reference: Plan: ODSK -13 PK1 wp14 (ODSK- 131/KUP C lateral PK1) 573.7 3512.0 ODSK - 13 MWD (ODSK - 131 KupH) MWD+IFR2 +MS+sag Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100 /1000 of reference 3512.0 9294.6 ODSK -13 PK1 PH wp06 (ODSK -13i KulNl9VD+IFR2 +MS+sag 9294.6 16172.5 ODSK -13 PK1 wp14 (KUP C lateral PK$IWD +IFR2 +MS+sag 0 30 33 30 0 111, From Color To MD r 330 30 0 250 30 60 250 500 7 500 750 750 1000 1000 • 1250 • 1250 1500 s • 300 60 3 ' l 4 . i .6 1500 1iO 270 ¢ ' 1 � s j 90 1750 - t 2500 2750 2750 3000 3000 4000 240 120 111 270 I f i ll ..;,,,,,,,,,. .. :., 4000 500 PO 5000 6000 �� 6000 -' 7000 7000 8000 2 10 150 8000 __ ___._ 9000 30 9000 10000 ■ 180 10000 11000 ` 1 11000 12000 ODSK - 13i KupH ,, 50 12000 13000 240 120 13000 ' 14000 Travelling Cylinder Azimuth (TFO+AZI) 1 ?) vs Centre to Centre Separation (20 ft/ I II 14000 ' ' °" 15000 15000 16000 75..... 16000 17000 • 17000 18000 210 0 150 18000 19000 • 19000 20000 100 20000 21000 ODSK - 13i KupH 180 21000 0 SECTION DETAILS Travelling Cylinder Azimuth (TFO+AZI) [ ?] vs Centre to Centre Separation [50 ft /in] Sec MD Inc ALI TVD 41-9 .E-IN Meg TFece VSec T°y °t 1 92946 5876 35419 5801.0 5854.6 19055 000 000 52200 2 93548 5480 35588 5634.7 5701.1 1901 2 4.00 14500 52694 3 9709 7 61 16 345 78 5823 3 6000.4 1852 4 3.00 -5619 55697 4 99181 61 18 345 78 5922 0 8175.7 1808.0 0.00 000 5750 0 5 0861 1 86 00 322 77 6191.2 6974.4 1410.1 350 45 60 6607 3 PK1 v11 T1 REFERENCE INFORMATION Well Planning - Pioneer - Oooguruk 6 14065 890 0 022 62266 7 1141.8 3W 000 7002 7098 8 1618 9 8952 316 39 6229 3 7569.3 943.1 3.00 -85 43 7276 5 Co-ordinate (N /E) Reference. Well ODSK •132 - Slot ODS -13, True North Calculation Method: Minimum Curvature 10 266627 8911 325 62092 83398 24 30 0 9207 6 PK1 v14 72 Vertical (TVD) Reference: 42.7' + 13.5' © 56.2ft (Nabors 19AC) 11 2674.7 89.12 32559 62394 83497 233 6 300 8899 8171 7 Section (VS) Reference: Slot - ODS- 13(0.ON, 0.6E) Error System: ISCWSA 12 36572 8912 32559 6254 5 91802 -321 6 0.00 0.00 9068.8 Measured Depth Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) can Method: Tray. Cylinder North 1 3 89 3 3254 5 , 82 2 92 - -421 6 300 -91.02 92176 PK1 v14 T3 Calculation Method: Minimum Curvature Error Surface: Elliptical Conic 15 47557 8907 321.41 62723100216 -10029 000 0 00 10038 6 16 50088 88.72 31383 62772 102083 -11733 3.00 -9272 102529 PK1 v14 74 Warning Method: Rules Based 17 8172.5 8872 31383 83032 110140 -20127 000 0.00 111984 PK1 v14 75 NAD 27 ASP Zone 4 : WELL DETAILS: ODSK -13i Ground Level: 13.5 +N / -S +E/ -W Northing Easting Latiftude Longitude Slot 0.0 0.0 6031076.06 469845.81 70° 29' 45.498 N 150° 14' 47.653 W ODS -13 Well Planning - Pioneer - Oooguruk HALLIBURT N Oooguruk Development Anticollision Report for ODSK -13i - ODSK -13 PK1 wp14 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - KUP C lateral PK1 - ODSK -13 PK1 wp14 Scan Range: 9,294:6 to 16,172.5 ft. Measured Depth. Scan Radius is 1,813.0 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft Oooguruk Drill Site ODSK -13i - ODSK -13i KupH - ODSK -13 PK1 PH wpOt ODSN -29i - ODSN -29i IN4 - ODSN -29i IN4 wp06 14,900.0 665.1 14,900.0 262.2 18,700.0 1.651 Clearance Factor Pass - Major Risk ODSN -30 - ODSN -30 PN5 - ODSN -30 PN5 wp05 10,185.0 731.5 10,185.0 563.0 12,850.0 4.340 Centre Distance Pass - Major Risk ODSN -30 - ODSN -30 PN5 - ODSN -30 PN5 wp05 15,513.6 940.0 15,513.6 464.3 18,142.7 1.976 Clearance Factor Pass - Major Risk Survey tool Droaram From To Survey /Plan Survey Tool (ft) (ft) 100.0 532.0 SR- Gyro -SS 573.7 3,512.0 MWD +IFR2 +MS +sag 3,512.0 9,294.6 MWD +IFR2 +MS +sag 9,294.6 16,172.5 ODSK -13 PK1 wp14 MWD +IFR2 +MS +sag Ellipse error terms are correlated across survey tool tie -on points. C • alculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 17 November, 2010 - 16:29 Page 2 of 4 COMPASS l 3D View ❑ ,K in faa :.. V le 0 * a •, RI + *. '' I lc et at1 $ C)DSDWI-- 14IODSDW1 -44 Disposal 500 I ! 3000 1 X500 6000 - -I ODSK -13i, KUP C lateral PK1, ODSK -13 PK1 wp14 VO I 1500 - - ODSDW1 -44 Disposal I I 1 - -I ODSK -131, ODSK -13i KupH, ODSK -13 PK1 PH wp06 VO I I I . I 9000 c Legend ❑ )(, $ODSDW 1 -44 Disposal Q (A ODSK -13i, KUP C lateral PK1, ODSK -13 PK1 wp14 VO / ,spa 44-ODSK -13i, ODSK -13i KupH, ODSK-13 PK1 PH wp06 VO • I Legend y � L I ° �-- .p • a _ I 1 As =built Conductor " • 19 yYt O 0 • rropot 1••• �'1 • i l)' O • .\• • ° 1 1 14 lido Y1 �,� o Location Map • GRAPHIC SCAM 41 • • • 30 IS 0 30 o '`N``Ti "�OFgt • a r i Corot) � `' • 4 • 4: i � a P '`' °' ,: •• ~ ~ s' f� / , • 0 • • �� '0 .• 1 ilip G. Davis • e ^ � . • 4 � � No, 41143 • ''C to , � ♦�r • • e • M4 0 0 t. O C ff • • bp 1 . ` 10 ", ,i)t .: '�' 1. , 0 IP Pioneer Natural Resouoee JOB NAME: Oooguruk Drill Site DRAWN BY: et. 'CHECKED BY: ma . LOCATION: Protracted Section 11 SCALE: .1%.343 Township 13 North , Range 7 East . 7 -12 -07 Umiak Meridian Notes: NANUQ JOB NO. SHEET Coordinates ore listed on shuts 3 and 4 DESCRIPTION: Alaska Nod 27. Zone 4 Conductor As —bulit Rion 05204 I of 4 • i • 1111 1 i 1 { Vistritt Soundly F I 1 ‘ • ! SE Corner of mowURUK SITE # Protracted Section 11 n e T t . 0 •'` i Co ordinates fl I1 N 6028111.04 �! ; E 410989.01 I ' o ; $ I PI-25 4V \ Ref. AK BLM . * . " \ \ I Harrison Bay Trac "A" -24 \y _ • • . 9 rawi :\\' s � �°b��, fi st # ' a n . x 1 1 � 3 1 s9' w. 1 i ., j p 4 . ro 1 1 ��1♦/ `- ` • �•II e ..�_— �►- Q • •rg e �eoad=5.9 ku8es � � �� ' ! ear Shore 1 i-M' + _ V a a a Sn4 N. a a 4 w � P1-23' c. X14 • F7-18 �1 �- " " - ' . Tundra 1 1 s ..w-!7 etrSP a f _ ♦ � " Rca� t o i Y r . • r ' a � ' s' � EN� • � - � B asis of Location ....tilli 04 iv ‘ ! Buc 1f DS -3H West Monument . . '` Coordinates ; , � , N 6001016.61 .STAKED PI INFORMATION ONLY ' , � �1 h � , a E 498081.23 If 11 1111 U i o 7J o ; • -� ' Ref. Lownsbury & Assoc. W D ::z 1 . - < Drawing No. r • ci , ----"+ • NSK 6.01 —d672 l • • 4 k* � r i re 4 ......• • so* Ih " ^ ° Z: r ', _ I • ilip G. Is ,, e as No. 4110-S •, f I : "c O •,,, 1 %..„..+� `���■•■ ! Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 East DATE: 7 -12 -07 Umiat Meridian NANUQ JOB NO. SHEET DESCRIPTION: Basis of Location • 05204 2 of 4 .. • - -- ,A(astca State Plane - — _ _ Sect= Line • et Well No, - Latitude (N) Longitude (W) - - Pad ilev, F$L 6 6,031, 151,32 469,920,45 70 29 46.24160 15014 45,46468 3035 1077 13,50 2 - ,03131,, 146,35 .. .- ._ 469,915.52 70 29 46.19252 15414 45, 60922 $030 1062 13.50 • 3 6,031,141,39 469,910.59 70 29 150 14 45,75375 3025 1087 13,50 6,031,136.46 469 905, 67 • 70 29 40.09485 15014 45,5970 3020 1092 18.50 5 6,031,131,45 469,900,74 ' 70 29 46.045_3$ 15014 46,04252 3015 1097 13,50 6 6,091,126,51 469,895.80 7Q 29 45,99660_ 15014 46,1$735_ 3010 1102 13 7 6,031,113,73 469,883.13 70 29 45,670$9 15014 45.55679 2997 1115 13,50 8 6,031,108,73 469,875,21 70 29 45,52102 15014 46,70303 2992 1120 13.50 9 6,031,103.75 469,873,26 - 7 - 0 - 29 477184 15014 46,84514 2987 1125 13.50 ?0 10 6,031,098,79 469,568,36 - 15011 __...- 29 45,722$6 4 49.99179 2982 130 _ ' ' 13,51 _ 469,863,39 70 29 45.6739$ _15014 47,13750 2977 -- - - - - -- _-_ -- .__$1 - ,08$,$7 - -_. 8 469,858,47 70 29 45.62490 15014 47,28174 2972 1140 13,50 MEM 5,031,076,06 469,845,81 ° 70 29 150 14 47,65288 2960 1152 , 13,50 6,061,071,09 469,840.87 70 29 45,44932 _ 150 14 47_,79770 2955 1157 19,90 -- _ 15 6,031,966.15 469,8$5.96 - 7 15014 47,94165 2950 1162 13,50 16 6,031,061.18 469,831,04 70 29 45 .35145 15014 48,08_588 2945 . 17 6,031,056,25 469,826,11 70 29 45,30277 15014 48,2_3042 2940 Mal 13,5Q 18 6,031,051,27 469,821,18 70 45,25359 15014 48.37495 2935 1177 13,50 19 6, 6 031,038,52 469,806,60 70 29 45,12768 15014 48,74668 2922 11: ` 13.50 _ ,50 - - 469,603,59 702 45.07811 15014 48.89061 2917 1194 13.50 20 . 21 6,031,02153 469,798,62 70 29 45,029Q3 150 2912 13,5 0 - 6,931,023,58 469,7916r 70 2 _ - 150_14 4 2907 _ _ _ 1204 • 13,50 23 6,031,41$,57 469,788,76 70 29 44,93067 15014 49,32537 2902 ' 1150 • 24 6,031,013.30 469,783,84 70 20 44 -86159 - 1 - 50 14 49.46560 269. 1214 13,5+ Zf OF q4 4i�8 *4 .0 .r'p— •. iv *• " . C ST. ~: � \ 1c' •- • '.••_ �f 1l Philip G. Davis : c j — � ti No. 4110.5 . ..4 11 0 1, i L IttzoFfsstextm.t- 4. Notes: 1, Elevations ore based on BP Mean Sea Level, 2. Coordinates are based on Alaska State Plane Nod 27, Zone 4, 3, All conductors are within Protracted Section 11, Pioneer Natural Resouaes .'. JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: 8L CHECKED 9Y: MJD LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 East DATE: 7 -12 -Q7 Urniat Meridian __ NANUQ JOB NO SHEET DESCRIPTION: As -built Coordinates 05204 3 of 4 Alaska. State Plane Section Line Offset Well No. Y X Latitude (N) Longitude (W) FSL FEL Pad Elev. 25 6,031 469,943.64 70 29 46.01630 150 14 44.77930 3013 1055 13.50 26 6,031,123.35 469, 938.69 70 29 45.96722 150 14 44. C. 2442 3008 1060 13.50 27 6,031,118.33 469,933.76 70 29 45.91765 150 14 45.06895 300 1065 13.50 28 6,031,113.39 469,928.86 70 29 45.86887 150 14 45.21260 2997 1070 13.50 29. " 6,031,108.44 469,923.95 , 70 29 45.81999 150 14 45.35655 2992 1075 13.50 30 6,031,103.45 469,919.01 70 29 45.77071 150 14 45.50137 2988 1079 13.50 31 6,031,090.65 469,906.38 70 29 45.64431 150 14 45.87163 2975 1092 13.50 32 6, 031, 085.68 469, 901.39 70 29 45.59523 150 14 46.01793 2970 1097 13.50 33 6,031,080.67 469,896.50 70 29 45.54576 150 14 46.16128 2965 1102 13.50 34 6,031,075.73 469,891.57 70 29 45.49698 150 14 46.30581 2960 1106 13.50 35 6,031,070.76 469,886.60 70 29 45.44789 150 14 46.45152 2955 1111 13.50 36 6,031,065.83 469,881.69 70 29 45.39921 150 14 46.59547 2950 1116 13.50 37 6,031,053.00 469,869.00 70 29 45.27251 150 14 46.96749 2937 1129 13.50 38 6,031,047.99 469,864.14 70 29 45.22304. 150 14 47.10995 2932 1134 13.50 39 6, 031, 043.03 469, 859.20 70 29 45.17406 150 14 47.25478 2927 1139 13.50 40 6,031,038.10 469,854.21 70 29 45.12537 ' 15014 47.40108 2922 1144 • 13.50 41 6,031,033.05 469,849.29 ' 70 29 45.07551 15014 47.54530 2917 1149 13.50 42 6,031,028.13 469,844.38 70 29 45.02692 150 14 47.68925 2912 1154 13.50 43 6,031,015.46 469,831.70 70 29 44.90180 150 14 48.06099 2899 1166 13.50 44 6,031,010.49 469,826.79 70 29 44.85272 150 14 48.20493 2894 1171 13.50 45 6,031,005.53 469,821.86 70 29 44.80373 150 14 48.34946 2889 1176 13.50 46 6,031,000.54 469,816.94 70 29 44.75446 150 14 48.49369 2884 1181 13.50 47 6,030,995.50 , 469,811.98 70 29 44.70469 150 14 48.63910 2879 1186: 13.50 48 6,030,990.58 469,807.07 ' 70 29 44.65610 150 14 48.78304 2874 1191 13.50 OF A ' *> SURVEYOR'S CERTIFICATE j • •...�. I HEREBY CERTIFY THAT I AM • "/ 4. 4- • • ! 9 t PROPERLY REGISTERED AND / 1k 1 / 4 T A j LICENSED TO PRACTICE LAND • j ••° i • '•'° SURVEYING IN THE STATE OF • . • ALASKA AND THAT THIS PLAT f , REPRESENTS A SURVEY DONE BY • Ili :Davis . +� � • G �' ME OR UNDER MY SUPERVISION t ♦ ivo .41103 ° Q a s 7a 4 � .. co J �+ AND THAT I BELIEVE THAT ALL �� OF�SSlDNA1� DIMENSIONS AND OTHER DETAILS N .o.og.nrow ARE CORRECT AS SUBMITTED TO • ME BY NANUQ, INC. AS OF JULY - -� 12TH, 2007. Pioneer Natural Resouces JOB NAME:' Oooguruk Drill Site Conductors DRAWN BY: BL CHECKED "BY: MJD. ' LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 East DATE: 7 -12 -07 Umiot Meridian NANUQ JOB NO. SHEET DESCRIPTION: As -built Coordinates 05204 4 of 4 • TRANSMITTAL LETTER CHECKLIST WELL NAME C PTD# 1. Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: - 1 POOL: � . �'+ �' �'� ' � IL� , ,,1 Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both / well name ( C�� `�j K '� _, -S PH) and API number 1/ (50- 0 - (-47 U 7 - '7l`)) from records, data and logs acquired for well 7)3K- / SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/1H/2008 Field & Pool 000GURUK, KUPARUK OIL - 576100 �� — — Well Name: 000GURUK KUP ODSK -13 Program DEV Well bore seg ❑ PTD#: 2091460 Company PIONEER NATURAL RESOURCES ALASKA INC Initial Class /Type DEV / PEND_ GeoArea 973 Unit 11550 On /Off Shore On Annular Disposal ❑ Administration 1 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A -D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes Surf Loc & Top Prod Int in ADL0355036; TD in ADL0389958 3 Unique well name and number Yes Oooguruk- Kuparuk injector. 4 Well located in a defined pool Yes 000GURUK, KUPARUK OIL - 576100 governed by CO 596 5 Well located proper distance from drilling unit boundary Yes No restrictions in CO 596 other than >500' from external property line. 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 1 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes SFD 11/19/2010 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) NA 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs NA No Aquifers... 20 CMT vol adequate to circulate on conductor & surf csg Yes 121 CMT vol adequate to tie -in long string to surf csg No TOC planned for 500' above Kuparuk zone 22 CMT will cover all known productive horizons No Slotted liner planned. 123 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Close approach with ODSK -14 near surface. 27 If diverter required, does it meet regulations NA Diverter Waiver approved per AAC 15.035 (h) (2) Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure= 3443 psi (9.8 ppg EMW) .. Will drill with 7.2-10.5 ppg and MPD for hole Stability GLS 11/30/2010 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP =2700 psi Will test BOPs to 4500 psi IIV 31 Choke manifold complies w /API RP -53 (May 84) Yes 132 Work will occur without operation shutdown Yes Rig is moving back to finish this well. Surface hole drilled and cemented back in Jan. 2010. 133 Is presence of H2S gas probable No No H2S on Pad. Rig has alarms and sensors. 134 Mechanical condition of wells within AOR verified (For service well only) NA AOR complete.. Well now planned as a producer in Kuparuk zone. 35 Permit can be issued w/o hydrogen sulfide measures Yes None anticipated, but sensors will be employed and H2S mud scavengers will be on location. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is up to 9.8 ppg EMW; will be drilled using 7.2 to 10.5 ppg mud using Appr Date 1 37 Seismic analysis of shallow gas zones NA managed pressure drilling technique to maintain borehole stability with ECD's up to 12.5 ppg. Prod interval SFD 11/19/2010 38 Seabed condition survey (if off - shore) NA be drilled while maintaining an ECD of 9.8 to 10.2 ppg. SFD 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering�. Second re -issue forOooguruk- Kuparuk well. This reincarnation will be utilized as a producer. A pilot hole to the Nechelik will be Commissioner: Date: Commissioner: Date Co 4,4_,f2�er ' Dat � ' drilled, then plugged back prior to drilling a horizontal wellbore through the Kuparuk reservoir sandstone. Q STATE OF ALASKA ,- RECEIVED ALASKA IL AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS APR 0 9 2010 1. Operations Abandon LJ Repair Well Li Plug Perforations U Stimulate U 4411410181GasCas.Comassiorl Performed: Alter Casing ❑ Pull Tubing Perforate New Pool ❑ Waiver ❑ Time Extension 0 Anchor a Change Approved Program ❑ Operat. Shutdown In Perforate ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: ' .5. Permit to Drill Number: Name: Pioneer Natural Resources Alaska, Inc. Development ❑ Exploratory 209 -146 3. Address: 700 G Street, Suite 600 Stratigraphic❑ Service 0 . API Number: Anchorage, AK 99501 50- 703 - 20607 -00 -00 7. Property Designation (Lease Number): \ 8. Well Name and Number: ADL 355036 \ ODSK -13i 9. Field /Pool(s): Oooguruk Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 3525 feet Plugs (measured) N/A feet true vertical 2955 feet Junk (measured) N/A feet Effective Depth measured 3427' feet Packer (measured) N/A feet true vertical 2911' feet (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3475' 11 -3/4" 3513' 2949' 5830 3180 Intermediate Production Liner Perforation depth: Measured depth: N/A True Vertical depth: N/A Tubing (size, grade, measured and true vertical depth): 2 -7/8 ", 6.5# L -80 IBT -M 2005' MD 1928' TVD Packers and SSSV (type, measured and true vertical depth): 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: I Freeze protect w/ 225 Blois diesel to 2000' MD 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run X Exploratory Development Service 0 Daily Report of Well Operations X 15. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WAG ❑ GINJ ❑ WINJ El SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Alex Vaughan, 343 - 2189 Prepared By Kathy Campoamor, 343 - 2183 Printed Name Vey, Johnson �/ Title Drilling Superintendent Signature / 40 Phone 343 -2111 Date 4/8/2010 RBDMS APR 12 101) 5 7,4 ',tag() Form 10 -404 Revised 7/2009 „„ze a�✓ 7/(-) Submit Original Only PIONEER •perations Summary Report • NATURAL RESOURCES Well Name: ODSK -13i Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: DEVELOPMENT DRILL Start Date: 12/31/2009 End Date: - Depth Start Foot/Meters . Last Mud Start Date End Date (ttKS) (tt) Dens (tb/gaI) Summary 12/31/2009 1/1/2010 0.0 Move Rig from ODSK -42Ai to ODSK -13i. Rig accepted 12/31/09 © 00:00 hrs. 1/1/2010 1/2/2010 0.0 Move Pit/Pipeshed Complex from south side to north side of Wellbays. Installed MPD Pump' Skid. Spotted Pit/Pipeshed Complex next to Substructure. Lower and/or install all EXIT route stairs. RU rig for Drilling operations. NU Drilling Adapter, Surface Drilling Riser and Air Boot Adapter. C/O pump liners f/ 5 -1/2" t/ 6°- C/O Top Drive Upper and Lower IBOP's 1/ 4" 1/ 5 ". 1/2/2010 1/3/2010 158.0 65.00 9.10 CIO Top Drive 4" IBOP and stabbing guide to 5 ". PU 105 jts 5" DP, 14 jts 5" HWDP, Drilling Jars and stand back in derrick. PU 14 -1/2" Conductor Clean -Out BHA, 14 -1/2" Security XT1C Bit (1x12 and 3x16 jets) - SperryDrill Motor (1.5 deg bend) - Float Sub - Stablizer - UBHO - XO = 48.8'. Clean out 16" Conductor f/55' 11158'. Drill f/158' t/233'. CBU. POOH t/43'. PU BHA #1, Security XT1 C Bit - Drill Motor (1.5 deg bend) - NM Float Sub - Integral Blade Stabilizer - EM Pony HOC - EM HOC - EM Indexing Sub - EM Antenna Sub - NM XO - NM UBHO Sub - 3 x NM Flex DC's. 1/3/2010 1/4/2010 223.0 1,218.00 9.25 RU Gryo surrey sheaves in derrick and hang wireline. RU MGT on ODSN -35. R1141/144' t/223'. Drill 1/223' 1/1,441', (RD Gryo at 918'). 1/4/2010 1/5/2010 1,441.0 1,284.00 9.20 Drill f/1,441' 112,235'. Circulate and reciprocate DP while repairs being made on cuttings Hammer Mill (stood back 1 std DP every 1/2 hr 111,965'). Decision was made to perform wiper trip while repairing Hammer Mill. POOH f/1,965' t/632'. Switched from Rig Power to Hi -line Power. RIH f/632' 112,156'. Ream down f/2,156' t/2,235'. Drill f/2,235' 1/2,725'. 1/512010 1/6/2010 2,725.0 800.00 9.30 Drill 1/2,725' t13,525'. Circulate 50 bbls HI -Vis weighted sweep S/S and condition mud for wiper trip, (stood back 3 stands DP during circulation). POOH 1/3,201' 1/207', worked tight areas at 1,659`, and 1,520'. RIH 1/207' 1/2,250'. 1/6/2010 1/7/2010 3,525.0 0.00 9.60 RIH f/2,250' 1/3,525'. Circulate and condition mud for 11 -3/4" casing. POOH w/ BHA #1 and LD same. Remove VG Spacer Spool and install VG Landing Ring. RU casing handling equipment. RIH w/ 85 jts 11 -3/4" 60# L -80 Hydril 521 Casing 1/3,470'. 1/7/2010 1/8/2010 3,525.0 0.00 9.40 MU 11 -3/4° Casing Hanger and Landing Jt. Land 11 -3/4" Casing at 3,512.6'. MU Cement Head. Circulate and condition mud for cement operations. PJSM - Release 1st Bottom Cement Plug. Pump 10 bbts seawater. Test cement lines to 4000 psi. Pump 60 bbls 10.0 ppg Dual Spacer. Released 2nd Bottom Plug, Pump 371 bbls 10.9 ppq (502 sx 0 4.15 CuFt/Sk) Lead Permafrost "V 0 5 bpm /600 psi followed by 55.2 bbls 16,9 ppq (260.5 sx • , 1.19 CuFt/Sk) Premium Cement w/ 2% Calcium Chloride and 2% CFR -3 0 5 bpm /675 psi. Pump 1 bbl seawater, I)mp Top Cement Plug, pump 20 bbls seawater. Swtiched to rig and displaced Cement w/ 368.5 bbls seawater at 10 bpm w/ ICP 011850 psi, FCP 2600 psi, bump plug w/ 3500 psi, held pressure 30 min. CIP 0 1245 hrs. 100 bbls cement returns to surface. , Bled back 4 bbls seawater after pressure test, floats held. RD cementing and casing equipment. LD Ldg A. ND Drilling Riser. NU Multibowl Wellhead. Freeze protect w/ 225 bbls diesel to 2,000'. Rig released from ODSK -131 on 01/07/10 % 23:59 hrs. L Page 1/1 Report Printed: 4/8/2010 • • • ODSK -13i Batched Surface Casing — Well Status , Well Head: 11 -3/4 ", 5K, VetcoGray Tree: 3 -1/2 ", 5K, Horizontal RKB: 56' 16" Conductor 158' MDrkb / 158' TVDrkb 1 Freeze Protection Diesel 2000' MD / 1924' TVDrkb 2 -7/8" 6.5# L -80 IBT -M Tubing 2005' MD / 1928' TVDrkb Seawater IL 11 -3/4 ", 60# L -80 HYD 521, 10.772" ID 3513' MDrkb / 2949' TVDrkb TD of 14 - /z' Hole @ 3525' MDrkb / 2955' TVDrkb Date: Revision By: Comments P I 0 A r E E n 04/06/2010 klc Batched Surface Casing O R ODSK -13i Batched Surface Casing NATURAL RESOURCES ALASKA Schematic PIONEER Survey Report Well Name: ODSK -131 NATURAL RESOURCES Hint: Enter the date by the survey type for when this survey type started and that will control which surveys appear on the daily report. Wellbore Name Deviation Survey VS Dir ( °) Kick Ott Depth (ftKB) Kick Off Method Lat/Long Datum Latitude ( °) Longitude ( °) Original Hole ODSK -13i 322.92 300.0 Steerable Motor Deviation Surveys Date Description Declination ( °) Proposed? Definitive? 1/2/2010 ODSK -13i 21.70 No Yes MD Tie In (ftKB) Inclination Tie In ( °) Azimuth Tie In ( °) TVDTie In (ftKB) NSTie In (ft) EWTie In (ft) 0.00 0.00 0.00 0.00 0.00 0.00 Survey Data Date MD (ftKB) Ind ( °) Az#n (°) TVD (ftKB) VS (ft) NS (ft) EW (ft) DLS MOM) ` Method 1/2/2010 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Tie -On Pt. 1/2/2010 42.70 0.00 0.00 42.70 0.00 0.00 0.00 0.00 Gyro SS 1/2/2010 100.00 0.34 221.19 100.00 -0.03 -0.13 -0.11 0.59 Gyro SS 1/2/2010 168.00 0.16 130.95 168.00 -0.17 -0.34 -0.17 0.55 Gyro SS 1/3/2010 259.00 0.70 164.84 259.00 -0.81 -0.96 0.07 0.63 Gyro SS 1/3/2010 350.00 0.37 253.30 349.99 -1.22 -1.58 -0.07 0.86 Gryo SS 1/3/2010 441.00 1.19 307.31 440.99 -0.21 -1.09 -1.10 1.12 GryoSS 1/3/2010 532.00 1.95 322.83 531.95 2.25 0.71 -2.79 0.95 Gryo SS 1/3/2010 573.71 1.85 317.80 573.64 3.63 1.78 -3.67 0.47 MWD 1/3/2010 626.58 3.17 315.66 626.46 5.93 3.45 -5.26 2.50 MWD 1/3/2010 671.26 4.30 316.56 671.04 8.82 5.55 -7.28 2.53 MWD 1/3/2010 763.81 6.86 316.45 763.14 17.76 12.08 -13.47 2.77 MWD 1/3/2010 813.54 8.01 316.35 812.46 24.15 16.74 -17.91 2.31 MWD 1/3/2010 860.24 8.60 315.98 858.67 30.85 21.61 -22.58 1.27 MWD 1/3/2010 909.76 9.51 313.90 907.57 38.57 27.10 -28.11 1.95 MWD 1/3/2010 956.78 9.35 312.67 953.95 46.16 32.39 -33.71 0.55 MWD 1/3/2010 1,005.95 9.18 310.28 1,002.48 53.92 37.63 -39.64 0.86 MWD 1/3/2010 1,049.84 11.17 311.64 1,045.68 61.51 42.72 -45.49 4.57 MWD 1/3/2010 1,096.33 13.93 309.80 1,091.05 71.38 49.29 -53.16 6.00 1/3/2010 1,145.56 15.24 312.60 1,138.70 83.51 57.47 -62.47 3.02 MWD 1/3/2010 1,194.22 15.31 310.88 1,185.64 96.09 66.00 -72.04 0.94 MWD 1/3/2010 1,240.56 16.78 310.92 1,230.17 108.61 74.39 -81.72 3.17 MWD 1/3/2010 1,289.96 18.95 309.46 1,277.19 123.39 84.16 -93.30 4.48 MWD 1/3/2010 1,336.79 20.72 308.92 1,321.24 138.83 94.19 - 105.62 3.80 MWD 1/3/2010 1,384.42 22.51 306.84 1,365.52 155.76 104.95 - 119.47 4.09 MWD 1/4/2010 1,430.42 23.07 305.99 1,407.93 172.85 115.53 - 133.81 1.41 MWD 1/4/2010 1,479.83 23.39 304.58 1,453.33 191.42 126.79 - 149.72 1.30 MWD 1/4/2010 1,525.32 23.94 305.15 1,494.99 208.78 137.22 - 164.70 1.31 MWD 1/4/2010 1,576.16 24.01 305.92 1,541.45 228.49 149.23 - 181.51 0.63 MWD 1/4/2010 1,621.34 24.33 306.96 1,582.67 246.23 160.22 - 196.39 1.18 MWD 1/4/2010 1,671.07 25.79 307.41 1,627.72 266.51 172.95 - 213.17 2.96 MWD 1/4/2010 1,705.60 25.58 308.15 1,658.83 280.95 182.12 - 225.00 1.11 MWD 1/4/2010 1,766.84 25.73 308.07 1,714.04 306.59 198.48 - 245.86 0.25 MWD 1/4/2010 1,811.68 25.57 310.02 1,754.46 325.43 210.71 - 260.93 1.92 MWD 1/4/2010 1,862.23 25.52 312.44 1,800.07 346.77 225.07 - 277.32 2.07 MWD 1/4/2010 1,907.09 25.51 313.53 1,840.55 365.80 238.25 - 291.46 1.05 MWD 1/4/2010 1,958.99 26.92 315.00 1,887.11 388.47 254.25 - 307.87 2.99 MWD 1/4/2010 2,001.97 27.61 317.05 1,925.32 408.01 268.42 - 321.54 2.71 MWD 1/4/2010 2,097.12 28.74 323.48 2,009.21 452.83 302.95 - 350.18 3.40 MWD 1/4/2010 2,192.69 29.36 331.16 2,092.79 499.01 341.96 - 375.16 3.95 MWD 1/4/2010 2,241.25 29.14 334.14 2,135.16 522.39 363.02 - 386.06 3.03 MWD 1/4/2010 2,287.81 29.36 334.80 2,175.78 544.68 383.55 - 395.87 0.84 MWD 1/4/2010 2,383.06 33.63 338.04 2,256.99 593.02 429.17 - 415.68 4.82 MWD 1/4/2010 2,477.86 36.61 342.39 2,334.53 645.03 480.48 - 434.06 4.10 MWD 1/5/2010 2,530.79 38.32 345.12 2,376.55 675.11 511.39 - 443.05 4.50 MWD 1/4/2010 2,572.80 40.97 347.17 2,408.89 699.73 537.41 - 449.46 7.03 MWD 1/5/2010 2,619.68 42.07 349.45 2,444.00 727.80 567.83 - 455.74 3.99 MWD 1/5/2010 2,668.18 44.23 350.62 2,479.38 757.32 600.50 - 461.48 4.75 MWD _ 1/5/2010 2,763.56 46.77 352.08 2,546.23 817.12 667.75 - 471.69 2.88 MWD 1/5/2010 2,857.18 49.32 354.88 2,608.82 877.04 736.91 - 479.56 3.52 MWD 1/5/2010 2,953.56 52.79 357.15 2,669.40 939.80 811.67 - 484.73 4.04 MWD 1/5/2010 3,048.04 54.50 358.46 2,725.40 1,002.21 887.70 - 487.63 2.13 MWD Page 1/2 Report Printed: 4/8/2010 PIONEER 0 Survey Report Well Name: ODSK -13i NATURAL RESOURCES Hint: Enter the date by the survey type for when this survey type started and that will control which surveys appear on the daily report. Survey Data Date ' MD (ftK6) Ind ( °) Azm (°) ND {ttK6} VS (ft) NS (ft) — ON (ft) DLS MOM) Method 1/5/2010 3,143.06 57.30 358.73 2,778.67 1,066.12 966.35 - 489.56 2.96 MWD 1/5/2010 3,239.01 61.30 359.87 2,827.65 1,132.52 1,048.83 - 490.55 4.29 MWD 1/5/2010 3,332.55 64.45 1.07 2,870.29 1,198.50 1,132.06 - 489.86 3.56 MWD 1/5/2010 3,429.23 64.20 1.45 2,912.18 1,266.85 1,219.18 - 487.94 0.44 MWD 1/5/2010 3,468.28 63.59 2.08 2,929.36 1,294.16 1,254.23 - 486.86 2.13 MWD II �I Page 2/2 Report Printed: 4/8/2010 E *„ • . ' � A SEAN PARNELL, GOVERNOR 1 [ LE [g_1' ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99051 Re: Oooguruk, Kuparuk Oil, ODSK -13i Sundry Number: 309 -431 Dear Mr. Johnson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4 :30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 4 / ' Daniel T. Seamount Chair `ft.. DATED this 21 day of December, 2009 Encl. 0ov -r '1G + Vf't ^� STATE OF ALASKA RECEIVED �, t5 ` ALAS OIL AND GAS CONSERVATION COMMISSI ul` r 2 2 ?JIM APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Alaska 0 =11 & (iv Coos. COmmiSSiaf3 1. Type of Request: Abandon ❑ Suspend ❑ Operational shutdown ❑ Perforate ❑ Re -enter Suspend ill Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Other ❑ Specify: Change approved program El Pull Tubing ❑ Perforate New Pool ❑ Time Extension ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Development ❑ Exploratory ❑ 209 -146 • 3. Address: Stratigraphic ❑ Service 0 6. API Number: 700 G Street, Suite 600, Anchorage, AK 99051 50 703 - 20607 - 00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El • ODSK -13i • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 355036 Oooguruk - Kuparuk Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 158' • 158' 158' 158' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program IS BOP Sketch ❑ Exploratory ❑ Development ❑ Service IS • 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/30/2009 ` Oil ❑ Gas ❑ WDSPL ❑ Plugged ❑ 16. Verbal Approval: Date: WINJ (O • GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG P ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact James Franks, 343 - 2179 Printed Name Vern Johnson Title Sr. Staff Drilling Engineer Signatur 1 1/2 � ' Phone 343 -2111 Date 12/22/2009 Prepared By: Kathy Campoamor, 343 -2183 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .3679-431 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4 /1 Oriainc� f Tb 347 pw1,41 di+ - 41p . • Subsequent Form Required: `D, G -Z I 411''' W ,..a C-45 m l I G �� • � APPROVED BY Approved by: / COMMISSIONER THE C MMISSION Date: 1 2? 11 O RIGINAL 7 .. Form 10 -403 Revised 7/2009 Submit. i Duplicate /2 6 -r P r0 N E E NATURAL RESOURCES December 22, 2009 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Change to Approved Program ODSK -13i, PTD 209 -146 Surface Location: 2960' FSL, 1152' FEL, Sec 11, T13N, R7E, UM X = 469,845.81, Y = 6,031,076.06, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a change to approved program for ODSK -13i. Analysis performed after the original permit application has indicated increased drilling risk due to poor hole stability. To mitigate potential drilling problems while drilling intermediate hole, PNRA plans to increase the surface bole size from 13 -1/2" to 14 -1/2 ", • • and increase the surface casing size from 10 -3/4" to 11 -3/4 ". This will allow for improved flexibility and potentially larger intermediate hole. Surface hole /casing size and cement volumes are the only changes to the existing program • proposed in this application. Well targets, depths and directional plan remain unchanged. . The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Report of Sundry Well Operations Vern Johnson, Senior Staff Drilling Engineer 20 AAC 25.070(3) 907.343.2111 vern.iohnsona,pxd.com If you have any questions or require further information, please contact Vern Johnson at 907.343.2111. Si erely, Vern Johnson Senior Staff Drilling Engineer Attachments: Form 10 -403, Plan summary cc: ODSK -13i Well File • • ODSK -13i Permit to Drill Well Plan Summary Oooguruk - Kuparuk Pre - produced Injection Well Surface TD @ 3636' MD / 3000' TVD Production TD @ 9694' MD / 6516' TVD Surface Location: 2960' FSL, 1152' FEL, Sec 11, T13N, R7E, UM ASP 4 (NAD27) projection X = 469845.81 I Y = 6031076.06 Target: Oooguruk - Kuparuk 2254' FSL, 4470' FEL Sec 2, T13N, R7E, Umiat X = 466543 I Y = 6035664 I 5990' TVDrkb Bottom Hole Location: 2599' FSL, 4867' FEL Sec 2, T13N, R7E, Umiat X = 466147.59 Y = 6036010.38 6516' TVDrkb AFE Number: TBA Est. Start Date: December 30, 2010 I Rig: Nabors 19AC Operating days: 6.3 days D &C Surface, 18.5 days D &C Production TD: 9694' MD / 6516' TVDrkb Objectives: Kuparuk I Well Type (exp, dev, etc): Development Well Design (conventional, slimhole, etc): Injector — wp09 Current Mechanical Condition: Well Bay Footing / ODS Ground Level: Elevation above MSL: 13.5' RKB to Ground Level: 42.66' Rig Elevation: RKB + MSL = 56.16' Conductor: 157.66' MDrkb Well Control: 14 -1/2" Surface Hole Section: • • Maximum anticipated BHP: 935 psi @ 2078' TVDrkb (Based on seawater gradient of 0.4472 psi /ft) • Maximum surface pressure: 706 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) Maximum casing pressure: 4500 psi @ surface Planned BOP test pressure: 4500 psi (annular to 2500 psi) Due to required 4500 psi casing pressure test. Planned completion fluid: 10.2 ppg Brine /6.8 ppg Diesel Formation Integrity Testing Requirements: Test Point Depth Test Type Minimum EMW 11 -3/4" Surface Shoe Rathole + 20' to 50' from shoe LOT 12.5 ppg Pioneer Natural Resources Last Revised: December 21, 2009 ODSK -13i Change to Approved Program Page 1 of 3 • • Drilling Fluids Program: Surface Hole Mud Properties: 14 -1/2" hole Spud Mud Interval Density (ppg) Viscosity (secs) YP PV 10 sec gel API FL Initial 8.8 150 -200 35 - 50 15 -25 10 - 15 unrestricted Final 9.2 -9.6 70 -100 25-35 15-25 10-15 <12 Logging Program: 14 -1/2" Section: Drilling: Dir / GR Open Hole: N/A Cased Hole: N/A Casing Program: Hole Casing / Weight Grade Conn. Casing Csg/Tbg Top Hole Btm Size Tubing Length MDrkb MDrkb/TVDrkb 24" 16" 109# H -40 Welded 115' Surface 158' / 158' 14 -1/2" 11 -3/4" 60# L -80 Hydril 521 3,593' Surface 3,636' / 3,000' Casing Properties Size Weight Grade ID Drift Conn. Internal Collapse Tensile Strength ID Yield (psi) (psi) Joint Body 16" 109# H -40 14.67" 14.5" Welded Conductor casing 11 -3/4" 60# L -80 10.772" 10.62" Hydril 521 5830 13180 I 1384M I 1384M Cement Calculations: Casing Size: 111-3/4" Surface Casing - single stage Basis: Lead: 75% excess over gauge hole in permafrost + 50 bbls, 30% excess over gauge hole below permafrost Lead TOC: Surface Tail: 500' of open hole with 30% excess, plus 85' shoe track Tail TOC: 3136' MD 1 Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 10.0 ppg Dual Spacer Lead 395 bbls / 535 sx of 10.92 ppg Type "L" Permafrost Cement. 4.15 cf /sk, 20.0 gps water req. Tail 55 bbls / 260 sx of 15.9 ppg Premium "G" + adds. 1.19 cf /sk, 5.23 gps water req. Displ 400 bbls Mud Temp BHST -55° F, BHCT -60° F estimated Should hole conditions indicate that we will have trouble getting cement to surface, a TAM Port Collar may be run in the casing string and a staged cement job will be performed. In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Pioneer Natural Resources Last Revised: December 21, 2009 ODSK -13i Change to Approved Program Page 2 of 3 t This well and the pilot hole are outside the 1/2 mile radius around the disposal well at the intersection with the Torok disposal zone. Pioneer Natural Resources Well Plan Summary Drilling Operations Pre -Rig Work 1. 16" Conductors have been set and the Well Bay modules have been placed. Rig Activity: Drill Surface Hole and Set Surface Casing 1. MIRU Nabors 19AC over pre - installed 16" conductor casing. 2. Nipple up spacer spools and riser. 3. MU 14 -1/2" Directional Drilling, MWD /LWD assembly. Drill surface hole to the casing point, making wiper trips as necessary. Circulate and condition the hole to run casing. POOH. 4. Run and cement the 11 -3/4 ", 60# surface casing - displace the cement with seawater. Bump the plug and bring the pressure up to 3500 psi - chart and hold for 30 minute pressure test. Send chart to ODE. Note: A Port Collar may be run based on hole conditions at Company Rep discretion. 5. Ensure floats are holding. WOC if needed. 6. ND spacer spools and riser 7. NU Vetco multibowl wellhead 8. RIH with enough 3 -1/2" or 2 -7/8" tubing to allow freeze protection of the well to -2000' TVD. 9. Land the tubing and RILDS. 10. NU tree and test. 11. Circulate diesel freeze protection fluid to -2000' TVD. 12. RDMO to ODSK -14 to drill and complete that well Note: The plan is to drill and complete ODSK -14 prior to moving back onto ODSK -13i to finish drilling and completing the well. Pioneer Natural Resources Last Revised: December 21, 2009 ODSK -13i Change to Approved Program Page 3 of 3 o SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION CO11I11IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Mr. Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources 700 G Street Anchorage, Alaska 99501 Re: Oooguruk, Kuparuk Oil Pool, ODSK -13i Pioneer Natural Resources Permit No: 209 -146 (revised) Surface Location: 2960' FSL, 1152' FEL, Sec. 11, T13N, R7E, UM Bottomhole Location: 2599' FSL, 4867' FEL, Sec. 2, T13N, R7E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced service well. This permit supersedes and replaces Permit Number 209 -146 previously issued to you on November 23, 2009. 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). incerely, Daniel T. Seamount, Jr. Chair DATED this 2 Iday of December, 2009 cc: Department of Fish 86 Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. RECEIVED STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMI N DEL 1 ' ?OH PERMIT TO DRILL Mow) ji: sr: SE.3 C£S;ts,, Commission 20 AAC 25.005 1a. Type of Work: lb. Proposed Well Class: Development - Oil ❑ Service - Winj 111 . Single Zone 0 . 1c. Speciff {IVVPi posed for: Drill El . Redrill ❑ 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: Blanket El Single Well ❑ 11. Well Name and Number . Pioneer Natural Resources Alaska, Inc. Bond No. 103655283 - ODSK -13i 3. Address: 700 G Street, Suite 600 6. Proposed Depth: 12. Field /Pool(s): Anchorage, AK 99501 MD: 9694' ` TVD: 6516' 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): . Oooguruk - Kuparuk Oil Pool Surface: 2960' FSL, 1152' FEL, Sec. 11, T13N, R7E, UM .. ADL 355036 - Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2254' FSL, 4470' FEL, Sec. 2, T13N, R7E, UM 417497 1/2/2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2599' FSL, 4867' FEL, Sec. 2, T13N, R7E, UM 5760 2680' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: • 56.2 feet 15. Distance to Nearest Well Open Surface: x- 469845.81 • y- 6031076.06 • Zone- ASP 4 GL Elevation above MSL: 13.5 feet to Same Pool: ODSK -38 is 4581' 16. Deviated wells: Kickoff depth: 300 feet • 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 63.37 degrees Downhole: 3247 . Surface: 2546 • 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 109# H -40 Welded 115' Surface Surface 158' 158' Driven 13 -1/2" 10 -3/4" 45.5# L -80 BTC 3593' Surface Surface 3636. 3000' 488 sx PF'L; 237 sx Class 'G' . 9 -7/8" 7 -5/8" 29.7# L -80 BTC -M 9651' Surface Surface 9694 - 6516 317 sx Class 'G' • 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat El BOP Sketch ❑ Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact James Franks, 343 - 2179 Prepared By: Kathy Campoamor, 343 -2183 Printed Name Vern Johnson Title Sr. Staff Drilling Engineer ( x(1171 Signature --- Phone 343 -2111 Date 12/15/2009 Commission Use Only Permit to Drill ? // J` - API Number: , 7 Permit AppfO �/ ? See cover letter for other Number: L•� � 7b(- -- 50- 7b .--7 ~ �� t L !'" Date: // requirements. Conditions of approval : If box is checked well may not be used to explore for, test, or produce .lbed methane, s hydrates, or gas contained in shales: Other: ,ti L/5 xJ P s2- /3 DI te -1 Samples req'd: Yes ❑ No / Mud log req'd: Yes ❑ o [y� - 2 Sod d o s ' A A -' . t i �+- ". " \) H measures: Yes ❑ No [ Directional svy req'd: Yes 2' o ❑ -. 25. ,/ e AA tr 20 e- c 3S 01)(2) d ;�- - ev re uc.re r 3 w eo", t� a,DGI- ;ah 1 ". 4.G.COr -c+' c,,: AI 46 3,3 • �i� / Zi Z( 1 APPROVED BY THE COMMISSION DATE: COMMISSIONER ORIGIN Al. f. . Gam, Form 10 (Revised 7/2009) This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Submit in Duplicate Pioneer Natural Resources Well Plan Summary Drilling Operations Pre -Rig Work 1. 16" Conductors have been set and the Well Bay modules have been placed. Rig Activity: Drill Surface Hole and Set Surface Casing 1. MIRU Nabors 19AC over pre - installed 16" conductor casing. 2. Nipple up spacer spools and riser. 3. MU 13 -1/2" Directional Drilling, MWD /LWD assembly. Drill surface hole to the casing point, making wiper trips as necessary. Circulate and condition the hole to run casing. POOH. 4. Run and cement the 10 -3/4 ", 45.5# surface casing - displace the cement with seawater. Bump the plug and bring the pressure up to 3500 psi - chart and hold for 30 minute pressure test. Send chart to ODE. Note: A Port Collar may be run based on hole conditions at Company Rep discretion. 5. Ensure floats are holding. WOC if needed. 6. ND spacer spools and riser 7. NU Vetco multibowl wellhead 8. RIH with enough 3 -1/2" or 2 -7/8" tubing to allow freeze protection of the well to -2000' TVD. 9. Land the tubing and RILDS. 10. NU tree and test. 11. Circulate diesel freeze protection fluid to -2000' TVD. 12. RDMO to ODSK -14 to drill and complete that well Note: The plan is to drill and complete ODSK -14 prior to moving back onto ODSK -13i to finish drilling and completing the well. Rig Activity: Drill Production Hole, Set Production Casing and Complete 1. MIRU Nabors 19AC over ODSK -13i. RU circulation lines and circulate out the diesel freeze protection fluid and ensure the well is dead. 2. Install TWC. ND Tree and NU BOPE. Test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 3. Pull the TWC. 4. Pull the circulation string from the well. 5. LD 4" drillpipe (if necessary) and pick up 5" drillpipe. 6. MU 9 -7/8" directional drilling, MWD /LWD. RU MPD trip nipple. RIH and cleanout casing to landing collar. Displace well over to intermediate hole drilling fluid. 7. Drill through surface shoe + 20' of new hole and perform LOT to a minimum of 12.5 ppg. 8. RD the MPD trip nipple and RU the MPD bearing assembly. 9. Drill 9 -7/8" to TD getting LWD logs across the Kuparuk and Nuiqsut. 10. Circulate and condition the hole to run 7 -5/8" casing. Displace the well over to -12.5 ppg drilling fluid for shale stability reasons. 11. RD MPD bearing assembly and RU trip nipple. 12. POH standing back 5" DP. 13. Change one set of pipe rams to 7 -5/8" and test BOPE as required. 14. Run and cement the 7 -5/8 ", 29.7# intermediate casing. 15. Bump the plug and bring pressure up to 4500 psi - chart and hold pressure for 30 minutes for Pioneer Natural Resources Last Revised: December 15, 2009 ODSK -13i Permit To Drill Page 5 of 7 • • intermediate casing pressure test. Send the chart to the ODE. Release pressure and ensure floats are holding. 16. RU HES E -line. Run a cement bond log from PBTD to TOC. POH and RD HES E -line. 17. Change pipe rams to 3 -1/2" and Test BOPE to 250/4500 psi 18. RIH with 3 -1/2" injection completion with hang off perforating guns. 19. Land the tubing and RILDS. 20. Drop ball and rod, pressure up on the tubing to set packers. Increase pressure to perform pressure test of the tubing to 4500 psi. Pressure test 3 -1/2" to 7 -5/8" annulus to 4,500 psi. 21. Install TWC. 22. ND BOPE, NU tree and test to 5,000 psi. 23. Pull TWC. 24. Reverse circulate 4500' of freeze protection fluid down 3 -1/2" tubing annulus through gas lift mandrel shear out valve. 25. RDMO to next well. Post -Riq Activity: 26. RU Slickline / E -line Unit 27. Pull the ball and rod. 28. Pull the shear out valve from the upper GLM. 29. RIH and set dummy valve in upper GLM 30. Pull the RHC -m plug. 31. RD Slickline / E -line Unit. 32. Pressure up on the tubing to fire the pert guns and release guns from tubing string Post -Riq Activity Prior to Injection: 1. Perform MITIA, contact AOGCC slope representative 48 hrs prior to test for potential witness of test. Pioneer Natural Resources Last Revised: December 15, 2009 ODSK -13i Permit To Drill Page 6 of 7 • • ODSK -13i Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • Prior to drilling into the Kuparuk, hold a pre - reservoir meeting to outline heightened • awareness for kick detection and lost circulation. o Following the Kuparuk penetration, pick up off bottom, shut off the pumps and perform a flow check to verify there isn't any overpressure. Hydrates and Shallow gas • No hydrates are expected in this area. Lost Circulation /Breathing /Formation Stability /Stuck Pipe Events • Breathing may be seen while drilling the Hue shale. Minimizing swab and surge on the formation is critical to reducing the impact of breathing in the wellbore. Breathing was seen in the ODSN -40 well, but only after substantial time in trying to solve the lost circulation problems in the fault seen in and below the Torok Sands. • Lost Circulation was seen in drilling the ODSN -36 across this same interval. Review the DOB2C pill procedure prior to penetrating the Kuparuk. Follow the Lost Circulation Decision Tree and combat losses accordingly • During the attempt to retrieve a fish from the ODSK -33 well, an un- centralized BHA got stuck from differential sticking across the Torok due to the increase in mud weight needed to hold back the shales below. Differential sticking indications were not noted with the drilling BHA and drill pipe. In any event, keep the pipe moving and avoid allowing the pipe to remain stationary any longer than necessary to minimize the chances of differential sticking. • There is a small section of formation above the Top of the HRZ that is volcanic in nature (TUFFS) and can either have "glassy" material, swelling clays or both while drilling, which produced a pack off on ODSK -33 and ODSN -45 - close attention while drilling this interval is advised. Kick Tolerance /Integrity Testing Kick Tolerance / Integrity Testing Summary Table Casing set / Maximum Mud Weight Exp Pore Min LOT / FIT Interval Influx Volume Press Surface. 33.2 10.5 ppg 3229 12.5 ppg (LOT) ( -12.5 ppg via MPD)` NOTE: All LOT / FIT will be taken with a minimum of 20 -ft and a maximum of 50 -ft of new hole drilled outside of the previous casing string Hydrogen Sulfide • The Oooguruk Drill Site is not designated as an H site, however Standard Operating Procedures for H precautions should be followed at all times. Faults Production Hole: • Sub seismic faults with throws <25' may be encountered. Losses may be associated with these faults. Pioneer Natural Resources Last Revised: December 15, 2009 ODSK -13i Permit To Drill Page 7 of 7 • • ODSK -13i Kup H, Kuparuk Injection Well - Draft Well Head: 10 -3/4 ", 5K, VetcoGray Tree: 3 -1/2 ", 5K, Horizontal 16" Conductor 153' MDrkb / 153' TVDrkb 3 -1/2" ScSSSV, 2.813" ID @ 754' MDrkb / 754' TVDrkb 10 -3/4 ", 45.5# L -80 BTC, 9.95" ID 3636' MDrkb / 3000' TVDrkb 3 -1/2" MMG GLM @ 4300' MDrkb / 3330' TVDrkb 1 ' /2: Dummy Valve 3 -1/2 ", 9.3# L -80 TCII ► 3 -1/2" MMG GLM @ 8100' MDrkb / 5510' TVDrkb TOC @ 8446' MDrkb —t♦ 1 ' /z: Dummy Valve Down hole Pressure Gauge 8710' MDrkb 7 -5/8" Ultra Pak TH Permanent Packer X Nipple, 2.813" ID @ 8800' MDrkb / 5906' TVDrkb 8740' MDrkb X Nipple, 2.813" ID w /RHC -M Plug 8860' MDrkb XN Nipple, 2.725" ID Nogo 8920' MDrkb Perforations from 8946' MDrkb / 5990' TVDrkb Ported Pup 8930' MDrkb to 8990' MDrkb / 6015' TVDrkb .— 6 spf @ 60 degree phasing Auto release / WLEG 8940' MDrkb TCP Guns — dropped from tubing string PBTD @ 9609' MDrkb 7 -5/8 ", 29.7# L -80 BTC -M, 6.875" ID 9694' MDrkb / 6516' TVDrkb PIONEER Date: Revision By: Comments 12/15/2008 James Franks Proposed Completion ODSK -13i Injector NATURAL RESOURCES ALASKA Well Schematic Version 2.0 • ODSK -13i Permit to Drill Well Plan Summary Oooguruk - Kuparuk Pre - produced Injection Well Surface TD @ 3636' MD / 3000' TVD Production TD @ 9694' MD / 6516' TVD Surface Location: 2960' FSL, 1152' FEL, Sec 11, T13N, R7E, UM • ASP 4 (NAD27) projection X = 469845.81 Y = 6031076.06 - Target: Oooguruk - Kuparuk 2254' FSL, 4470' FEL Sec 2, T13N, R7E, Umiat X = 466543 Y = 6035664 1 5990' TVDrkb Bottom Hole Location: 2599' FSL, 4867' FEL Sec 2, T13N, R7E, Umiat • X = 466147.59 Y = 6036010.38 1 6516' TVDrkb AFE Number: TBA Est. Start Date: January 2, 2010 1 Rig: Nabors 19AC Operating days: 6.3 days D &C Surface, 18.5 days D &C Production TD: 9694' MD / 6516' TVDrkb Objectives: Kuparuk Well Type (exp, dev, etc): Development Well Design (conventional, slimhole, etc): Slim hole — Injector — wp09 Current Mechanical Condition: Well Bay Footing / ODS Ground Level: Elevation above MSL: 13.5' RKB to Ground Level: 42.66' Rig Elevation: RKB + MSL = 56.16' - Conductor: 157.66' MDrkb Well Control: 13 -1/2" Surface Hole Section: • Maximum anticipated BHP: 935 psi @ 2078' TVDrkb (Based on seawater gradient of 0.4472 psi /ft) • Maximum surface pressure: 706 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) 9 -7/8" Production Hole Section: • Maximum anticipated BHP: � 3247 psi @ 6368' TVDrkb (Based on 9.7 ppg Oooguruk- Nechelik pore pressure) • Maximum surface pressure: ' 2546 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) Maximum casing pressure: 4500 psi @ surface Planned BOP test pressure: 4500 psi (annular to 2500 psi) Due to required 4500 psi casing pressure test. Planned completion fluid: 10.2 ppg Brine /6.8 ppg Diesel Pioneer Natural Resources Last Revised: December 15, 2009 ODSK -13i Permit To Drill Page 1 of 7 • Diverter (see attached schematic) - Note: Requesting Diverter Exemption on a Well by Well Basis): Hydril 21 -1/4" 2M annular BOP 1 16" full opening knife gate valve, hydraulically actuated 16" diverter line 5000 psi BOP stack (see attached schematic): Hydril GK 11" 5M annular BOP Hydril 11" 5M single ram BOP w/ studded connections Hydril 11" 5M single ram BOP w/ studded connections Drilling cross 11" 5M x 11" 5M with 2 ea. 3 -1/8" 5M side outlets w /flanged connections 2 ea. 3 -1/8" 5M full opening inner manual gate valves mounted on drilling cross 2 ea. 3 -1/8" 5M full opening outer remote hydraulic controlled gate valves mounted on inner gate valves. Hydril 11" 5M single ram BOP w/ studded connections Formation Integrity Testing Requirements: Test Point Depth Test Type Minimum EMW 10 -3/4" Surface Shoe Rathole + 20' to 50' from shoe LOT 12.5 ppg Drilling Fluids Program: Surface Hole Mud Properties: 13 -1/2" hole Spud Mud Interval Density (ppg) Viscosity (secs) YP PV 10 sec gel API FL Initial 8.8 150 -200 35 - 50 15 -25 10 - 15 unrestricted Final 9.2 -9.6 70 -100 25-35 15-25 10-15 <12 Production Hole Mud Properties: 9 -7/8" hole LSND Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial to Base 9.2 -10.0 (-10.5 40 - 60 15 - 25 15 - 20 < 12 6 - 8 Torok ppg via MPD) From Base Torok 10.0 - 11.0 . 40 - 60 15 - 25 20 - 30 < 15 3 - 5 (8 -10 ° to TD (-12.5 ppg via HTHP) MPD) Logging Program: 13 -1/2" Section: Drilling: Dir / GR Open Hole: N/A Cased Hole: N/A 9 -7/8" Sections: Production Hole Drilling: Mud logging Dir /GR /Res /Dens /Neut /PWD Open Hole: N/A Cased Hole: Cement Bond Log Pioneer Natural Resources Last Revised: December 15, 2009 ODSK -13i Permit To Drill Page 2 of 7 0 0 Formation Markers: Formation Tops MD (ft) TVDrkb Pore Press. EMW Comments (ft) (psi) (ppg) Base of Permafrost 1711 1666 Top West Sak 2171 2078 935 8.65 Base of fluvial sands Tuffaceous Shales 2943 2658 Brook 2b 6177 4402 Top Torok Sands 7351 5075 2270 8.6 Wet Base Torok Sands 7752 5305 Top Hrz 8503 5736 Base Hrz 8701 5849 Kalubik Mkr 8857 5939 Kup C 8946 5990 3021 9.7 OiI ` Base Kup C (LCU) 8990 6015 BCU 9332 6235 Nuiqsut 9376 626 3161 9.7 Oil B Nuiqsut 9496 6357 Nechelik 9511 6368 B Nechelik 9599 6438 3247 9.7 OiI TD 9694 6516 Casing Program: Hole Casing / Weight Grade Conn. Casing Csg/Tbg Top Hole Btm Size Tubing Length MDrkb/TVDrkb MDrkb/TVDrkb 24" 16" 109# H -40 Welded 115' Surface 158' / 158' 13-1/2" 10-3/4" 45.5# L -80 BTC 3593' Surface 3636' / 3000' 9 -7/8" 7 -5/8" 29.7# L -80 BTC -M 9651' Surface 9694' / 6516' Tubing 3 -1/2" 9.3# L -80 TSHP /TCII 8903' Surface 8946' / 5990' Casing Properties Size Weight Grade ID Drift ID Conn. Internal Collapse Tensile Strength Yield (psi) (psi) Joint Body • 16" 109# H -40 14.67" 14.5" Welded Conductor casing 10 -3/4" 45.5# L -80 9.950" 9.794" BTC 5210 2470 1063M 1063M 7 -5/8" 29.7# L -80 6.875" 6.75 BTC -M 6890 4790 683 M 683 M Pioneer Natural Resources Last Revised: December 15, 2009 ODSK -13i Permit To Drill Page 3 of 7 • Cement Calculations: Casing Size: 1 10 -3/4" Surface Casing - single stage Basis: Lead: 75% excess over gauge hole in permafrost + 50 bbls, 30% excess over gauge hole below permafrost Lead TOC: Surface Tail: 500' of open hole with 30% excess, plus 85' shoe track Tail TOC: 3136 MD Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 10.0 ppg Dual Spacer Lead 361 bbls / 488 sx of 10.92 ppg Type "L" Permafrost Cement. 4.15 cf /sk, 20.0 gps water req. Tail 50.3 bbls / 237 sx of 15.9 ppg Premium "G" + adds. 1.19 cf /sk, 5.23 gps water req. Displ 337 bbls Seawater Temp BHST -55° F, BHCT -60° F estimated Should hole conditions indicate that we will have trouble getting cement to surface, a TAM Port Collar may be run in the casing string and a staged cement job will be performed. In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casing Size: 1 7 -5/8" Intermediate Casing - single stage Basis: Tail: 1248' of open hole with 30% excess, plus 85' shoe track TOC: >9.69 MD - 500' MD above the top of the Kuparuk Total Cement Volume: Preflush 10 bbl water Spacer 50 bbl 12.5 ppg Dual Spacer Tail 66 bbls / 317 sx Premium "G" + adds. 1.17 cf /sk, 5.05 gps Displ 439 bbls mud Temp BHST - 165° F at 6068' TVDrkb, -120° F BHCT This well and the pilot hole are outside the 1/2 mile radius around the disposal well at the intersection with the Torok disposal zone. Disposal: Annular Infection: Currently not requested, but may be requested in the future. Cuttings Handling: All Class 2 solids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1-44. Fluid Handling: All Class 1 and Class 2 fluids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDWI -44. Pioneer Natural Resources Last Revised: December 15, 2009 ODSK -13i Permit To Drill Page 4 of 7 • Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -13i - Slot ODS -13 ODSK -13i KupH Plan: ODSK -13i KupH wp09 Standard Proposal Report 15 December, 2009 HALLIBURT ©N Sperry Drilling Services • • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK - 13i - Slot ODS - 13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK - 13i Survey Calculation Method: Minimum Curvature Welibore: ODSK -13i KupH Design: ODSK -13i KupH wp09 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology ( ?) ( ?) 8,700.5 5,849.2 Base HRZ 0.00 2,943.2 2,658.2 Tuffaceous Shales 0.00 9,331.5 6,235.2 BCU 0.00 7,350.7 5,075.2 Top Torok 0.00 7,751.8 5,305.2 Base Torok 0.00 9,510.6 6,368.2 Top Nechelik 0.00 9,496.3 6,357.2 Base Nuiqsut 0.00 8,857.4 5,939.2 Kalubik Marker 0.00 8,946.3 5,990.2 Kup C 0.00 8,989.9 6,015.2 Base Kup C (LCU) 0.00 9,376.0 6,267.2 Top Nuiqsut 0.00 1,710.6 1,666.2 Base of Permafrost 0.00 8,503.4 5,736.2 Top HRZ 0.00 6,177.1 4,402.2 Book 2b 0.00 9,599.4 6,438.2 Base Nechelik 0.00 2,171.2 2,078.2 Top West Sak 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N /-S +E /-W (ft) (ft) (ft) (ft) Comment 300.0 300.0 0.0 0.0 Start Dir 1.00/100' 300.00' MD, 300.00' TVD 600.0 599.9 4.5 -6.4 Start Dir 2.00/100' 600.00' MD, 599.90' TVD 750.0 749.4 11.3 -16.1 Start Dir 3.00/100' 750.00' MD, 749.40' TVD 1,016.7 1,011.8 37.8 -54.0 Start Dir 1.50/100' 1016.70' MD, 1011.80' TVD 1,692.8 1,650.0 164.3 -234.7 End Dir 1692.80' MD, 1650.00' TVD 1,802.4 1,750.0 190.0 -271.4 Start Dir 3.49/100' 1802.40' MD, 1750.00' TVD 3,308.4 2,853.2 1,104.4 -517.1 End Dir 3308.40' MD, 2853.20' TVD 3,655.9 3,009.0 1,414.8 -506.0 Start Dir 3.0/100' 3655.90' MD, 3009.00' TVD 5,128.2 3,800.7 2,523.4 -960.5 End Dir 5128.20' MD, 3800.70' TVD 8,988.2 6,014.2 4,597.5 - 3,347.6 Start Dir 3.00/100' 8988.20' MD, 6014.20' TVD 9,694.4 6,515.8 4,919.8 - 3,718.6 Total Depth at 9694.40' MD, 6515.80' TVD 12/15/2009 1:35:07PM Page 7 COMPASS 2003.16 Build 42 1 [PIONEER W ELL DETAILS: ODSK -13i REFERENCE INFORMATION HA LLI t, 11`t� N Co- ordinate (N/E) Reference: Well ODSK -13i - Slot ODS -13, True North E. - -- - - - Ground Level: 13.5 Vertical O VD) Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) I, 1 . �' ( J .1 C { xN, `S l i ", :, i 1,,,, , € , , +N / - +E/ - W Northing Easting Latittude Longitude Slot Measured Depth Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) 0.0 0.0 6031076.06 469845.81 70° 29' 45.498 N 150°14'47.653 W ODS-13 Calculation Method: Minimum Curvature COMPANY DETAILS: Well Planning - Pioneer - Oooguruk WELLBORE TARGET DETAILS (MAP CO- ORDINATES) Project: Oooguruk Development Calculation Method: Minimum Curvature Site: Oooguruk Drill Site Name TVD +N / -S +E / -W Northing Easting Shape Error System: ISCWSA KupHi PB1 SCP 3000.0 1397.0 -506.7 6032474.92 469344.86 Point Scan Method: Tray. Cylinder North Well: ODSK -13i KupHi v7 T1 5990.2 4575.0 - 3321.7 6035664.00 466543.00 Circle (Radius: 200.0) Error Surface: Elliptical Conic Welibore: ODSK -13i KupH Warning Method: Rules Based I Plan: ODSK -13i KupH wpD9 - SECTION DETAILS _ ( CASING DETAILS Start Dir 1.00/100' 300.00' MD, 300.00' TVD Sec MD Inc Azi ND +N / -S +E / -W DLeg TFace VSec Target 1 42.7 0.00 0.00 42.7 0.0 0.0 0.00 0.00 0.0 0- - TVD MD Name Size - - "" 2 300.0 0.00 0.00 300.0 0.0 0.0 0.00 0.00 0.0 _ 3000.0 3635.9 10 3/4" 10.750 - - - - Start Dir 2.00/100' 600.00' MD, 599.90' TVD 3 600.0 3.00 305.00 599.9 4.5 -6.4 1.00 305.00 7.5 6515.8 9694.4 7 5/8" 7.625 - 4 750.0 6.00 305.00 749.4 11.3 -16.1 2.00 0.00 18.7 - _ - - - " " 5 1016.7 14.00 305.00 1011.8 37.8 -54.0 3.00 0.00 62.7 600 Start Dir 3.00/100' 750.00' MD, 749.40' TVD 6 1692.8 24.14 305.00 1650.0 164.3 -234.7 1.50 0.00 272.6 - _ _ _ - _ - 7 1802.4 24.14 305.00 1750.0 190.0 -271.4 0.00 0.00 315.3 - 8 3308.4 63.37 2.05 2853.2 1104.4 -517.1 3.49 70.86 1192.9 A5 Start Dir 1.50/100' 1016.70' MD, 1011.80' TVD 9 3635.9 63.37 2.05 3000.0 1397.0 -506.7 0.00 0.00 1419.9 KupHi PB1 SCP 10 3655.9 63.37 2.05 3009.0 1414.8 -506.0 0.00 0.00 1433.8 1200 - 11 5128.2 55.01 310.99 3800.7 2523.4 -960.5 3.00 - 113.85 2592.2 - End Dir 1692.80' MD, 1650 TVD 12 8946.3 55.01 310.99 5990.2 4575.0 - 3321.7 0.00 0.00 5652.6 KupHi v7 T1 _ _ _ 13 8988.2 55.01 310.99 6014.2 4597.5 - 3347.6 0.00 0.00 5686.2 _ Base of Permafrost - - - - - - - 14 9594.4 36.82 310.99 6434.2 4881.9 - 3675.0 3.00 180.00 6110.5 1800 50 01 Start Dir 3.49/100' 1802.40' MD, 1750.00' TVD 15 9694.4 33.82 310.99 6515.8 4919.8 - 3718.6 3.00 180.00 6167.0 End Dir 3308.40' MD, 2853.20' TVD FORMATION TOP DETAILS • 2400- - - -- 5 Top West Sak (0 6 TVDPath TVDssPath MDPath Formation - ° - Start Dir 3.0/100' 3655.90' MD, 3009.00' TVD 1666.2 1610.0 1710.6 ease of Permafrost 0 O , . - " - - - 2078.2 2022.0 2171.2 Top West Sak 2658.2 2602.0 2943.2 Tuffaceous Shales 3000 - DDI = 6.14 ` - 10 3/4" 4402.2 4346.0 6177.1 Book 2b - 5075.2 5019.0 7350.7 Top Torok / End Dir 5128.20' MD, 3800.70' TVD Q - 1 5305.2 5249.0 7751.8 Base Torok a) - Tuffaceous Shales / - 5736.2 5680.0 8503.4 Top HRZ O 3600 i " - - - 5849.2 5793.0 8700.5 Base HRZ ✓ _ KupHi PB1 SCP 5 5934.0 8946.3 KupCkMarker E - 6015.2 5959.0 8989.9 Base Kup C (LCU) - > 4200 6235.2 6179.0 9331.5 BCU 6267.2 6211.0 9376.0 Top Nuiqsut • - 6357.2 6301.0 9496.3 Base Nuiqsut II: - - 6368.2 6312.0 9510.6 T Nechelik Book 2b by 6438.2 6382.0 9599.4 Base Nechelik 4800 _ • Top Torok. - KupHi v7 T1 5400 - Base Torok I Start Dir 3.00/100' 8988.20' MD, 6014.20' TVD Top HRZ 6000- _ - - - - - - - " Total Depth at 9694.40' MD, 6515.80' TVD Base HRZ " - - Kalubik Marker i - -7 5/8" 6600- _ Kup C BCU ' , 1 - SURVEY PROGRAM . - ,- , ' ■ - Base Kup C (LCU) , Base Nechelik , 7200 Date: 2009 12 15T00:00:00 Validated: Yes Version: ODSK - 13i KupH wp09 - Top Nuiqsut Top Nechelik 1 Depth From Depth To Survey /Plan Tool _ 42.7 1500.0 ODSK -13i KupH wp09 SR- Gyro -SS B Niu sut 7800 1500.0 9694.4 ODSK -13i KupHwp09 MWD +IFR2 +MS +sag q - 11 1 1 1 1 1 1 1 1 I 1 1 1 I I 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 I I I 1 1 1 r 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 l 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 -3000 -2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 Vertical Section at 322.92? (1500 ft/in) • Halliburton Company HALL1BURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK - 13i - Slot ODS - 13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Weil: ODSK - 13i Survey Calculation Method: Minimum Curvature Wellbore: ODSK -13i KupH Design: ODSK -13i KupH wp09 Project Oooguruk Development 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 Oooguruk Drill Site Site Position: Northing: 6,031,151.32ft Latitude: 70° 29' 46.242 N From: Map Easting: 469,920.45ft Longitude: 150° 14' 45.465 W Position Uncertainty: 0.0 ft Slot Radius: in Grid Convergence: - 0.23 ? Well ODSK - 13i - Slot ODS - 13 Well Position +N / - S 0.0 ft Northing: 6,031,076.06 ft Latitude: 70° 29' 45.498 N +E / - 0.0 ft Easting: 469,845.81 ft Longitude: 150° 14' 47.653 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft Wellbore ODSK - 13i KupH Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) ( ?) (nT) IGRF200510 4/14/2009 22.31 80.81 57,730 Design ODSK -13i KupH wp09 Audit Notes: Version: Phase: PLAN Tie On Depth: 42.7 Vertical Section: Depth From (TVD) +NI-S +E/ -W Direction (ft) (ft) (ft) ( ?) 42.7 0.0 0.0 322.92 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/ -W Rate Rate Rate Tool Face (ft) ( ?) ( ?) (ft) ft (ft) (ft) ( ?l1ooft) ( ?llooft) ( ?/140ft) ( ?) 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 0.00 0.00 0.00 0.00 300.0 0.00 0.00 300.0 243.8 0.0 0.0 0.00 0.00 0.00 0.00 600.0 3.00 305.00 599.9 543.7 4.5 -6.4 1.00 1.00 0.00 305.00 750.0 6.00 305.00 749.4 693.2 11.3 -16.1 2.00 2.00 0.00 0.00 1,016.7 14.00 305.00 1,011.8 955.6 37.8 -54.0 3.00 3.00 0.00 0.00 1,692.8 24.14 305.00 1,650.0 1,593.8 164.3 -234.7 1.50 1.50 0.00 0.00 1,802.4 24.14 305.00 1,750.0 1,693.8 190.0 -271.4 0.00 0.00 0.00 0.00 3,308.4 63.37 2.05 2,853.2 2,797.0 1,104.4 -517.1 3.49 2.60 3.79 70.86 3,635.9 63.37 2.05 3,000.0 2,943.8 1,397.0 -506.7 0.00 0.00 0.00 0.00 3,655.9 63.37 2.05 3,009.0 2,952.8 1,414.8 -506.0 0.00 0.00 0.00 0.00 5,128.2 55.01 310.99 3,800.7 3,744.5 2,523.4 -960.5 3.00 -0.57 -3.47 - 113.85 8,946.3 55.01 310.99 5,990.2 5,934.0 4,575.0 - 3,321.7 0.00 0.00 0.00 0.00 8,988.2 55.01 310.99 6,014.2 5,958.0 4,597.5 - 3,347.6 0.00 0.00 0.00 0.00 9,594.4 36.82 310.99 6,434.2 6,378.0 4,881.9 - 3,675.0 3.00 -3.00 0.00 180.00 9,694.4 33.82 310.99 6,515.8 6,459.6 4,919.8 - 3,718.6 3.00 -3.00 0.00 180.00 12/15/2009 1:35:07PM Page 2 COMPASS 2003.16 Build 42 • • Halliburton Company HALLIBURTOr Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK - 13i - Slot ODS - 13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) Protect: Oooguruk Development MD Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK - 13i Survey Calculation Method: Minimum Curvature Welibore: ODSK -13i KupH Design: ODSK -13i KupH wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N(-S +E/-W Northing Easting DLS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) -13.50 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 6,031,076.06 469,845.81 0.00 0.00 100.0 0.00 0.00 100.0 43.8 0.0 0.0 6,031,076.06 469,845.81 0.00 0.00 200.0 0.00 0.00 200.0 143.8 0.0 0.0 6,031,076.06 469,845.81 0.00 0.00 300.0 0.00 0.00 300.0 243.8 0.0 0.0 6,031,076.06 469,845.81 0.00 0.00 Start Dir 1.00/100' 300.00' MD, 300.00' TVD 400.0 1.00 305.00 400.0 343.8 0.5 -0.7 6,031,076.56 469,845.10 1.00 0.83 500.0 2.00 305.00 500.0 443.8 2.0 -2.9 6,031,078.07 469,842.96 1.00 3.32 600.0 3.00 305.00 599.9 543.7 4.5 -6.4 6,031,080.59 469,839.40 1.00 7.47 Start Dir 2.00/100' 600.00' MD, 599.90' TVD 700.0 5.00 305.00 699.6 643.4 8.5 -12.1 6,031,084.61 469,833.70 2.00 14.11 750.0 6.00 305.00 749.4 693.2 11.3 -16.1 6,031,087.38 469,829.78 2.00 18.67 Start Dir 3.00/100' 750.00' MD, 749.40' TVD 800.0 7.50 305.00 799.0 742.8 14.6 -20.9 6,031,090.77 469,824.99 3.00 24.26 900.0 10.50 305.00 897.8 841.6 23.6 -33.7 6,031,099.79 469,812.21 3.00 39.14 1,000.0 13.50 305.00 995.6 939.4 35.5 -50.7 6,031,111.78 469,795.23 3.00 58.92 1,016.7 14.00 305.00 1,011.8 955.6 37.8 -54.0 6,031,114.07 469,791.99 3.00 62.69 Start Dir 1.50/100' 1016.70' MD, 1011.80' TVD 1,100.0 15.25 305.00 1,092.4 1,036.2 49.9 -71.2 6,031,126.20 469,774.81 1.50 82.71 1,200.0 16.75 305.00 1,188.5 1,132.3 65.7 -93.8 6,031,142.10 469, 752.30 1.50 108.94 1,300.0 18.25 305.00 1,283.9 1,227.7 82.9 -118.4 6,031,159.44 469,727.74 1.50 137.55 1,400.0 19.75 305.00 1,378.5 1,322.3 101.6 -145.1 6,031,178.22 469,701.15 1.50 168.53 1,500.0 21.25 305.00 1,472.1 1,415.9 121.7 -173.8 6,031,198.42 469,672.54 1.50 201.85 1,600.0 22.75 305.00 1,564.8 1,508.6 143.2 -204.5 6,031,220.03 469,641.95 1.50 237.49 1,692.8 24.14 305.00 1,650.0 1,593.8 164.3 -234.7 6,031,241.33 469,611.78 1.50 272.63 End Dir 1692.80' MD, 1650.00' TVD 1,700.0 24.14 305.00 1,656.5 1,600.3 166.0 -237.1 6,031,243.02 469,609.39 0.00 275.42 1,710.6 24.14 305.00 1,666.2 1,610.0 168.5 -240.7 6,031,245.52 469,605.85 0.00 279.54 Base of Permafrost 1,800.0 24.14 305.00 1,747.8 1,691.6 189.5 -270.6 6,031,266.62 469,575.98 0.00 314.34 1,802.4 24.14 305.00 1,750.0 1,693.8 190.0 -271.4 6,031,267.19 469,575.18 0.00 315.28 Start Dir 3.49/100' 1802.40' MD, 1750.00' TVD 1,900.0 25.45 312.50 1,838.6 1,782.4 215.7 -303.3 6,031,292.93 469,543.47 3.49 354.90 2,000.0 27.15 319.39 1,928.3 1,872.1 247.5 -334.0 6,031,324.90 469,512.90 3.49 398.82 2,100.0 29.14 325.47 2,016.5 1,960.3 284.9 -362.6 6,031,362.40 469,484.39 3.49 445.93 2,171.2 30.71 329.33 2,078.2 2,022.0 314.8 -381.7 6,031,392.41 469,465.40 3.49 481.34 Top West Sak 2,200.0 31.38 330.79 2,102.9 2,046.7 327.7 -389.1 6,031,405.30 469,458.05 3.49 496.06 2,300.0 33.81 335.45 2,187.1 2,130.9 375.7 -413.4 6,031,453.44 469,433.98 3.49 549.02 2,400.0 36.39 339.53 2,268.9 2,212.7 428.9 -435.3 6,031,506.63 469,412.26 3.49 604.62 2,500.0 39.09 343.14 2,348.0 2,291.8 486.8 -454.9 6,031,564.69 469,392.97 3.49 662.65 2,600.0 41.90 346.34 2,424.1 2,367.9 549.5 -471.9 6,031,627.39 469,376.19 3.49 722.89 2,700.0 44.78 349.21 2,496.8 2,440.6 616.5 -486.4 6,031,694.51 469,361.98 3.49 785.13 2,800.0 47.73 351.79 2,565.9 2,509.7 687.8 -498.3 6,031,765.79 469,350.39 3.49 849.12 2,900.0 50.73 354.15 2,631.2 2,575.0 762.9 -507.5 6,031,840.97 469,341.47 3.49 914.64 12/15/2009 1:35:07PM Page 3 COMPASS 2003.16 Build 42 • . Halliburton Company HALL1BURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK - 13i - Slot ODS - 13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Protect: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK - 13i Survey Calculation Method: Minimum Curvature Wellbore: ODSK -13i KupH Design: ODSK -13i KupH wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N /S +E/ -W Northing Easting DLS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) 2,602.00 2,943.2 52.04 355.10 2,658.2 2,602.0 796.6 - 510.7 6,031,874.59 469,338.44 3.49 943.37 Tuffaceous Shales 3,000.0 53.78 356.31 2,692.4 2,636.2 841.7 -514.0 6,031,919.77 469,335.24 3.49 981.44 3,100.0 56.86 358.30 2,749.3 2,693.1 923.8 -517.9 6,032,001.90 469,331.73 3.49 1,049.27 3,200.0 59.97 0.16 2,801.7 2,745.5 1,009.0 -519.0 6,032,087.05 469,330.96 3.49 1,117.88 3,300.0 63.10 1.91 2,849.4 2,793.2 1,096.9 -517.4 6,032,174.91 469,332.92 3.49 1,187.02 3,308.4 63.36 2.05 2,853.2 2,797.0 1,104.4 -517.1 6,032,182.41 469,333.21 3.49 1,192.84 End Dir 3308.40' MD, 2853.20' TVD 3,400.0 63.37 2.05 2,894.2 2,838.0 1,186.2 -514.2 6,032,264.21 469,336.47 0.00 1,256.36 3,500.0 63.37 2.05 2,939.1 2,882.9 1,275.5 -511.0 6,032,353.52 469,340.02 0.00 1,325.69 3,600.0 63.37 2.05 2,983.9 2,927.7 1,364.9 -507.8 6,032,442.83 469,343.58 0.00 1,395.03 3,635.9 63.37 2.05 3,000.0 2,943.8 1,397.0 -506.7 6,032,474.92 469,344.86 0.00 1,419.94 10 we - KupHi PBI SCP 3,655.9 63.37 2.05 3,009.0 2,952.8 1,414.8 - 506.0 6,032,492.76 469,345.57 0.00 1,433.79 Start Dir 3.01100' 3655.90' MD, 3009.00' TVD 3,700.0 62.84 0.69 3,028.9 2,972.7 1,454.1 -505.1 6,032,532.06 469,346.67 3.00 1,464.59 3,800.0 61.69 357.56 3,075.5 3,019.3 1,542.6 -506.4 6,032,620.54 469,345.69 3.00 1,535.98 3,900.0 60.61 354.36 3,123.7 3,067.5 1,630.0 -512.6 6,032,707.91 469,339.89 3.00 1,609.38 4,000.0 59.61 351.10 3,173.6 3,117.4 1,715.9 -523.5 6,032,793.94 469,329.28 3.00 1,684.59 4,100.0 58.70 347.77 3,224.8 3,168.6 1,800.3 -539.3 6,032,878.37 469,313.90 3.00 1,761.39 4,200.0 57.87 344.38 3,277.4 3,221.2 1,882.9 -559.7 6,032,961.00 469,293.78 3.00 1,839.58 4,300.0 57.14 340.93 3,331.1 3,274.9 1,963.4 -584.9 6,033,041.58 469,268.98 3.00 1,918.94 4,400.0 56.50 337.43 3,385.9 3,329.7 2,041.6 -614.6 6,033,119.91 469,239.58 3.00 1,999.26 4,500.0 55.96 333.88 3,441.5 3,385.3 2,117.3 -648.8 6,033,195.75 469,205.64 3.00 2,080.31 4,600.0 55.52 330.29 3,497.8 3,441.6 2,190.3 -687.5 6,033,268.91 469,167.26 3.00 2,161.88 4,700.0 55.19 326.66 3,554.7 3,498.5 2,260.4 -730.5 6,033,339.19 469,124.55 3.00 2,243.74 4,800.0 54.97 323.01 3,611.9 3,555.7 2,327.4 -777.7 6,033,406.39 469,077.63 3.00 2,325.66 4,900.0 54.85 319.35 3,669.4 3,613.2 2,391.2 -829.0 6,033,470.33 469,026.62 3.00 2,407.43 5,000.0 54.85 315.68 3,727.0 3,670.8 2,451.4 -884.2 6,033,530.83 468,971.66 3.00 2,488.81 5,100.0 54.96 312.02 3,784.5 3,728.3 2,508.1 -943.2 6,033,587.72 468,912.91 3.00 2,569.58 5,128.2 55.01 310.99 3,800.7 3,744.5 2,523.4 -960.5 6,033,603.10 468,895.67 3.00 2,592.22 End Dir 5128.20' MD, 3800.70' TVD 5,200.0 55.01 310.99 3,841.9 3,785.7 2,562.0 - 1,004.9 6,033,641.85 468,851.43 0.00 2,649.77 5,300.0 55.01 310.99 3,899.2 3,843.0 2,615.7 - 1,066.7 6,033,695.83 468,789.81 0.00 2,729.92 5,400.0 55.01 310.99 3,956.6 3,900.4 2,669.5 - 1,128.6 6,033,749.80 468,728.19 0.00 2,810.08 5,500.0 55.01 310.99 4,013.9 3,957.7 2,723.2 - 1,190.4 6,033,803.78 468,666.58 0.00 2,890.23 5,600.0 55.01 310.99 4,071.3 4,015.1 2,776.9 - 1,252.3 6,033,857.76 468,604.96 0.00 2,970.39 5,700.0 55.01 310.99 4,128.6 4,072.4 2,830.7 - 1,314.1 6,033,911.73 468,543.34 0.00 3,050.54 5,800.0 55.01 310.99 4,185.9 4,129.7 2,884.4 - 1,375.9 6,033,965.71 468,481.72 0.00 3,130.70 5,900.0 55.01 310.99 4,243.3 4,187.1 2,938.1 - 1,437.8 6,034,019.69 468,420.10 0.00 3,210.85 6,000.0 55.01 310.99 4,300.6 4,244.4 2,991.8 - 1,499.6 6,034,073.66 468,358.49 0.00 3,291.01 6,100.0 55.01 310.99 4,358.0 4,301.8 3,045.6 - 1,561.5 6,034,127.64 468,296.87 0.00 3,371.16 6,177.1 55.01 310.99 4,402.2 4,346.0 3,087.0 - 1,609.2 6,034,169.26 468,249.35 0.00 3,432.97 Book 2b 6,200.0 55.01 310.99 4,415.3 4,359.1 3,099.3 - 1,623.3 6,034,181.62 468,235.25 0.00 3,451.32 12/15/2009 1:35:07PM Page 4 COMPASS 2003.16 Build 42 Halliburton Company HQLL1BURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK - 13i - Slot ODS - 13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK - 13i Survey Calculation Method: Minimum Curvature Welibore: ODSK -13i KupH Design: ODSK -13i KupH wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N /$ +E/ -W Northing Easting DLS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) 4,416.47 6,300.0 55.01 310.99 4,472.7 4,416.5 3,153.0 - 1,685.2 6,034,235.59 468,173.63 0.00 3,531.47 6,400.0 55.01 310.99 4,530.0 4,473.8 3,206.8 - 1,747.0 6,034,289.57 468,112.01 0.00 3,611.63 6,500.0 55.01 310.99 4,587.4 4,531.2 3,260.5 - 1,808.8 6,034,343.55 468,050.39 0.00 3,691.78 6,600.0 55.01 310.99 4,644.7 4,588.5 3,314.2 - 1,870.7 6,034,397.52 467,988.78 0.00 3,771.93 6,700.0 55.01 310.99 4,702.0 4,645.8 3,368.0 - 1,932.5 6,034,451.50 467,927.16 0.00 3,852.09 6,800.0 55.01 310.99 4,759.4 4,703.2 3,421.7 - 1,994.4 6,034,505.48 467,865.54 0.00 3,932.24 6,900.0 55.01 310.99 4,816.7 4,760.5 3,475.4 - 2,056.2 6,034,559.45 467,803.92 0.00 4,012.40 7,000.0 55.01 310.99 4,874.1 4,817.9 3,529.2 - 2,118.1 6,034,613.43 467,742.30 0.00 4,092.55 7,100.0 55.01 310.99 4,931.4 4,875.2 3,582.9 - 2,179.9 6,034,667.40 467,680.69 0.00 4,172.71 7,200.0 55.01 310.99 4,988.8 4,932.6 3,636.6 - 2,241.7 6,034,721.38 467,619.07 0.00 4,252.86 7,300.0 55.01 310.99 5,046.1 4,989.9 3,690.4 - 2,303.6 6,034,775.36 467,557.45 0.00 4,333.02 7,350.7 55.01 310.99 5,075.2 5,019.0 3,717.6 - 2,335.0 6,034,802.74 467,526.19 0.00 4,373.68 Top Torok 7,400.0 55.01 310.99 5,103.5 5,047.3 3,744.1 - 2,365.4 6,034,829.33 467,495.83 0.00 4,413.17 7,500.0 55.01 310.99 5,160.8 5,104.6 3,797.8 - 2,427.3 6,034,883.31 467,434.21 0.00 4,493.33 7,600.0 55.01 310.99 5,218.1 5,161.9 3,851.6 - 2,489.1 6,034,937.29 467,372.60 0.00 4,573.48 7,700.0 55.01 310.99 5,275.5 5,219.3 3,905.3 - 2,551.0 6,034,991.26 467,310.98 0.00 4,653.64 7,751.8 55.01 310.99 5,305.2 5,249.0 3,933.1 - 2,583.0 6,035,019.23 467,279.05 0.00 4,695.17 Base Torok 7,800.0 55.01 310.99 5,332.8 5,276.6 3,959.0 - 2,612.8 6,035,045.24 467,249.36 0.00 4,733.79 7,900.0 55.01 310.99 5,390.2 5,334.0 4,012.7 - 2,674.6 6,035,099.22 467,187.74 0.00 4,813.95 8,000.0 55.01 310.99 5,447.5 5,391.3 4,066.5 - 2,736.5 6,035,153.19 467,126.12 0.00 4,894.10 8,100.0 55.01 310.99 5,504.9 5,448.7 4,120.2 - 2,798.3 6,035,207.17 467,064.50 0.00 4,974.25 8,200.0 55.01 310.99 5,562.2 5,506.0 4,173.9 - 2,860.2 6,035,261.15 467,002.89 0.00 5,054.41 8,300.0 55.01 310.99 5,619.6 5,563.4 4,227.7 - 2,922.0 6,035,315.12 466,941.27 0.00 5,134.56 8,400.0 55.01 310.99 5,676.9 5,620.7 4,281.4 - 2,983.9 6,035,369.10 466,879.65 0.00 5,214.72 8,500.0 55.01 310.99 5,734.2 5,678.0 4,335.1 - 3,045.7 6,035,423.08 466,818.03 0.00 5,294.87 8,503.4 55.01 310.99 5,736.2 5,680.0 4,337.0 - 3,047.8 6,035,424.92 466,815.93 0.00 5,297.61 Top HRZ 8,600.0 55.01 310.99 5,791.6 5,735.4 4,388.9 - 3,107.5 6,035,477.05 466,756.41 0.00 5,375.03 8,700.0 55.01 310.99 5,848.9 5,792.7 4,442.6 - 3,169.4 6,035,531.03 466,694.80 0.00 5,455.18 8,700.5 55.01 310.99 5,849.2 5,793.0 4,442.8 - 3,169.7 6,035,531.28 466,694.51 0.00 5,455.56 Base HRZ 8,800.0 55.01 310.99 5,906.3 5,850.1 4,496.3 - 3,231.2 6,035,585.01 466,633.18 0.00 5,535.34 8,857.4 55.01 310.99 5,939.2 5,883.0 4,527.2 - 3,266.7 6,035,616.00 466,597.80 0.00 5,581.36 Kalubik Marker 8,900.0 55.01 310.99 5,963.6 5,907.4 4,550.1 - 3,293.1 6,035,638.98 466,571.56 0.00 5,615.49 8,946.3 55.01 310.99 5,990.2 5,934.0 4,575.0 - 3,321.7 6,035,664.00 466,543.00 0.00 5,652.64 Kup C - KupHi v7 T1 8,988.2 55.01 310.99 6,014.2 5,958.0 4,597.5 - 3,347.6 6,035,686.59 466,517.21 0.00 5,686.19 Start Dir 3.00/100' 8988.20' MD, 6014.20' TVD 8,989.9 54.96 310.99 6,015.2 5,959.0 4,598.4 - 3,348.7 6,035,687.53 466,516.14 3.00 5,687.59 Base Kup C (LCU) 9,000.0 54.66 310.99 6,021.0 5,964.8 4,603.8 - 3,354.9 6,035,692.95 466,509.96 3.00 5,695.63 9,100.0 51.66 310.99 6,081.0 6,024.8 4,656.3 - 3,415.3 6,035,745.67 466,449.77 3.00 5,773.92 12/15/2009 1:35:07PM Page 5 COMPASS 2003.16 Build 42 • • • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK - 13i - Slot ODS - 13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK -13i Survey Calculation Method: Minimum Curvature Wel!bore: ODSK -13i KupH Design: ODSK -13i KupH wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/ -W Northing Easting DLS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) 6,088.82 9,200.0 48.66 310.99 6,145.0 6,088.8 4,706.6 - 3,473.2 6,035,796.25 466,392.03 3.00 5,849.03 9,300.0 45.66 310.99 6,213.0 6,156.8 4,754.7 - 3,528.6 6,035,844.55 466,336.89 3.00 5,920.75 9,331.5 44.71 310.99 6,235.2 6,179.0 4,769.3 - 3,545.4 6,035,859.26 466,320.10 3.00 5,942.60 BCU 9,376.0 43.38 310.99 6,267.2 6,211.0 4,789.6 - 3,568.8 6,035,879.65 466,296.82 3.00 5,972.88 Top Nuiqsut 9,400.0 42.66 310.99 6,284.7 6,228.5 4,800.4 - 3,581.2 6,035,890.44 466,284.50 3.00 5,988.90 9,496.3 39.77 310.99 6,357.2 6,301.0 4,842.0 - 3,629.1 6,035,932.24 466,236.78 3.00 6,050.98 Base Nuiqsut 9,500.0 39.66 310.99 6,360.0 6,303.8 4,843.5 - 3,630.8 6,035,933.79 466,235.01 3.00 6,053.28 9,510.6 39.34 310.99 6,368.2 6,312.0 4,847.9 - 3,635.9 6,035,938.23 466,229.95 3.00 6,059.87 Top Nechelik 9,594.4 36.82 310.99 6,434.2 6,378.0 4,881.9 - 3,675.0 6,035,972.30 466,191.05 3.00 6,110.47 9,599.4 36.67 310.99 6,438.2 6,382.0 4,883.8 - 3,677.2 6,035,974.27 466,188.81 3.00 6,113.39 Base Nechelik 9,600.0 36.66 310.99 6,438.7 6,382.5 4,884.0 - 3,677.5 6,035,974.49 466,188.55 3.00 6,113.72 9,694.4 33.82 310.99 6,515.8 ; 6,459.6 4,919.8 - 3,718.6 6,036,010.38 466,147.59 3.00 6,167.01 Total Depth at 9694.40' MD, 6515.80' TVD - 7 5/8" Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/ -W Northing Easting - Shape ( ?) ( ?) (ft) (ft) (ft) (ft) (ft) KupHi v7 T1 0.00 0.00 5,990.2 4,575.0 - 3,321.7 6,035,664.00 466,543.00 - plan hits target - Circle (radius 200.0) KupHi PB1 SCP 0.00 0.00 3,000.0 1,397.0 -506.7 6,032,474.92 469,344.86 - plan hits target - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 3,635.9 3,000.0 10 3/4" 10.750 13.500 9,694.4 6,515.8 7 5/8" 7.625 9.875 12/15/2009 1 :35 :07PM Page 6 COMPASS 2003.16 Build 42 PLO N E ER Project: Oooguruk Development imimmimironi Site. Oooguruk Drill Site — ■MI■■■■■ ■ ■ ■■ ■ ■ ■� ■1\� ■ ■■MEMENI 11E1�! 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' I■1�i111 I ■�■■ ■��M ■� ■■■■■ ■ill' =1� ■�■\\_MIIIII■MM ■IIII■ ■IIIIMI\■■ 1000 -9000 -8500 -8000 -7500 -7000 -6500 -6000 -5500 -5000 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 West( -) /East( +) (1000 ft/in) PIONEER HALLIBURTON WELL DETAILS: ODSK -13i REFERENCE INFORMATION Ground Level: 13.5 Co-ordinate (N/E) Reference: Well ODSK -13i - Slot ODS -13, True North +N / -S +E/ -W Northing Eastin Latittudc Longitude Slot Vertical (TVD) Reference: 42.T + 13.5' @ 56.2ft (Nabors 19AC) g g ?;' Measured Depth Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) 0.0 0.0 6031076.06 469845.81 70° 29' 45.498 N 150° 14' 47.653 W ODS-13 Calculation Method: Minimum Curvature WELLBORE TARGET DETAILS (MAP CO-ORDINATES) COMPANY DETAILS: Well Planning - Pioneer - Oooguruk Name TVD +N / -S +E / -W Northing Easting Shape Calculation Method: Minimum Curvature Project: Oooguruk Development Error System: ISCWSA 9 p KupHi P61 SCP 3000.0 1397.0 -506.7 6032474.92 469344.86 Point Site: Oooguruk Drill Site KupHi v7 T1 5990.2 4575.0 - 3321.7 6035664.00 466543.00 Circle (Radius: 200.0 Scan Method: Tray. Cylinder North Well: ODSK -13i Warning Surface: Elliptical Conic min Method: Rules Based Wellbore: ODSK -13i KupH Plan: ODSK -13i KupH wp09 SURVEY PROGRAM 5200 Total Depth at 9694.40' MD, 6515.80' TVD 7 5/8' , Date: 2009 12 15T00:00:00 Validated: Yes Version: ODSK - 13i Kup11 wp09 - , b De p th From Depth To Survey /Plan Tool Start Dir 3.00/100' 8988.20' MD, 6014.20' TVD 42.7 1500.0 ODSK - 13i KupH wp09 SR - Gyro - 4800 ` - - 1500.0 9694.4 ODSK - 13i KupH wp09 MW D +IFR2 +MS +sag D D Poly 95% 4400 - I 9 .. C • - SECTION DETAILS KupHi v7 Ti S pa h Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target - 1 42.7 0.00 0.00 42.7 0.0 0.0 0.00 0.00 0.0 4000- 2 300.0 0.00 0.00 300.0 0.0 0.0 0.00 0.00 0.0 - 3 600.0 3.00 305.00 599.9 4.5 -6.4 1.00 305.00 7.5 _ pa 4 750.0 6.00 305.00 749.4 11.3 -16.1 2.00 0.00 18.7 _ h 5 1016.7 14.00 305.00 1011.8 37.8 -54.0 3.00 0.00 62.7 3600- 6 1692.8 24.14 305.00 1650.0 164.3 -234.7 1.50 0.00 272.6 - 7 1802.4 24.14 305.00 1750.0 190.0 -271.4 0.00 0.00 315.3 - 8 3308.4 63.37 2.05 2853.2 1104.4 -517.1 3.49 70.86 1192.9 9 3635.9 63.37 2.05 3000.0 1397.0 -506.7 0.00 0.00 1419.9 KupHi PB1 SCP - 3200- - DDI = 6.14 a 10 3655.9 63.37 2.05 3009.0 1414.8 -506.0 0.00 0.00 1433.8 11 5128.2 55.01 310.99 3800.7 2523.4 -960.5 3.00 - 113.85 2592.2 ' - 12 8946.3 55.01 310.99 5990.2 4575.0 - 3321.7 0.00 0.00 5652.6 KupHi v7 Ti w - 13 8988.2 55.01 310.99 6014.2 4597.5 - 3347.6 0.00 0.00 5686.2 14 9594.4 36.82 310.99 6434.2 4881.9 - 3675.0 3.00 180.00 6110.5 O 2800- ce 15 9694.4 33.82 310.99 6515.8 4919.8 - 3718.6 3.00 180.00 6167.0 o - .+-. - 2400- End Dir 5128.20' MD, 3800.70' TVD _ -50 Start Dir 3.0 /100' 3655.90' MD, 3009.00' TVD CASING DETAILS s 2000- TVD MD Name Size 3000.0 3635.9 10 3/4" 10.750 O / End Dir 3308.40' MD, 2853.20' TVD 6515.8 9694.4 7 5/8" 7.625 rn 1600 10 3/4" " ' KupH P SCE _ - - Start Dir 3.49/100' 1802.40' MD, 1750.00' TVD 3000 1200 / E nd pi, 1692.80' MD, 1650.00' TVD - - / Starbdir 1.50 /100' 1016.70' MD, 1011.80' TVD 800 250 Start -Dir 3.00 /100' 750.00' MD, 749.40' TVD 400 7 ' / __ Start Dir 200/100' 600.00' MD, 599.90' TVD _ _ . - . Start Dir 1.00 /100' 300.00' MD, 300.00' TVD 0- -400 - 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 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 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 I I I I I I I I I I I I I I I I I I I I I I I I -6000 -5600 -5200 -4800 -4400 -4000 -3600 -3200 -2800 -2400 -2000 -1600 -1200 -800 -400 0 400 800 1200 1600 2000 2400 2800 3200 3600 West( - )/East( +) (1000 ft/in) Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -13i ODSK -13i KupH ODSK -13i KupH wp09 • Sperry Drilling Services Clearance Summary Anticollision Report 15 December, 2009 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - ODSK -13i KupH - ODSK -13i KupH wp09 Well Coordinates: 6,031,076.06 N, 469,845.81 E (70° 29' 45.50" N, 150° 14' 47.65" W) • Datum Height: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Scan Range: 1,600.0 to 9,694.4 ft. Measured Depth. Scan Radius is 1,165.2 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services SURVEY PROGRAM ANTI- COLLISION SETTINGS Date: 2009-12-15T00:00:00 Validated: Yes Version: FOR USE FROM Interpolation Method: MD, interval: 25.0 Dept Ram: T Depth From Depth To Survey /Plan Tool 1 6 00 • TO T D Results h Limited ng e Fr o By: Centre 1600.0 Distance: o 9694.4 1165.2 42.7 1500.0 ODSK -13i KupH wp09 SR- Gyro -SS Reference: Plan: ODSK -13i KupH wp09 (ODSK -13i /ODSK -13i KupH) 1500.0 9694.4 ODSK -13i KupH wp09 MWD+IFR2 +MS+sag Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference u From Color To MD 0 i4 s 330 � 30 43 250 � _� 30 250 500 \ ' ` 500 700 � , �• '11"---- \` ` 1000 1250 750 1000 , r 11 1 1 ` 1 _ �� 300 60 300 60 1250 1500 �� 54 % 1500 ...- --_-_. 1750 /74',''. N � � 1750 2000 is t � - 4,,,,, � 2000 2250 - ��� /// 6 7--- /� zo z�so r r�i11 / / � , 270 - 90 NI .� i - _ - 2750 3000 i . ; : l 3000 4000 .., vigiliiii, . .. ,�•���'•: 4000 5000 270 �','4��� : ; ..:.�. 90 soon s000 r ..n ' � (,� 6000 7000 `, ,��•`_` ,,,,vi �; : 7000 8000 240 �� _ , � 120 ,e•r s000 s000 �� ��� '� I s000 10000 �- _ � \ %-; r _ • : • ' /� A , • I 10000 - _ _ 11000 _� � li II‘ \ i;;', '''%°:,..:::::,:;,;-%::',:-. �. l* 11000 12000 � _�� //.., ,,., ,: ' • ., , ®7 12000 13000 0 % '� 1 50 240 ......;;6 � ,- ,�� /., w , , 120 �i tl �I. �, 13000 14000 j •' s I s, • . ODSN -12 PS10 14000 15000 180 :•>'. Range 1600 - 2000 1 I; � ''1�,�� Major Risk 150 16000 � � ., �� 16000 17000 • ODSK -14 KupB i �' � ��"`,�� \: 17000 18000 Range 1600 -1750 *. ; / -' �' ® ' te r 18000 19000 Major Risk 21 �! ..;.."-•'''' / 1. 150 „�;•„, :, III ,mow \ 19000 20000 � ` 20000 21000 Travelling Cylinder Azimuth (TFO+AZI) 171 vs Centre to Centre Separation 120 ft/in] ODSK - Ku P B Range 1600 - 2250 180. Major Risk ODSN - 11 i 1511 Range 1600 - 2750 Travelling Cylinder Azimuth (TFO+AZI) ( ?( vs Centre to Centre Separation 150 ft /in( SECTION DUALS REFERENCE INFORMATION Well Planning - Pioneer - Oooguruk Sec MD 414 AP TVD +WS +E6W DLeg TFSCe VSec Tayet 1 427 000 000 42.7 00 00 000 000 00 2 3000 000 000 3000 00 00 000 000 00 Co-ordinate (N /E) Reference: Well ODSK -13i - Slot ODS -13, True North Calculation Method: Minimum Curvature 3 4 6 600 3 6404 143 -16 1 ° 1 200 0 0000 1ei Vertical (TVD) Reference: 42.T +13.5' @ 56.20 (Nabors 19AC) Errors stem: ISCWSA 5 10167 1400 3050 8 0 ,01, 37.8 640 340 000 627 Section (VS ) Reference: Slot - ODS- 13( ) 0.ON, 0.0E �' 6 1692.8 2414 30500 16500 164.3 -234.7 150 000 2726 1` Measured Depth Reference: 42.7+ 13.5' @ 56.2ft (Nabors 19AC) Scan Method: Tray. Cylinder North 7 1802.4 2414 30500 17500 1900 -271.2 000 000 3153 8 3308.4 8337 205 2853.2 1104.4 -5171 349 7086 11929 Calculation Method: Minimum Curvature Error Surface: Elliptical Conic 9 36359 6337 205 30000 13970 -5067 000 000 1419.9 KupHIPB1SCP 10 36559 6337 205 30090 1414.8 -5060 000 000 14336 Warning Method: Rules Based 11 5128.2 5501 31099 3800, 25234 -9605 300 -11385 2592.2 12 89463 5501 31099 59902 45750 -33217 000 000 56526 KupH v7 T1 13 89882 5501 31099 60142 4597.5 -33476 000 000 56862 14 95940 3882 31099 64342 48819 -36750 300 18000 61105 15 96940 3382 31099 85158 49198 -37186 300 18000 81670 NAD 27 ASP Zone 4 : WELL DETAILS: ODSK -13i Ground Level: 13.5 +NI -S +E/ -W Northing Easting Latittude Longitude Slot 0.0 0.0 6031076.06 469845.81 70° 29' 45.498 N 150° 14' 47.653 W ODS -13 Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -13i - ODSK -13i KupH wp09 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - ODSK -13i KupH - ODSK -13i KupH wp09 Scan Range: 1,600.0 to 9,694.4 ft. Measured Depth. Scan Radius is 1,165.2 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth ion th Factor Minimum Separation Warning p Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft Oooguruk Drill Site • ODSDW1 -44 - ODSDW1 -44 Disposal - ODSDW1 -44 C 1,600.0 289.8 1,600.0 261.3 1,675.0 10.147 Clearance Factor Pass - Major Risk ODSDW2 -20 - ODSDW2 -20 Disposal - ODSDW2 -20 C 1,607.5 321.7 1,607.5 293.5 1,700.0 11.434 Clearance Factor Pass - Major Risk ODSK - 14 - ODSK - 14 KupB - ODSK - 14 KupB wp04.a 1,623.0 52.6 1,623.0 14.7 1,625.0 1.386 Fatty Pass - tYl Risk ODSK -33 - ODSK -33 KupA - ODSK -33 KupA 1,604.1 178.2 1,604.1 150.4 1,650.0 6.418 Clearance Factor Pass - Major Risk ODSK -33 - ODSK -33 PB1 KupA - ODSK -33 PB1 KupP 1,604.1 178.2 1,604.1 150.4 1,650.0 6.418 Clearance Factor Pass - Major Risk ODSK -35 - ODSK -35 KupB - ODSK -35 KupB Surveys 1,604.0 270.1 1,604.0 243.2 1,675.0 10.035 Clearance Factor Pass - Major Risk ODSK -38i - ODSK -381 KupD - ODSK -381 KupD Survey; 1,600.0 445.3 1,600.0 417.8 1,750.0 16.229 Clearance Factor Pass - Major Risk ODSK -41 - ODSK -41 KupF - ODSK -41 KupF Surveys 1,600.0 448.2 1,600.0 420.1 1,750.0 15.950 Clearance Factor Pass - Major Risk ODSK -41 - ODSK -41 PB1 KupF - ODSK -41 PB1 KupF 1,600.0 448.2 1,600.0 420.1 1,750.0 15.950 Clearance Factor Pass - Major Risk ODSK -42i - ODSK -42Ai - ODSK -42Ai wp06 1,615.6 432.0 1,615.6 401.2 1,750.0 14.023 Clearance Factor Pass - Major Risk ODSK -42i - ODSK -42Ai - ODSK -42Ai 1,615.6 432.0 1,615.6 401.2 1,750.0 14.023 Clearance Factor Pass - Major Risk ODSK -42i - ODSK -42i KupG - ODSK -42i KupG 1,615.6 432.0 1,615.6 401.2 1,750.0 14.023 Clearance Factor Pass - Major Risk ODSN -1 - ODSN -1 - ODSN -1 NE3 wp01 1,610.3 461.3 1,610.3 426.8 1,725.0 13.406 Clearance Factor Pass - Major Risk ODSN -10 - ODSN -10 PS12 - ODSN -10 PS12 wp11 - 6 1,608.5 194.3 1,608.5 164.5 1,650.0 6.520 Clearance Factor Pass - Major Risk ODSN -11i - ODSN -111 IS11 - ODSN -11i IS11 wp09 1,613.9 70.0 1,613.9 37.7 1,625.0 2.168 Clearance Factor Pass - Major Risk ODSN -12 - ODSN -12 PS10 - ODSN -12 PS10 wp13 - 8 1,608.1 92.6 1,608.1 62.2 1,625.0 3.051 Clearance Factor Pass - Major Risk ODSN -15 - ODSN -15 PS13 - ODSN -15 PS13 wp09 8K 1,615.3 72.0 1,615.3 38.2 1,625.0 2.128 Clearance Factor Pass - Major Risk ODSN -16i - ODSN -16i 1S14 - ODSN -16i 1S14 wp09 1,600.0 133.6 1,600.0 103.5 1,625.0 4.450 Clearance Factor Pass - Major Risk ODSN -17i - ODSN -17i IS16 - ODSN -171 IS16 wp09 1,613.0 106.3 1,613.0 68.3 1,625.0 2.797 Clearance Factor Pass - Major Risk ODSN -18 - ODSN -18 PS15 - ODSN -18 PS15 wp09 1,600.0 160.0 1,600.0 125.6 1,625.0 4.652 Clearance Factor Pass - Major Risk ODSN -2 - ODSN -2 PS1 - ODSN -2 PS1 wp08 1,618.6 426.5 1,618.6 390.9 1,725.0 11.957 Clearance Factor Pass - Major Risk ODSN -25 - ODSN -25 - ODSN -25 NE4 wp02 1,613.1 611.4 1,613.1 579.5 1,825.0 19.169 Clearance Factor Pass - Major Risk ODSN -26 - ODSN -26 PN1 - ODSN -26 PN1 wp06 1,614.8 478.9 1,614.8 444.3 1,750.0 13.879 Clearance Factor Pass - Major Risk ODSN -27i - ODSN -27i 1N2 - ODSN -27i 1N2 wp06 1,616.1 460.9 1,616.1 428.6 1,750.0 14.265 Clearance Factor Pass - Major Risk ODSN -28 - ODSN -28 PN3 - ODSN -28 PN3 wp07.a 1,600.0 576.3 1,600.0 544.7 • 1,800.0 18.256 Clearance Factor Pass - Major Risk ODSN -29i - ODSN -29i 1N4 - ODSN -291 1N4 wp06 1,611.9 503.9 1,611.9 473.2 1,775.0 16.458 Clearance Factor Pass - Major Risk ODSN -30 - ODSN -30 PN5 - ODSN -30 PN5 wp05 1,605.4 504.2 1,605.4 474.6 1,775.0 17.034 Clearance Factor Pass - Major Risk ODSN -31 - ODSN -31 PB1 PN6 - ODSN -31PB1 PN6 S 1,600.0 555.7 1,600.0 526.7 1,800.0 19.167 Clearance Factor Pass - Major Risk 15 December, 2009 - 12:56 Page 2 of 6 COMPASS Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -13i - ODSK -13i KupH wp09 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - ODSK -131 KupH - ODSK -13i KupH wp09 Scan Range: 1,600.0 to 9,694.4 ft. Measured Depth. Scan Radius is 1,165.2 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft ODSN -31 - ODSN -31 PN6 - ODSN -31 PN6 Surveys 1,600.0 555.7 1,600.0 526.8 1,800.0 19.198 Clearance Factor Pass - Major Risk ODSN -32i - ODSN -32i IN7 - ODSN -32i IN7 Surveys 1,613.7 480.1 1,613.7 450.5 1,775.0 16.241 Clearance Factor Pass - Major Risk ODSN -32i - ODSN- 32iPB1 IN7 - ODSN- 32iPB1 IN7 1,613.7 480.1 1,613.7 450.5 1,775.0 16.241 Clearance Factor Pass - Major Risk • ODSN -34i - ODSN -34 IN9 - ODSN -34i IN9 Surveys 1,600.0 544.1 1,600.0 516.0 1,800.0 19.404 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB1 IN9 - ODSN- 34iPB1 IN9 1,600.0 544.1 1,600.0 516.0 1,800.0 19.403 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB2 IN9 - ODSN- 34iPB2 IN9 1,600.0 544.1 1,600.0 516.0 1,800.0 19.404 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB3 IN9 - ODSN- 34iPB3 IN9 1,600.0 544.1 1,600.0 516.0 1,800.0 19.404 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 PB1 - ODSN -36 PB1 PN10 1,609.0 883.9 1,609.0 854.9 2,050.0 30.467 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 PB2 - ODSN -36 PB2 PN10 1,609.0 883.9 1,609.0 854.9 2,050.0 30.467 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 PN10 - ODSN -36 PN10 Surveys 1,609.0 883.9 1,609.0 854.9 2,050.0 30.467 Clearance Factor Pass - Major Risk ODSN -37 - ODSN -37 - ODSN -37 PN8 1,600.0 534.2 1,600.0 505.3 1,800.0 18.476 Centre Distance Pass - Major Risk ODSN -37 - ODSN -37 - ODSN -37 PN8 9,542.8 780.7 9,542.8 390.9 13,500.0 2.003 Clearance Factor Pass - Major Risk ODSN -39i - ODSN -39i IN11 - ODSN -39i IN11 1,607.9 538.6 1,607.9 509.9 1,800.0 18.818 Clearance Factor Pass - Major Risk ODSN -3i - ODSN -3i IS2 - ODSN -3i IS2 wp08 1,600.0 340.1 1,600.0 304.1 1,675.0 9.451 Clearance Factor Pass - Major Risk ODSN -4 - ODSN -4 PS3 - ODSN -4 PS3 wp07 1;614.5 245.9 1,614.5 205.9 1,650.0 6.151 Clearance Factor Pass - Major Risk ODSN -40 - ODSN -40 PN12 - ODSN -40 PN12 Surveys 1,611.9 613.6 1,611.9 585.0 1,850.0 21.411 Clearance Factor Pass - Major Risk ODSN -40 - ODSN -40PB1 PN12 - ODSN -40PB1 PN12 1,611.9 613.6 1,611.9 585.0 1,850.0 21.411 Clearance Factor Pass - Major Risk ODSN -40 - ODSN -40PB2 PN12 - ODSN -40PB2 PN12 1,611.9 613.6 1,611.9 585.0 1,850.0 21.411 Clearance Factor Pass - Major Risk ODSN -43 - ODSN -43 PN14 - ODSN -43 PN11 wp18 1,613.3 509.9 1,613.3 476.8 1,775.0 15.397 Clearance Factor Pass - Major Risk • ODSN -45 - ODSN -45A Moraine - ODSN -45A Surveys 1,613.8 505.3 1,613.8 475.3 1,775.0 16.857 Clearance Factor Pass - Major Risk ODSN -45 - ODSN -45i IN13 PB1 - ODSN -45i IN13 PB1 1,613.8 505.3 1,613.8 475.3 1,775.0 16.857 Clearance Factor Pass - Major Risk ODSN -46i - ODSN -46i IN14 - ODSN -46i IN14 wp13 1,611.2 679.5 1,611.2 648.7 1,875.0 22.033 Clearance Factor Pass - Major Risk ODSN -47 - ODSN -47 SW11 wp01 - ODSN -47 SW11 v 1,600.0 558.2 1,600.0 524.8 1,775.0 16.693 Clearance Factor Pass - Major Risk ODSN -48 - ODSn -48 SW9 - ODSN -48 SW9 wp01 1,612.8 510.9 1,612.8 475.9 1,750.0 14.614 Clearance Factor Pass - Major Risk ODSN -5i - ODSN -5i IS4 - ODSN -5i IS4 wp08 1,608.0 239.8 1,608.0 205.9 1,650.0 7.074 Clearance Factor Pass - Major Risk ODSN -6 - ODSN -6 PS5 - ODSN -6 PS5 wp09 1,604.5 197.0 1,604.5 158.8 1,625.0 5.148 Clearance Factor Pass - Major Risk ODSN -7i - ODSN -7i IS7 - ODSN -7i IS7 wp08 1,600.0 285.7 1,600.0 247.5 1,675.0 7.477 Clearance Factor Pass - Major Risk ODSN -8 - ODSN -8 PS8 - ODSN -8 PS8 wp08 - 8K' Hor 1,619.2 178.1 1,619.2 139.3 1,650.0 4.591 Clearance Factor Pass - Major Risk ODSN -9i - ODSN -9i IS9 - ODSN -9i IS9 wp11 - 8K' Hori 1,610.3 102.4 1,610.3 63.4 1,625.0 2.622 Clearance Factor Pass - Major Risk 15 December, 2009 - 12:56 Page 3 of 6 COMPASS Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -13i - ODSK -13i KupH wp09 Survey tool program From To Survey /Plan Survey Tool (ft) (ft) 1 42.7 1,500.0 ODSK -13i KupH wp09 SR- Gyro-SS 1,500.0 9,694.4 ODSK -13i KupH wp09 MWD +IFR2 +MS +sag Ellipse error terms are correlated across survey tool tie -on points. • Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. • 15 December, 2009 - 12:56 Page 4 of 6 COMPASS Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -13i ODSK -13i KupH ODSK -13i KupH wp09 Sperry Drilling Services Clearance Summary Anticollision Report 15 December, 2009 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - ODSK -13i KupH - ODSK -13i KupH wp09 Well Coordinates: 6,031,076.06 N, 469,845.81 E (70° 29' 45.50" N, 150° 14' 47.65" W) • Datum Height: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Scan Range: 42.7 to 1,600.0 ft. Measured Depth. Scan Radius is 1,165.2 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services SURVEY PROGRAM + ANTI- COLLISION SETTINGS Date: 2009 - 12 - 15700:00:00 Validated: Yes Version: OR USE 1' (t ' Interpolation Method: MD, interval: 25.0 Depth Range From: 42.7 To 1600.0 Depth From Depth To Survey /Plan Tool to 1600 Results Limited By: Centre Distance: 1165.2 42.7 1500.0 ODSK - 13i KupH 1909 SR Gyro - SS Reference: Plan: ODSK -13i KupH wp09 (ODSK -13i /ODSK -13i KupH) 1500.0 9694.4 ODSK - 13i KupH 1909 MWD +IFR2 +MS+sag Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference ODSN -2 PSI ` OODSN-11i IS11 ODSN-4 PS3I u i $ � CI ! From Color To MD ODSN 100 � , 1 • , U ` ` 048N-3i 1S2 • 43 250 ! 30 330 t - - - , 30 `\ ` � 1 , ' ODSN - PN3 250 500 33 0 , / / 30 ---- \ ` I ODSN - 5i 1 ODSN - 29i IN4 500 750 . ODSN - 11i 1511 , 750 1000 Range 0 -1250 1250 26 Major Risk , , 1000 _ - 1 ODSN$ PS8 P 8 1250 1500 300 , 60 i ' 7 7 7 , l 1500 1750 ,,� - , � 401 300 i ODSN -9i IS9 +, 7 , 50 ' �/ 77 'OJjSN -30 PN5 20 2250 2000 t---/ t i ' t , 7 i 2250 2500 j % , ,..-- ? t / ��'' ODSN•7' IS7 2500 2750 / ,, :- / 2750 3000 � ` go 4 e i ODb -31 PN6 3000 4000 270 1 \ / / • s ♦ .i' , , t , ∎ M ODSF132iPB1 IN7 4000 5000 . ' . r ` \ - " : i i I 5000 6000 ♦ a,� 270 s' r \ ' 49 10 PS12 6000 7000 t �+: ODSN- 12PS10 L 7000 8000 : r w Range 0 -1250 ODSN -12 PS10 9.,...... ti Ma jor Risk i • . 8000 9000 ��. ., , J 240 r , �•�� ; "' - 12C ' ODSN32i IN7 9000 10000 ; ` ' (;� ���` -� '''I 10000 11000 •��� !� - _ �� ` �r • � � ODSN341N8 11aoo 120 ��� /� 1 i li :: ` 110 t�. :�� ' i � t ' ' - 120 ODSN -36 PN10 1 � ► . _= ODSK- 35 - 13000 , 1 /4 1 . 210 , ! • �,' ' 13000 14000 s /J 150 / e v 14000 -- 15000 I _ < ►i _ 1 '! Lf . J I ? ` -` / J ^ s. I 15000 16000 � 1 180 \ \ `` - -- 240 ODSK-14 KupB' � � _ t � ef o _ I ODSK -33 KupA \ Range 0 -1600 - R ..,• , ;! � !' 16000 17000 ODSK -14 KupB Minor Risk 1/1 `�• ODSN37 17000 18000 Range 0 - 1500 ODSN -16i IS14 • "r " • • / / '" i� "4 N 18000 19000 Minor Risk 1/10 Range O - 1250 f�' • . e ► . ODSK - 38i KupD Major Risk ;6/' !II ` � , 19000 20000 210 1 6 <' s wo t] 1 150' 005n -48 SW9 - a 4 + .. , ODSN -161 1914 20000 21000 _ - ; ; - S ` � I Travelling Cylinder Azimuth (TF0+A711 171 vs Centre to Centre Separation 120 ft/in1 ODSN -47 SW11 wp01 - - - _ / 180- -- ' // - 1 ‘ ` I ODSN -39i IN11 - _ - - / ODSK -42i KupG `, SECTON DETAILS __ -- - _ / I \ ODSK-'. ,ipF Sac MD 4 AA TVD 42-9 +E/ -W DLe9 Tface VS. Target 1 1 427 000 000 427 00 0.0 000 000 00 / ' ODSN -18 PS15 : ODSN -40 PN12 _ 3 6000 300 30500 5999 45 414 000 1 100 305.00 15 ODSN-46i IN14 - ' 0 6 4 4 75000 305.00 7494 113 -161 200 000 18.7 5 10167 1400 30500 10118 378 -540 300 000 62.7 1 6 16928 24.14 30500 16500 164.3 -2347 190 0.00 2726 / ODSDWI -44 Disposal I ODSDW2 -20 Disposal __ _ 8 3308.4 63.37 X 205 28532 11044 -5171 349 7086 13929 7 18024 24 14 - 9 36359 6337 205 30000 1397.0 -5067 000 090 14199 1q9841 SCP Travelling Cylinder Azimuth (TFO+AZI) [.] vs Centre to Centre Separation 150 ft /inl 10 38559 55.07 095 3800.7 1414.8 -9800 0.00 000 1433.8 7 11 51283 5501 31099 39007 25234 -9605 0.00 -11000 25926 13 89483 5501 31099 60142 45975 3347.6 000 000 56822 KiyHiN Ti 13 95944 3682 31099 64342 4881.9 36750 300 000 51105 14 96944 3682 31099 65358 49118 37186 390 18000 81600 15 96944 33.82 31099 65158 49198 37186 300 18000 8187.0 REFERENCE INFORMATION Well Planning - Pioneer - Oooguruk Co- ordinate (N /E) Reference: Well ODSK-13i - Slot ODS- 13, True North Calculation Method: Minimum Curvature NAD 27 ASP Zone 4: WELL DETAILS: ODSK -13i Vertical (TVD) Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Error System: ISCWSA Section (VS) Reference: Slot - ODS13(0.0N, 0.0E) Scan Method: Tray. Cylinder North Ground Level: 13.5 Measured Depth Reference: 42.7' +13.5'@ 56.2ft (Nabors 19AC) Error Surface: Elliptical Conic +N / -S +E/ -W Northing Easting Latittude Longitude Slot Calculation Method: Minimum Curvature Warning Method: Rules Based 0.0 0.0 6031076.06 469845.81 70° 29' 45.498 N 150° 14'47.653 W ODS -13 Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -13i - ODSK -13i KupH wp09 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - ODSK -13i KupH - ODSK -13i KupH wp09 Scan Range: 42.7 to 1,600.0 ft. Measured Depth. Scan Radius is 1,165.2 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft Oooguruk Drill Site ODSDW1 -44 - ODSDW1 -44 Disposal - ODSDW1 -44 C 42.7 68.3 42.7 67.3 42.7 70.819 Centre Distance Pass - Major Risk ill ODSDW1 -44 - ODSDW1 -44 Disposal - ODSDW1 -44 C 598.9 71.0 598.9 60.6 600.0 6.875 Clearance Factor Pass - Major Risk ODSDW2 -20 - ODSDW2 -20 Disposal - ODSDW2 -20 C 625.2 59.1 625.2 47.6 625.0 5.137 Centre Distance Pass - Major Risk ODSDW2 -20 - ODSDW2 -20 Disposal - ODSDW2 -20 C 749.6 59.9 749.6 46.0 750.0 4.310 Clearance Factor Pass - Major Risk ODSK - 14 - ODSK - 14 KupB - ODSK - 14 KupB wp04.a 300.0 7.0 300.0 4.8 300.0 3.219 Ceram Distance Para - harm Risk 1110 ODSK -14 - ODSK -14 KupB - ODSK -14 KupB wp04.a 525.0 7.4 525.0 4.5 525.0 2.523 Factor Pass - War Risk 1110 ODSK -33 - ODSK -33 KupA - ODSK -33 KupA 298.7 50.2 298.7 44.8 300.0 9.395 Centre Distance Pass - Major Risk ODSK -33 - ODSK -33 KupA - ODSK -33 KupA 768.5 56.1 768.5 42.4 775.0 4.090 Clearance Factor Pass - Major Risk ODSK -33 - ODSK -33 PB1 KupA - ODSK -33 PB1 KupP 298.7 50.2 298.7 44.8 300.0 9.395 Centre Distance Pass - Major Risk ODSK -33 - ODSK -33 PB1 KupA - ODSK -33 PB1 KupP 768.5 56.1 768.5 42.4 775.0 4.090 Clearance Factor Pass - Major Risk ODSK -35 - ODSK -35 KupB - ODSK -35 KupB Surveys 150.0 41.0 150.0 38.3 150.0 15.258 Centre Distance Pass - Major Risk ODSK -35 - ODSK -35 KupB - ODSK -35 KupB Surveys 424.2 42.5 424.2 35.1 425.0 5.722 Clearance Factor Pass - Major Risk ODSK -38i - ODSK -38i KupD - ODSK -38i KupD Survey: 198.7 33.2 198.7 29.6 200.0 9.316 Centre Distance Pass - Major Risk ODSK -38i - ODSK -38i KupD - ODSK -38i KupD Survey: 373.3 34.4 373.3 27.8 375.0 5.154 Clearance Factor Pass - Major Risk ODSK -41 - ODSK -41 KupF - ODSK -41 KupF Surveys 42.7 43.2 42.7 42.2 44.0 44.760 Centre Distance Pass - Major Risk ODSK -41 - ODSK -41 KupF - ODSK -41 KupF Surveys 398.2 45.1 398.2 37.8 400.0 6.226 Clearance Factor Pass - Major Risk ODSK -41 - ODSK -41 PB1 KupF - ODSK -41 PB1 KupF 42.7 43.2 42.7 42.2 44.0 44.760 Centre Distance Pass - Major Risk • ODSK -41 - ODSK -41 PB1 KupF - ODSK -41 PB1 KupF 398.2 45.1 398.2 37.8 400.0 6.226 Clearance Factor Pass - Major Risk ODSK -42i - ODSK -42Ai - ODSK -42Ai wp06 75.0 47.9 75.0 46.4 75.0 31.856 Centre Distance Pass - Major Risk ODSK -42i - ODSK -42Ai - ODSK -42Ai wp06 374.7 49.3 374.7 42.5 375.0 7.206 Clearance Factor Pass - Major Risk ODSK -42i - ODSK -42Ai - ODSK -42Ai 75.0 47.9 75.0 46.4 75.0 31.856 Centre Distance Pass - Major Risk ODSK -42i - ODSK -42Ai - ODSK -42Ai 374.7 49.3 374.7 42.5 375.0 7.206 Clearance Factor Pass - Major Risk ODSK -42i - ODSK -42i KupG - ODSK -42i KupG 75.0 47.9 75.0 46.4 75.0 31.856 Centre Distance Pass - Major Risk ODSK -42i - ODSK -42i KupG - ODSK -42i KupG 374.7 49.3 374.7 42.5 375.0 7.206 Clearance Factor Pass - Major Risk ODSN -1 - ODSN -1 - ODSN -1 NE3 wp01 300.0 106.0 300.0 100.4 300.0 18.891 Centre Distance Pass - Major Risk ODSN -1 - ODSN -1 - ODSN -1 NE3 wp01 399.7 107.0 399.7 99.6 400.0 14.427 Clearance Factor Pass - Major Risk ODSN -10 - ODSN -10 PS12 - ODSN -10 PS12 wp11 - 61 300.0 32.0 300.0 26.4 300.0 5.706 Centre Distance Pass - Major Risk ODSN -10 - ODSN -10 PS12 - ODSN -10 PS12 wp11 - 6 674.2 34.8 674.2 22.3 675.0 2.795 Clearance Factor Pass - Major Risk 15 December, 2009 - 12:39 Page 2 of 8 COMPASS Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -13i - ODSK -13i KupH wp09 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - ODSK -13i KupH - ODSK -13i KupH wp09 Scan Range: 42.7 to 1,600.0 ft. Measured Depth. Scan Radius is 1,165.2 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft ODSN -11i - ODSN -11i IS11 - ODSN -11i IS11 wp09 599.8 25.0 599.8 14.1 600.0 2.287 Centre Distance Pass - Major Risk ODSN -11i - ODSN -11i IS11 - ODSN -11i IS11 wp09 849.0 26.7 849.0 10.7 850.0 1.673 Clearance Factor Pass - Major Risk ODSN -12 - ODSN -12 PS10 - ODSN -12 PS10 wp13 - 8 300.0 18.0 300.0 12.4 300.0 3.234 Centre Distance Pass - Major Risk III ODSN -12 - ODSN -12 PS10 - ODSN -12 PS10 wp13 - 8 724.3 20.8 724.3 7.5 725.0 1.564 Clearance Factor Pass - Major Risk ODSN - 15 - ODSN - 15 PS13 - ODSN - 15 PS13 wp09 8K 300.0 14.0 300.0 11.3 300.0 5.257 Centre P - Nam Risk 1/200 ODSN - 15 - ODSN - 15 PS13 - ODSN - 15 PS13 wp09 8K 750.2 15.3 750.2 10.0 750.0 2.893 Fader Pores - Minor Risk 11200 ODSN -16i - ODSN -16i 1S14 - ODSN -16i IS14 wp09 500.0 20.7 500.0 11.4 500.0 2.231 Centre Distance Pass - Major Risk ODSN -16i - ODSN -16i 1S14 - ODSN -16i IS14 wp09 674.8 21.9 674.8 9.5 675.0 1.763 Clearance Factor Pass - Major Risk ODSN -17i - ODSN -17i 1S16 - ODSN -17i IS16 wp09 300.0 27.9 300.0 22.3 300.0 4.979 Centre Distance Pass - Major Risk ODSN -17i - ODSN -17i IS16 - ODSN -17i IS16 wp09 775.4 32.7 775.4 18.3 775.0 2.270 Clearance Factor Pass - Major Risk ODSN -18 - ODSN -18 PS15 - ODSN -18 PS15 wp09 425.1 34.8 425.1 26.9 425.0 4.413 Centre Distance Pass - Major Risk ODSN -18 - ODSN -18 PS15 - ODSN -18 PS15 wp09 650.1 36.8 650.1 24.9 650.0 3.102 Clearance Factor Pass - Major Risk ODSN -2 - ODSN -2 PS1 - ODSN -2 PS1 wp08 300.0 99.0 300.0 93.4 300.0 17.643 Centre Distance Pass - Major Risk ODSN -2 - ODSN -2 PS1 - ODSN -2 PS1 wp08 474.4 100.0 474.4 91.2 475.0 11.377 Clearance Factor Pass - Major Risk ODSN -25 - ODSN -25 - ODSN -25 NE4 wp02 298.7 110.9 298.7 105.3 300.0 19.843 Centre Distance Pass - Major Risk ODSN -25 - ODSN -25 - ODSN -25 NE4 wp02 373.1 111.6 373.1 104.7 375.0 16.186 Clearance Factor Pass - Major Risk ODSN -26 - ODSN -26 PN1 - ODSN -26 PN1 wp06 300.0 104.2 300.0 98.6 300.0 18.575 Centre Distance Pass - Major Risk ODSN -26 - ODSN -26 PN1 - ODSN -26 PN1 wp06 448.7 105.4 448.7 97.0 450.0 12.664 Clearance Factor Pass - Major Risk ODSN -27i - ODSN -27i 1N2 - ODSN -27i IN2 wp06 300.0 97.6 300.0 92.0 300.0 17.391 Centre Distance Pass - Major Risk • ODSN -27i - ODSN -27i 1N2 - ODSN -27i IN2 wp06 498.3 99.3 498.3 90.1 500.0 10.747 Clearance Factor Pass - Major Risk ODSN -28 - ODSN -28 PN3 - ODSN -28 PN3 wp07.a 300.0 91.1 300.0 85.5 300.0 16.228 Centre Distance Pass - Major Risk ODSN -28 - ODSN -28 PN3 - ODSN -28 PN3 wp07.a 374.4 91.7 374.4 84.8 375.0 13.290 Clearance Factor Pass - Major Risk ODSN -29i - ODSN -29i IN4 - ODSN -29i IN4 wp06 300.0 84.6 300.0 79.0 300.0 15.075 Centre Distance Pass - Major Risk ODSN -29i - ODSN -29i IN4 - ODSN -29i IN4 wp06 424.0 85.4 424.0 77.5 425.0 10.859 Clearance Factor Pass - Major Risk ODSN -30 - ODSN -30 PN5 - ODSN -30 PN5 wp05 300.0 78.2 300.0 72.6 300.0 13.929 Centre Distance Pass - Major Risk ODSN -30 - ODSN -30 PN5 - ODSN -30 PN5 wp05 473.6 79.7 473.6 70.9 475.0 9.065 Clearance Factor Pass - Major Risk ODSN -31 - ODSN -31 PB1 PN6 - ODSN -31 PB1 PN6 S 300.0 61.8 300.0 56.3 300.0 11.195 Centre Distance Pass - Major Risk ODSN -31 - ODSN -31 PB1 PN6 - ODSN-31PB1 PN6 S 374.5 62.3 374.5 55.6 375.0 9.228 Clearance Factor Pass - Major Risk ODSN -31 - ODSN -31 PN6 - ODSN -31 PN6 Surveys 300.0 61.8 300.0 56.4 300.0 11.291 Centre Distance Pass - Major Risk ODSN -31 - ODSN -31 PN6 - ODSN -31 PN6 Surveys 374.5 62.3 374.5 55.6 375.0 9.293 Clearance Factor Pass - Major Risk 15 December, 2009 - 12:39 Page 3 of 8 COMPASS Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -13i - ODSK -13i KupH wp09 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - ODSK -13i KupH - ODSK -13i KupH wp09 Scan Range: 42.7 to 1,600.0 ft. Measured Depth. Scan Radius is 1,165.2 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft ODSN -32i - ODSN -32i IN7 - ODSN -321 1N7 Surveys 150.0 56.0 150.0 53.3 150.0 20.511 Centre Distance Pass - Major Risk ODSN -32i - ODSN -32i IN7 - ODSN -32i IN7 Surveys 399.2 57.1 399.2 50.0 400.0 7.975 Clearance Factor Pass - Major Risk • ODSN -32i - ODSN- 32iPB1 1N7 - ODSN- 32iPB1 IN7 150.0 56.0 150.0 53.3 150.0 20.511 Centre Distance Pass - Major Risk ODSN -32i - ODSN- 32iPB1 IN7 - ODSN- 32iPB1 IN7 399.2 57.1 399.2 50.0 400.0 7.975 Clearance Factor Pass - Major Risk ODSN -34i - ODSN -34 1N9 - ODSN -34i IN9 Surveys 300.0 43.8 300.0 38.3 300.0 8.023 Centre Distance Pass - Major Risk ODSN -34i - ODSN -34 1N9 - ODSN -34i 1N9 Surveys 374.5 44.2 374.5 37.6 375.0 6.625 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB1 1N9 - ODSN- 34iPB1 1N9 300.0 43.8 300.0 38.3 300.0 8.023 Centre Distance Pass - Major Risk ODSN -34i - ODSN- 34iPB1 1N9 - ODSN- 34iPB1 1N9 374.5 . 44.2 374.5 37.6 375.0 6.625 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB2 1N9 - ODSN- 34iPB2 1N9 300.0 43.8 300.0 38.3 300.0 8.023 Centre Distance Pass - Major Risk ODSN -34i - ODSN- 34iPB2 1N9 - ODSN- 34iPB2 1N9 374.5 44.2 374.5 37.6 375.0 6.625 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB3 1N9 - ODSN- 34iPB3 IN9 300.0 43.8 300.0 38.3 300.0 8.023 Centre Distance Pass - Major Risk ODSN -34i - ODSN- 34iPB3 1N9 - ODSN- 34iPB3 IN9 374.5 44.2 374.5 37.6 375.0 6.625 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 PB1 - ODSN -36 PB1 PN10 200.0 37.0 200.0 33.3 200.0 10.207 Centre Distance Pass - Major Risk ODSN -36 - ODSN -36 PB1 - ODSN -36 PB1 PN10 324.8 37.4 324.8 31.7 325.0 6.549 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 PB2 - ODSN -36 PB2 PN10 200.0 37.0 200.0 33.3 200.0 10.207 Centre Distance Pass - Major Risk ODSN -36 - ODSN -36 PB2 - ODSN -36 PB2 PN10 324.8 37.4 324.8 31.7 325.0 6.549 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 PN10 - ODSN -36 PN10 Surveys 200.0 37.0 200.0 33.3 200.0 10.207 Centre Distance Pass - Major Risk ODSN -36 - ODSN -36 PN10 - ODSN -36 PN10 Surveys 324.8 37.4 324.8 31.7 325.0 6.549 Clearance Factor Pass - Major Risk ODSN -37 - ODSN -37 - ODSN -37 PN8 349.7 31.9 349.7 25.5 350.0 5.017 Centre Distance Pass - Major Risk • ODSN -37 - ODSN -37 - ODSN -37 PN8 399.4 32.2 399.4 25.0 400.0 4.479 Clearance Factor Pass - Major Risk ODSN -39i - ODSN -39i IN11 - ODSN -39i IN11 42.7 35.6 42.7 34.7 42.7 36.970 Centre Distance Pass - Major Risk ODSN -39i - ODSN -39i IN11 - ODSN -39i IN11 324.9 37.5 324.9 31.6 325.0 6.328 Clearance Factor Pass - Major Risk ODSN -3i - ODSN -3i 1S2 - ODSN -3i IS2 wp08 300.0 92.0 300.0 86.4 300.0 16.397 Centre Distance Pass - Major Risk ODSN -3i - ODSN -3i 152 - ODSN -3i 1S2 wp08 549.2 93.3 549.2 83.1 550.0 9.162 Clearance Factor Pass - Major Risk ODSN -4 - ODSN -4 PS3 - ODSN -4 PS3 wp07 300.0 85.0 300.0 79.4 300.0 15.156 Centre Distance Pass - Major Risk ODSN -4 - ODSN -4 PS3 - ODSN -4 PS3 wp07 449.6 86.4 449.6 78.0 450.0 10.347 Clearance Factor Pass - Major Risk ODSN -40 - ODSN -40 PN12 - ODSN -40 PN12 Surveys 42.7 38.9 42.7 37.9 44.0 40.328 Centre Distance Pass - Major Risk ODSN -40 - ODSN -40 PN12 - ODSN -40 PN12 Surveys 323.6 40.2 323.6 34.3 325.0 6.836 Clearance Factor Pass - Major Risk ODSN -40 - ODSN -40PB1 PN12 - ODSN -40PB1 PN12 42.7 38.9 42.7 37.9 44.0 40.328 Centre Distance Pass - Major Risk ODSN -40 - ODSN -40PB1 PN12 - ODSN -40PB1 PN12 323.6 40.2 323.6 34.3 325.0 6.836 Clearance Factor Pass - Major Risk 15 December, 2009 - 12:39 Page 4 of 8 COMPASS Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -13i - ODSK -13i KupH wp09 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - ODSK -13i KupH - ODSK -13i KupH wp09 Scan Range: 42.7 to 1,600.0 ft. Measured Depth. Scan Radius is 1,165.2 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft ODSN -40 - ODSN -40PB2 PN12 - ODSN -40PB2 PN12 42.7 38.9 42.7 37.9 44.0 40.328 Centre Distance Pass - Major Risk ODSN -40 - ODSN -40PB2 PN12 - ODSN -40PB2 PN12 323.6 40.2 323.6 34.3 325.0 6.836 Clearance Factor Pass - Major Risk ODSN -43 - ODSN -43 PN14 - ODSN -43 PN11 wp18 300.0 62.2 300.0 56.6 300.0 11.089 Centre Distance Pass - Major Risk • ODSN -43 - ODSN -43 PN14 - ODSN -43 PN11 wp18 374.7 62.9 374.7 56.1 375.0 9.195 Clearance Factor Pass - Major Risk ODSN -45 - ODSN -45A Moraine - ODSN -45A Surveys 42.7 74.5 42.7 73.5 42.7 73.678 Centre Distance Pass - Major Risk ODSN -45 - ODSN -45A Moraine - ODSN -45A Surveys 324.9 76.6 324.9 70.5 325.0 12.544 Clearance Factor Pass - Major Risk ODSN -45 - ODSN -45i IN13 PB1 - ODSN -45i IN13 PB1 42.7 74.5 42.7 73.5 42.7 73.678 Centre Distance Pass - Major Risk ODSN -45 - ODSN -45i IN13 PB1 - ODSN -45i IN13 PB1 324.9 76.6 324.9 70.5 325.0 12.544 Clearance Factor Pass - Major Risk ODSN -46i - ODSN -46i IN14 - ODSN -46i IN14 wp13 298.7 80.9 298.7 75.3 300.0 14.465 Centre Distance Pass - Major Risk ODSN -46i - ODSN -46i IN14 - ODSN -46i IN14 wp13 398.3 81.7 398.3 74.5 400.0 11.297 Clearance Factor Pass - Major Risk ODSN -47 - ODSN -47 SW11 wp01 - ODSN -47 SW11 v‘ 298.7 87.4 298.7 81.8 300.0 15.632 Centre Distance Pass - Major Risk ODSN -47 - ODSN -47 SW11 wp01 - ODSN -47 SW11 w 373.5 88.0 373.5 81.2 375.0 12.894 Clearance Factor Pass - Major Risk ODSN -48 - ODSn -48 SW9 - ODSN -48 SW9 wp01 298.7 93.9 298.7 88.3 300.0 16.790 Centre Distance Pass - Major Risk ODSN -48 - ODSn -48 SW9 - ODSN -48 SW9 wp01 373.5 94.4 373.5 87.6 375.0 13.826 Clearance Factor Pass - Major Risk ODSN -5i - ODSN -5i IS4 - ODSN -5i IS4 wp08 300.0 78.0 300.0 72.4 300.0 13.903 Centre Distance Pass - Major Risk ODSN -5i - ODSN -5i IS4 - ODSN -5i IS4 wp08 524.4 79.5 524.4 69.8 525.0 8.181 Clearance Factor Pass - Major Risk ODSN -6 - ODSN -6 PS5 - ODSN -6 PS5 wp09 300.0 71.0 300.0 65.4 300.0 12.658 Centre Distance Pass - Major Risk ODSN -6 - ODSN -6 PS5 - ODSN -6 PS5 wp09 499.6 72.8 499.6 63.6 500.0 7.876 Clearance Factor Pass - Major Risk ODSN -7i - ODSN -7i IS7 - ODSN -7i IS7 wp08 300.0 53.0 300.0 45.4 300.0 6.978 Centre Distance Pass - Major Risk • ODSN -7i - ODSN -7i IS7 - ODSN -7i IS7 wp08 673.6 56.5 673.6 38.6 675.0 3.157 Clearance Factor Pass - Major Risk ODSN -8 - ODSN -8 PS8 - ODSN -8 PS8 wp08 - 8K Hor 298.7 46.0 298.7 40.5 300.0 8.364 Centre Distance Pass - Major Risk ODSN -8 - ODSN -8 PS8 - ODSN -8 PS8 wp08 - 8K Hoi 573.2 48.1 573.2 37.6 575.0 4.571 Clearance Factor Pass - Major Risk ODSN -9i - ODSN -9i IS9 - ODSN -9i IS9 wp11 - 8K Hor 298.7 39.0 298.7 32.9 300.0 6.431 Centre Distance Pass - Major Risk ODSN -9i - ODSN -9i IS9 - ODSN -9i IS9 wp11 - 8K' Hor 772.8 42.9 772.8 26.8 775.0 2.660 Clearance Factor Pass - Major Risk 15 December, 2009 - 12:39 Page 5 of 8 COMPASS Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -13i - ODSK -13i KupH wp09 Survey tool program From To Survey /Plan Survey Tool (ft) (ft) 42.7 1,500.0 ODSK -13i KupH wp09 SR- Gyro-SS 1,500.0 9,694.4 ODSK -13i KupH wp09 MWD +IFR2 +MS +sag Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. • Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. • 15 December, 2009 - 12:39 Page 6 of 8 COMPASS PIONEER NATURAL RESOURCES December 15, 2009 RECEIVED State of Alaska DEC 1 111O9 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite #100 Alaska Oil & Gas CO M. Commission Anchorage, AK 99501 Aot;4 orage RE: Application for Permit to Drill ODSK -13i Previous Permit # 209 -146 Surface Location: 2960' FSL, 1152' FEL, Sec 11, T13N, R7E, UM X = 469,845.81, Y = 6,031,076.06, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill an injection well from the Oooguruk Drill Site (ODS) located within the Oooguruk Unit. The well is designed to be a pre - produced injection well in the Oooguruk- Kuparuk formation. PNRA requests the permit to drill based on approved Pool Rules. ODSK -13i was originally granted approval on November 23, 2009, Permit No. 209 -146. Pioneer Natural Resources is applying to re- permit ODSK -13i due to change of bottom hole location greater than 500 feet (20 ACC 25.015 al). This bottom hole location change is based on log data seen while drilling the ODSK -42i. Unlike the original PTD, this new bottom hole location does not allow for the well to be completed as a dual injector, however it is desired to drill - through and get Togs across the Oooguruk - Nuiqsut reservoir. As indicated in the attachments, the drilling and well construction program includes the following: • Surface Hole: For anti - collision concerns, the surface casing on ODSK -13i and ODSK- 14 will be batch set. o Drill 13 -1/2" to -3636' MD / 3000' TVD rkb and set 10 -3/4" casing • Temporarily shut down drilling operations, and move the rig to ODSK -14 • Production Hole: o Drill 9 -7/8" to -9694' MD / 6516' TVD rkb and set 7 -5/8" casing • Completion: o 3 -1/2" tubing with injection packer • Production: o Depending on reservoir pressure measurements, the well may be pre - produced for approximately 2 months Alaska Oil & Gas Consery n Commission • December 15, 2009 Page2of3 PNRA will implement Managed Pressure Drilling technology (MPD) while drilling the production hole of ODSK -13i. PNRA does not intend on drilling with a mud weight lower than the pore pressure of the exposed formations. PNRA plans to use this technique while drilling the production interval as outlined below. • From the Surface Shoe to below the Base of the Torok Sands o Use -9.0 to 10 ppg fluid while using MPD to control pressure from the surface to -10.5 ppg EMW at the bottom of the hole. • Open formations: • Torok Sands, -8.6 ppg Pore Pressure • From the base of the Torok Sands to Intermediate Hole TD o Use -10.0 to 11.0 ppg fluid while using MPD to control pressure from the surface to -12.5 ppg EMW at the bottom of the hole. • Open formations: • Torok Sands, -8.6 ppg Pore Pressure • • Kuparuk Sands, -9.7 ppg Pore Pressure • Nuiqsut Sands, -9.7 ppg Pore Pressure • Nechelik Sands, -9.7 ppg Pore Pressure ' Utilizing the MPD process allows PNRA to reduce the materials needed for the well and increase the overall safety of the personnel on the development by having Tess material to handle. Based on information previously submitted to the AOGCC and included in the AOGCC ,/ Oooguruk Field File, PNRA requests an exemption from 20 AAC 25.035 (c) which requires a k diverter system be installed on the well while drilling the surface interval. In the future, PNRA may provide information requesting the permitting of annular disposal of drilling wastes on this well. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10 -401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) A copy of the proposed drilling program per 20 AAC 25.005 (c) (13) including: a. The drilling fluid program as required by 20 AAC 25.033 b. Complete logging and mud logging operations are planned and descriptions are attached. c. A complete proposed casing and cementing program is attached as per 20 AAC 25.030. d. A summary of the drilling operations. e. A summary of drilling hazards per 20 AAC 25.005 (c) (4). f. A welibore schematic is also attached visually depicting the final proposed well. Alaska Oil & Gas Consery Commission • December 15, 2009 Page 3 of 3 3) A copy of the Planned Directional Well Path - including traveling cylinder and development layout plots. The following items are on file with the AOGCC: 1) A plat showing the surface location proposed for the well per 20 AAC 25.005 (c) (2). 2) Diagrams and descriptions of the BOP and diverter equipment to be used on Nabors Alaska Rig 19 -AC as required by 20 AAC 25.035 (b) and (c). 3) A description of the procedure for conducting formation integrity tests per 20 AAC 25.035 (c) (5). 4) PNRA does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment as specified in 20 AAC 25.065(1) will be functioning on the rig as standard operating procedure for all wells drilled by that rig. Products for treating H2S contamination in the drilling mud system will be maintained on the ODS. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Vern Johnson, Senior Staff Drilling Engineer (20 AAC 25.070) 907.343.2111 vern.johnson@pxd.com 2) Geologic Data and Logs Paul Daggett, Senior Staff Geophysicist (20 AAC 25.071) 907.343.2134 paul.daggett @pxd.com The anticipated spud date for this well is January 2, 2010. If you have any questions or require further information, please contact Vern Johnson at 907.343.2111. Sincer- y, at 05-// Vern Johnson Senior Staff Drilling Engineer Attachments: Form 10 -401 Supportin g permit information cc: ODSK -13i Well File Page l of 1 • • Schwartz, Guy L (DOA) From: Johnson, Vern [Vern.Johnson @pxd.com] Sent: Thursday, December 17, 2009 5:04 PM (� 2 „�1-N4 To: Schwartz, Guy L (DOA) Cc: Franks James prI) Subject: ODSK -13i permit to drill Guy, Per our conversation today, I have confirmed that there are no other Kuparuk penetrations within % mile of the Kuparuk penetration on ODSK -13i. The horizontal wells shown on the map included in the permit to drill application, ODSN -32i & ODSN- 37 are both at the Nuiqsut depth near ODSK -13i. Let me know if you need any further information. Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska 907 - 343 -2111 office 907 - 575 -9430 cell Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 12/18/2009 • TRANSMITTAL LETTER CHECKLIST WELL NAME ODSK -13 (Re- issue) PTD# 2091460 Development X Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: Oooguruk POOL: Oooguruk, Oooguruk- Kuparuk Oil Pool Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , Permit No. (If last two digits in API No. . Production should continue to be API number are reported as a function of the original API number stated above. between 60 -69) PILOT HOLE In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 ''' 1 09 . ; ,' ; , Field & Pool 000GURUK, KUPARUK OIL - 576100 000GURUK, NUIQSUT OIL - f. Well Name: 000GURUK KUP ODSK -13 Program SER Well bore seg 1460 Company PIONEER NATURAL RESOURCES ALASKA INC Initial Class /Type SER / PEND GeoArea 973 Unit 11550 _ -- On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Entire well will lie within ADL 355036 13 Unique well name and number Yes Dooguruk - Kuparuk injector. 4 Well located in a defined pool Yes 000GURUK, KUPARUK OIL - 576100 governed by CO 596 5 Well located proper distance from drilling unit boundary Yes No restrictions in CO 596 other than >500' from external property line. 1 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 1 12 Permit can be issued without administrative approval Yes SFD 12/16/2009 i13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For Yes AIO 33 15 All wells within 1/4 mile area of review identified (For service well only) Yes None 16 Pre- produced injector: duration of pre - production less than 3 months (For service well only) Yes Plan is to pre - produce for 2 months 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs NA No Aquifers..._ 20 CMT vol adequate to circulate on conductor & surf csg Yes 121 CMT vol adequate to tie-in long string to surf csg No TOC planned for 8846' and 22 CMT will cover_ all known productive horizons Yes Production casing cemented and perfed 23 Casing designs adequate for C, T, B & permafrost Yes 124 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re- drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Close approach with ODSK -14 near su rface . 27 If diverter required, does it meet regulations NA Diverter Waiver_ approved per AAC 15.035 (h) (2) Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure= 3247 psi ( 9.7 ppg EMW) .. Will drill with 10-11 ppg and MPD for hole Stability GLS 12/17/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP =2546 psi Will test BOPs to 4500 psi 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes Rig will drill surface hole.. Move to ODSK -14 D &C , then back to OD S K -13 i 33 Is presence of H2S gas probable No No H2S on Pad. Rig has alarms and sensors. 34 Mechanical condition of wells within AOR verified (For service well only) Yes AOR complete. No wells penetrate the Kuparuk zone within 1/4 mile. 35 Permit can be issued w/o hydrogen sulfide measures Yes None anticipated, but sensors will be employed. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is up to 9.7 P p p ppg EMW; will be drilled using 11.0 ppg mud Appr Date 37 Seismic analysis of shallow gas zones NA and managed pressure drilling technique to maintain borehole stability. SFD 12/16/2009 ' 38 Seabed condition survey (if off-shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering ' Re -issue for pre-produced Ooo uruk -Ku aruk injector that will, upon Commission a Commissioner: Date: C ssioner• Date ti.., ' Date P p 9 P J P pproval, eventually be converted to an C.ner Oooguruk-Kuparuk Pool injector. 0.1, , :- , , f �, a —' u r s_s ( .- i) j t P ° i ; Q 1 a P IA' � s p _ SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS i 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 / FAX (907) 276 -7542 Mr. Vern Johnson Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska Inc. 700 G Street, Suite 600 Anchorage, Alaska 99501 Re: Oooguruk - Kuparuk Oil Pool and Oooguruk - Nuiqsut Oil Pool, ODSK -13i Pioneer Natural Resources Alaska Inc. Permit No: 209 -146 Surface Location: 2960' FSL, 1152' FEL, SEC. 11, T13N, R7E, UM Bottomhole Location: 4665' FSL, 354' FEL, SEC. 3, T13N, R7E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced service 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. When providing notice for a representative of the Commission to witness any e • uired test, contact the Commission's petroleum field inspector at (907) 6 ;9 -3.17 (pager). Si :re Io / Or an - •m, sss'•ner DATED this'iiday of November, 2009 cc: Department of Fish 85 Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ! , , STATE OF ALASKA RECEIVED ALA OIL AND GAS CONSERVATION COMION NOV 1 7 200 PERMIT TO DRILL 20 AAC 25.005 ,Alaska Oil & Gas Cons. Commission 1 a. Type of Work: 1 b. Proposed Well Class: Development - Oil ❑ Service - Winj 0 • Single Zone ❑ 1 c. Specify dt osed for: Drill 10 . Redrill ❑ Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone 0 , Coalbed Gas 0 Gas Hydrates ❑ Re -entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Ei . Single Well ❑ 11. Well Name and Number: Pioneer Natural Resources Alaska, Inc. Bond No. 103655283 * ODSK -13i 3. Address: 700 G Street, Suite 600 6. Proposed Depth: 12. Field /Pool(s): Anchorage, AK 99501 MD: 11,174' • TVD: 6401' ' j) 4a. Location of Well (Govemmental Section): 7. Property Designation (Lease Number): Oooguruk - Kuparuk Oil Pool ,L Surface: 2960' FSL, 1152' FEL, Sec. 11, T13N, R7E, UM • ADL 355036 ' (;I A<<..rr k iL),.(, ,_6, -1C .),j - Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Dat </) 4155' FSL, 49' FEL, Sec. 3, T13N, R7E, UM 417497 12/14/2009 /i/-4"- "' c j Total Depth: 9. Acres in Property: 14. Distance to Nea�res Property: 4665' FSL, 354' FEL, Sec. 3, T13N, R7E, UM 5760 y 3 aM,,(-s 14'`fikI: i / Til- v'. 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 56.2 feet 15. Distance to Nearest Well Open Surface: x- 469845.81 y- 6031076.06 • Zone- ASP 4 GL Elevation above MSL i. 5 f eet t Same Pgo ODSK -38 is 6341' away ` Ad ' /2. 5 %`/c[' Y67LL L �S it1 �7 16. Deviated wells: Kickoff depth: 300 feet , 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) /S> / /.4. 0 Maximum Hole Angle: 63.58 degrees Downhole: 3186 • Surface: 2491 • 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVA 1 MD TVD (including stage data) 24" 16" 109# H -40 Welded 115' Surface sue ¢ IS r 158' Driven 13 -1/2" 10 -3/4" 45.5# L -80 BTC 3726' Surface r.. .. .376 ,7 ` 3000' 504 sx PF 'L'; 237 sx Class 'G' 9 -7/8" 7 -5/8" 29.7# L -80 BTC -M 11,130' Surface ,mot.,•. - / f 173' 6401' 274 sx Class 'G' `. 1 .,.4Zl ( 1• /4 • u I 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re- nE try Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat 0 BOP Sketch ❑ Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Alex Vaughan, 343 -2186 Prepared By: Kathy Campoamor, 343 -2183 Printed Name 7 Vern ohnson Title Sr. Staff Drilling Engineer Signature / - Phone 343 -2111 Date 11/16/2009 / Commission Use Only Permit to Drill / , API Number: �., Permit Approval See cover letter for other Number: Z - / / ( 50- /i' l--�--' 6 e 6C Date: I rI /2,3 /poi 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: D Other. 4/1 5'00 P 5 i 5) P -- g a t- . Samples req'd: Yes CI No Q Mud log req'd: Yes ❑ No p if 2.500 P L ( 1.114-4 'N ' yam H measures: Yep J No[ Directional svy req'd: Yes [r No ❑ u . re:- ; S 1 �v�vr . jPer' 2 0 AA-c.. Z 5.0 3 s C k)( I o live- --( re i - v4lfrMacs ope...4.-4...41L.., - J•. dCr•_ n -�,- �Jt"'� = I: 33 E 3t1 I )0, APPROVED BY THE COMMISSION DATE: 1/ -23 0 " Of /�/, COMMISSIONER 0 : Z 1G1NAL , //:/g.o 7 At . i ,.. 16 .iv Form 10 (Revised 7/2009) This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Submit in Duplicate PIONEER NATURAL RESOURCES November 16, 2009 RECEIVED Nov 1 7 2009 State of Alaska Alaska Oil and Gas Conservation Commission Alaska Oil & Gas Cons. Commission 333 West 7`" Avenue, Suite #100 Anchorage Anchorage, AK 99501 RE: Application for Permit to Drill ODSK -13i Surface Location: 2960' FSL, 1152' FEL, Sec 11, T13N, R7E, UM X = 469,845.81, Y = 6,031,076.06, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill an injection well from the Oooguruk Drill Site (ODS) located within the Oooguruk Unit. The well is designed to be a pre - produced injection well in the Oooguruk - Kuparuk formation. PNRA requests the permit to drill based on approved Pool Rules. Following State approval for co- mingled injection, the long term goal for this well is to be a dual, ✓ co- mingled injector into the Oooguruk - Kuparuk and Oooguruk - Nuiqsut formations ✓ As indicated in the attachments, the drilling and well construction program includes the following: • Surface Hole: For anti - collision concerns, the surface casing on ODSK -13 and ODSK- 14 will be batch set. o Drill 13 -1/2" to -3769' MD / 3000' TVD rkb and set 10 -3/4" casing • Temporarily shut down drilling operations, and move the rig to ODSK -14 ) 4 0 S /i.0.0? • Production Hole: o Drill 9 -7/8" to -11,173' MD / 6401' TVD rkb and set 7 -5/8" casing • Completion: o 3 -1/2" tubing with a straddle packer completion • Production: o Depending on reservoir pressure measurements, the well may be pre - produced for approximately 2 months PNRA will implement Managed Pressure Drilling technology (MPD)hile drilling the production hole of ODSK -13i. PNRA does not intend on drilling with a mud weight lower than the pore pressure of the exposed formations. PNRA plans to use this technique while drilling the production interval as outlined below. Alaska Oil & Gas Conservn Commission • November 13, 2008 Page 2 of 3 • From the Surface Shoe to below the Base of the Torok Sands o Use -9.0 to 10 ppg fluid while using MPD to control pressure from the surface to -10.5 ppg EMW at the bottom of the hole. • Open formations: • Torok Sands, -8.6 ppg Pore Pressure • From the base of the Torok Sands to Intermediate Hole TD o Use -10.0 to 11.0 ppg fluid while using MPD to control pressure from the surface to -12.5 ppg EMW at the bottom of the hole. • Open formations: • Torok Sands, -8.6 ppg Pore Pressure • Kuparuk Sands, -9.7 ppg Pore Pressure • Nuiqsut Sands, -9.7 ppg Pore Pressure • Nechelik Sands, -9.7 ppg Pore Pressure Utilizing the MPD process allows PNRA to reduce the materials needed for the well and increase the overall safety of the personnel on the development by having less material to handle. Based on information previously submitted to the AOGCC and included in the AOGCC Oooguruk Field File, PNRA requests an exemption from 20 AAC 25.035 (c) which requires a diverter system be installed on the well while drilling the surface interval. In the future, PNRA may provide information requesting the permitting of annular disposal of drilling wastes on this well. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10 -401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) A copy of the proposed drilling program per 20 AAC 25.005 (c) (13) including: a. The drilling fluid program as required by 20 AAC 25.033 b. Complete logging and mud logging operations are planned and descriptions are attached. c. A complete proposed casing and cementing program is attached as per 20 AAC 25.030. d. A summary of the drilling operations. e. A summary of drilling hazards per 20 AAC 25.005 (c) (4). f. A wellbore schematic is also attached visually depicting the proposed well. 3) A copy of the Planned Directional Well Path - including traveling cylinder and development layout plots. The following items are on file with the AOGCC: II • Alaska Oil & Gas Conservvn Commission • November 13, 2008 Page 3 of 3 1) A plat showing the surface location proposed for the well per 20 AAC 25.005 (c) (2). 2) Diagrams and descriptions of the BOP and diverter equipment to be used on Nabors Alaska Rig 19 -AC as required by 20 AAC 25.035 (b) and (c). 3) A description of the procedure for conducting formation integrity tests per 20 AAC 25.035 (c) (5). 4) PNRA does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment as specified in 20 AAC 25.065(1) • will be functioning on the rig as standard operating procedure for all wells drilled by that rig. Products for treating H2S contamination in the drilling mud system will be maintained on the ODS. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Vern Johnson, Senior Staff Drilling Engineer (20 AAC 25.070) 907.343.2111 vern.johnson @pxd.com 2) Geologic Data and Logs Paul Daggett, Senior Staff Geophysicist (20 AAC 25.071) 907.343.2134 paul.daggett @pxd.com The anticipated spud date for this well is December 14, 2009. If you have any questions or require further information, please contact Vern Johnson at 907.343.2111. Sincerely__ Vern Johnson Senior Staff Drilling Engineer Attachments: Form 10 -401 Supporting permit information cc: ODSK -13i Well File • 1 ODSK -13i Permit to Drill Well Plan Summary Oooguruk - Kuparuk Pre - produced Injection Well (Long term Dual Kuparuk — Nuiqsut Co- mingled Injection Well) Surface TD @ 3,769' MD / 3,000' TVD Production TD @ 11,174' MD / 6,401' TVD 2ti4.0 Surface Location: 2,9 -{� `FSL, 1 ' FE L, Sec 11, T13N, R7E, UM ASP 4 (NAD27) projection X = 469845.81 • Y = 603076.06 Target: Oooguruk - Kuparuk 4155' FSL, 49' FEL Sec 3, T13N, R7E, Umiat X = 465691.00 1 Y = 6037568.00 5,963' TVDrkb Bottom Hole Location: 4665' FSL, 354' FEL, Sec 3, T13N, R7E, Umiat X = 465386.98 • Y = 6038080.03 6401' TVDrkb AFE Number: TBA Est. Start Date: December 14, 2009 Rig: Nabors 19AC Operating days: 6.5 days D &C Surface, 22.2 days D &C Production TD: 11,174' MD / 6,401 TVDrkb* Objectives: Kuparuk Well Type (exp, dev, etc): Development • Well Design (conventional, slimhole, etc): Slim hole — Injector — wp05a Current Mechanical Condition: Well Bay Footing / ODS Ground Level: Elevation above MSL: 13.5' • RKB to Ground Level: 42.66' Rig Elevation: RKB + MSL = 56.16' Conductor: 157.66' MDrkb Well Control: 13 -1/2" Surface Hole Section: • Maximum anticipated BHP: 1322 psi @ 2957'TVDss (Based on seawater gradient of 0.4472 psi /ft) • Maximum surface pressure: 997 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) 9 -7/8" Production Hole Section: • Maximum anticipated BHP: 3186 psi @ 6316' TVDss / (Based on 9.7 ppg Oooguruk - Nechelik pore pressure) • Maximum surface pressure: 2491 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) Maximum casing pressure: 4500 psi @ surface Planned BOP test pressure: 4500 psi (annular to 2500 psi) ' Due to required 4500 psi casing pressure test. Planned completion fluid: 10.2 ppg Brine /6.8 ppg Diesel Diverter (see attached schematic) — Note: Requesting Diverter Exemption on a Well by Well Basis): Hydril 21 -1/4" 2M annular BOP Pioneer Natural Resources Last Revised: November 16, 2009 ODSK -13i Permit To Drill Page 1 of 7 • • 1 16" full opening knife gate valve, hydraulically actuated 16" diverter line 5000 psi BOP stack (see attached schematic): Hydril GK 11" 5M annular BOP Hydril 11" 5M single ram BOP w/ studded connections Hydril 11" 5M single ram BOP w/ studded connections Drilling cross 11" 5M x 11" 5M with 2 ea. 3 -1/8" 5M side outlets w /flanged connections 2 ea. 3 -1/8" 5M full opening inner manual gate valves mounted on drilling cross 2 ea. 3 -1/8" 5M full opening outer remote hydraulic controlled gate valves mounted on inner gate valves. Hydril 11" 5M single ram BOP w/ studded connections Formation Integrity Testing Requirements: Test Point Depth Test Type Minimum EMW 10 -3/4" Surface Shoe Rathole + 20' to 50' from shoe LOT 12.5 ppg Drilling Fluids Program: Surface Hole Mud Properties: 13 -1/2" hole Spud Mud Interval Density (ppg) Viscosity (secs) YP PV 10 sec gel API FL Initial 8.8 150 -200 35 - 50 15 -25 10 - 15 unrestricted Final 9.2 -9.6 • 70 -100 25-35 15-25 10- 15 <12 Production Hole Mud Properties: 9 -7/8" hole LSND Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial to Base 9.2 -10.0 (-10.5 40 - 60 15 - 25 15 - 20 < 12 6 - 8 Torok ppg via MPD) From Base Torok 10.5 (-12.5 ppg 40 - 60 15 - 25 20 - 30 < 15 3 - 5 (8 -10 to TD via MPD) HTHP) Logging Program: 13 -1/2" Section: Drilling: Dir / GR Open Hole: N/A Cased Hole: N/A 9 -7/8" Section: Drilling: Mud logging Dir / GR / Res / Dens / Neut / PWD Open Hole: N/A Cased Hole: Cement Bond Log Pioneer Natural Resources Last Revised: November 16, 2009 ODSK -13i Permit To Drill Page 2 of 7 0 • Formation Markers: TVDrkb Pore Press. EMW Formation Tops MD (ft) (ft) (psi) (ppg) Comments Base of Permafrost 1711 1666 Top West Sak 2436 2281 1026 8.65 Base of fluvial sands Tuffaceous Shales 3659 2951 Brook 2b 6710 4308 Top Torok Sands 8433 5075 2270 8.6 Base Torok Sands 8920 5292 Top Hrz 9834 5698 Base Hrz 10115 5823 Kalubik Mkr 10404 5908 Kup C 10429 5963 3008 9.7 Base Kup C (LCU) 10471 5982 BCU 10829 6171 Nuiqsut 10865 6193 3123 9.7 B Nuiqsut 11002 6281 Nechelik 11017 6292 B Nechelik 11115 6360 3208 9.7 TD 11174 6402 Casing Program: Hole Casing / Weight Grade Conn. Casing CsglTbg Top Hole Btm Size Tubing Length MDrkb/TVDrkb MDrkb/TVDrkb 24" 16" 109# H -40 Welded 115' Surface 158' / 158' 13 -1/2" 10 -3/4" 45.5# L -80 BTC 3726' Surface 3769' / 3000' 9 -7/8" 7 -5/8" 29.7# L -80 BTC -M 11130' Surface 11173' / 6401' Tubing 3 -1/2" 9.3# L -80 TSHP/TCII 10780' Surface 10823' / 6165' Casing Properties Size Weight Grade ID Drift ID Conn. Internal Collapse Tensile Strength Yield (psi) (psi) Joint Body 16" 109# H -40 14.67" 14.5" Welded Conductor casing 10 -3/4" 45.5# L -80 9.950" 9.794" BTC 5210 2470 1063M 1063M 7 -5/8" 29.7# L -80 6.875" 6.75 BTC -M 6890 4790 683 M 683 M Pioneer Natural Resources Last Revised: November 16, 2009 ODSK -13i Permit To Drill Page 3 of 7 • • Cement Calculations: Casing Size: 1 10 -3/4" Surface Casing - single stage Basis: Lead: 75% excess over gauge hole in permafrost + 50 bbls, 30% excess over gauge hole below permafrost Lead TOC: Surface Tail: 500' of open hole with 30% excess, plus 85' shoe track Tail TOC: 3,269' MD Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 10.0 ppg Dual Spacer Lead 373 bbls / 504 sx of 10.92 ppg Type "L" Permafrost Cement. 4.15 cf /sk, 20.0 gps water req. Tail 50.3 bbls / 237 sx of 15.9 ppg Premium "G" + adds. 1.19 cf /sk, 5.23 gps water req. Displ 350 bbls Seawater Temp BHST -55° F, BHCT -60° F estimated Should hole conditions indicate that we will have trouble getting cement to surface, a TAM Port Collar may be run in the casing string and a staged cement job will be performed. In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casing Size: 1 7 -5/8" Intermediate Casing - single stage Basis: Lead: 438' of open hole with 60% excess TOC: - 9,929'MD - 500' MD above the top of the Kuparuk Tail: 806' of open hole with 30% excess, plus 85' shoe track • TOC: - 10,367'MD - 62' MD above the top of the Kuparuk Total Cement Volume: Preflush 10 bbl water Spacer 55 bbl 12.5 ppg Dual Spacer Lead 26.8 bbls / 63 sx Premium "G" + adds. 2.44 cf /sk, 13.74 gps Tail 44 bbls / 211 sx Premium "G" + adds. 1.17 cf /sk, 5.05 gps Displ 509 bbls mud Temp BHST - 135° F at 6068' TVDrkb, -110° F BHCT This well is outside the 1/2 mile radius around the disposal well at the intersection with the Torok disposal zone. Disposal: Annular Infection: Currently not requested, but may be requested in the future. Cuttings Handling: All Class 2 solids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1 -44. Fluid Handling: All Class 1 and Class 2 fluids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDWI -44. Pioneer Natural Resources Last Revised: November 16, 2009 ODSK -13i Permit To Drill Page 4 of 7 0 Pioneer Natural Resources Well Plan Summary Drilling Operations Pre -Rig Work 1. 16" Conductors have been set and the Well Bay modules have been placed. Rig Activity: Drill Surface Hole and Set Surface Casing 1. MIRU Nabors 19AC over pre - installed 16" conductor casing. 2. Nipple up spacer spools and riser. 3. MU 13 -1/2" Directional Drilling, MWD /LWD assembly. Drill surface hole to the casing point, making wiper trips as necessary. Circulate and condition the hole to run casing. POOH. 4. Run and cement the 10 -3/4 ", 45.5# surface casing - displace the cement with seawater. Bump the plug and bring the pressure up to 3500 psi - chart and hold for 30 minute pressure test. Send • l chart to ODE. Note: A Port Collar may be run based on hole conditions at Company Rep discretion. 5. Ensure floats are holding. WOC if needed. 6. ND spacer spools and riser 7. NU Vetco multibowl wellhead 8. RIH with enough 3 -1/2" or 2 -7/8" tubing to allow freeze protection of the well to -2000' TVD. , 9. Land the tubing and RILDS. 10. NU tree and test. 11. Circulate diesel freeze protection fluid to -2000' TVD. 12. RDMO to ODSK -14 to drill and complete that well Note: The plan is to drill and complete ODSK -14 prior to moving back onto ODSK -13i to finish drilling and completing the well. G Go d5 f / - ! o Rig Activity: Drill Production Hole, Set Production Casing and Complete 1. MIRU Nabors 19AC over ODSK -13i. RU circulation lines and circulate out the diesel freeze protection fluid and ensure the well is dead. 2. Install TWC. ND Tree and NU BOPE. 3. Re -test 10 -3/4" casing against BOPE to 3500 psi for 30 minutes C 4 D 4" drillpipe and pick up 5" drillpipe. . P e WC. Test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 6. Pull the circulation string from the well. /1 J'vy 7. MU 9 -7/8" directional drilling, MWD /L■D. RU MPD trip nipple. RIH and cleanout casing to landing collar. Displace well over to intermediate hole drilling fluid. 8. Drill through surface shoe + 20' of new hole and perform LOT to a minimum of 12.5 ppg. 9. RD the MPD trip nipple and RU the MPD bearing assembly. 10. Drill 9 -7/8" intermediate hole to casing point. 11. Circulate and condition the hole to run 7 -5/8" casing. Displace the well over to -12.5 ppg drilling fluid for shale stability reasons. 12. RD MPD bearing assembly and RU trip nipple. 13. POH standing back 5" DP. 14. Change one set of pipe rams to 7 -5/8" and test BOPE as required. 15. Run and cement the 7 -5/8 ", 29.7# intermediate casing. Pioneer Natural Resources Last Revised: November 16, 2009 ODSK -13i Permit To Drill Page 5 of 7 16. Bump the plug and bring pressure up to 45009si - chart and hold pressure for 30 minutes for intermediate casing pressure test. Send the chart to the ODE. Release pressure and ensure floats are holding. 17. LD5 "DP. 18. Change rams over to 4" and test BOPE to 250/4500 psi. 19. PU and stand back 4" DP in the derrick for an upcoming scraper run. 20. RU HES E -line. Run a cement bond log from PBTD to TOC. RU and run perforating guns and • perforate over the Kuparuk interval. POH and RD HES E -line. 21. MU Scraper BHA on 4" DP and RIH past the Kuparuk perforations. POH laying down 4" DP. 22. Change pipe rams to 3 -1/2" and Test BOPE to 250/4500 psi 23. RIH with 3 -1/2" straddle packer completion. 24. Land the tubing and RILDS. 25. Drop ball and rod, pressure up on the tubing to set packers. Increase pressure to perform pressure test of the tubing to 4500 psi. Pressure test 3 -1/2" to 7 -5/8" annulus to 4,500 psi. 26. Install TWC. 27. ND BOPE, NU tree and test to 5,000 psi. 28. Pull TWC. 29. Reverse circulate 4500' of freeze protection fluid down 3 -1/2" tubing annulus through gas lift mandrel shear out valve. 30. RU Slickline / E -line Unit 31. Pull the ball and rod. 32. Pull the shear out valve from the upper GLM. 33. RIH and set dummy valve in upper GLM 34. Pull the dummy valves from the Water Flood Mandrels. 35. Pull the RHC -m plug. 36. RD Slickline / E -line Unit. 37. RDMO to next well. Post -Rig Activity Prior to Injection: 1 1. Perform MITIA, contact AOGCC slope representative 48 hrs prior to test for potential witness of test. 2. RU Slickline / E -line Unit. 3. Set valve catcher in lowest X nipple. 4. Insert water injection valves in water flood mandrels, pull valve catcher. 5. Turn the well over to injection into the Kuparuk interval. Long Term completion: Following State approval for co- mingled injection 1. RU Slickline / E -line Unit 2. Set valve catcher in lowest X nipple. 3. Insert dummy valves in the Flood Mandrels 4. RIH and perforate the Nuiqsut formation. 5. Pull the dummy valves from the Water Flood Mandrels and install orifice valves. 6. RD Slickline / E -line 7. Commence injection as a Dual Injector into the Kuparuk and the Nuiqsut formations Pioneer Natural Resources Last Revised: November 16, 2009 ODSK -13i Permit To Drill Page 6 of 7 • • ODSK -13i Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • Prior to drilling into the Kuparuk, hold a pre - reservoir meeting to outline heightened awareness for kick detection and lost circulation. o Following the Kuparuk penetration, pick up off bottom, shut off the pumps and perform a flow check to verify there isn't any overpressure. Hydrates and Shallow gas • No hydrates are expected in this area. 1 Lost Circulation /Breathing /Formation Stability /Stuck Pipe Events • Breathing may be seen while drilling the Hue shale. Minimizing swab and surge on the formation is critical to reducing the impact of breathing in the wellbore. Breathing was seen in the ODSN -40 well, but only after substantial time in trying to solve the lost circulation problems in the fault seen in and below the Torok Sands. • Lost Circulation was seen in drilling the ODSN -36 across this same interval. Review the DOB2C pill procedure prior to penetrating the Kuparuk. Follow the Lost Circulation Decision Tree and combat losses accordingly • During the attempt to retrieve a fish from the ODSK -33 well, an un- centralized BHA got stuck from differential sticking across the Torok due to the increase in mud weight needed to hold back the shales below. Differential sticking indications were not noted with the drilling BHA and drill pipe. In any event, keep the pipe moving and avoid allowing the pipe to remain stationary any longer than necessary to minimize the chances of differential sticking. • There is a small section of formation above the Top of the HRZ that is volcanic in nature (TUFFS) and can either have "glassy" material, swelling clays or both while drilling, which produced a pack off on ODSK -33 and ODSN -45 - close attention while drilling this interval is advised. Kick Tolerance /Integrity Testing Kick Tolerance / Integrity Testing Summary Table Casing set / Maximum Mud Weight Exp Pore Min LOT / FIT Interval Influx Volume Press Surface 33.2 10.5 ppg 3229 12.5 ppg (LOT) ( -12.5 ppg via MPD) NOTE: All LOT / FIT will be taken with a minimum of 20 -ft and a maximum of 50 -ft of new hole drilled outside of the previous casing string Hydrogen Sulfide • The Oooguruk Drill Site is not designated as an H site, however Standard Operating i Procedures for H precautions should be followed at all times. Faults • Sub seismic faults with throws <25' may be encountered. Losses may be associated with these faults. Pioneer Natural Resources Last Revised: November 16, 2009 ODSK -13i Permit To Drill Page 7 of 7 1 1 ODSK -13i Kup H, Kuparuk Injection Well - Draft Well Head: 10 -3/4 ", 5K, VetcoGray Tree: 3 -1/2 ", 5K, Horizontal AIK 16" Conductor 153' MDrkb / 153' TVDrkb 3 -1/2" ScSSSV, 2.813" ID @ 754' MDrkb / 754' TVDrkb h %3 ' x 10 -3/4 ", 45.5# L -80 BTC, 9.95" ID 3769' MDrkb / 3000' TVDrkb 3 -1/2" MMG GLM @ 4500' MDrkb / 3325' TVDrkb 1 1 /2: Dummy Valve 3 -1/2 ", 9.3# L -80 TCII 3 -1/2" MMG GLM @ 9400' MDrkb / 5505' TVDrkb TOC @ 9930' MDrkb 1 '' /z: Dummy Valve Down hole Pressure Gauge 10240' MDrkb , 7 -5/8" Ultra Pak TH Permanent Packer X Nipple, 2.813" ID ■ @ 10300' MDrkb / 5905 TVDrkb 10270' MDrkb 0_ M Waterflood Mandrel Perforations 10430' MDrkb / 5963' TVDrkb ,-;,7- -,i___ from 10430' MDrkb / 5963' TVDrkb to 10472 MDrkb / 5982' TVDrkb Waterflood Mandrel ..._, 6 spf @ 60 degree phasing 10470' MDrkb / 5982' TVDrkb J X Nipple, 2.813" ID w /RHC -M Plug 7 -5 /8" Ultra Pak TH Permanent Packer 10726' MDrkb @ 10700' MDrkb / 6095' TVDrkb ■ XN Nipple, 2.725" ID Nogo ■ Long Term Perforations (following approval for +- 10808' MDrkb commingled injection) ,ice from 10869' MDrkb / 6194' TVDrkb to 11006' MDrkb / 6283' TVDrkb WLEG @ 10823' MDrkb 6 spf @ 60 degree phasing PBTD @ 11088' MDrkb 7 -5/8 ", 29.7# L -80 BTC -M, 6.875" ID iii■ 11173' MDrkb / 6401' TVDrkb Date: Revision By: Comments PIONE 10/13/2008 James Franks Proposed Completion ODSK -13i Injector NATURAL RESOURCES ' Well Schematic Version 1.0 Pioneer Natural Resources Alaska Cementing Services ODSK -13i coal.. uruk EXECUTIVE SUMMARY Assumptions: This design is based on WP 5. 10 -3/4" SURFACE CASING SUMMARY The slurry design volumes are based on bring cement to surface and 500' of tail cement with 75% excess in the permafrost plus 50 bbls and 30% below the permafrost. Fluid Summary 10 bbl Water Spacer 40 bbl Dual Spacer 372 bbl (504 sk) Type L Permafrost Cement mixed at 10.7 ppg 50.3 bbl (237 sk) Premium Cement with 2% Calcium Chloride mixed at 15.9 ppg 354 bbl Mud Displacement V ECD Program based on 3,769' of fill and a frac. gradient of 13.9 ppg 3,769' MD / 3,000' TVD. Lead Slurry Fill Tail Slurry Fill ECD 3,269' 500' N 12.7 ppg 7 -5/8" PRODUCTION CASING SUMMARY The well is located outside of the '/2 mile radius of the disposal well so cement does not need to cover the disposal zone. The slurry design volumes are based on bringing the lead cement 500' above the Kuparuk (60% excess) and the tail cement 500' above the Nuiqsut (30% excess). Fluid Summary 10 bbl Water Spacer 55 bbl Dual Spacer 26.8 bbl (63 sk) Premium Cement+ 15 # /sk MicroLite, + 0.75% Halad -344 + .2% CFR -3, + 0.15% EZ Flow + 0.25% SCR -100 or as required 44 bbl (211 sk) Premium Cement+ 0.5% Halad -344 + .2% CFR -3, + 0.25 LB /SK. Super CBL+ 0.5% SCR -100 or as required mixed at 15.8 ppg 509 bbl Mud Displacement ECD Program based on 1,244' of fill and a frac. gradient of 13.0 ppg 11,173' MD / 6,400' TVD. Lead Slurry Fill Tail Slurry Fill ECD 438' 806' \I 12.9 ppg HALLIBURRTON 3 s 1 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -13i - Slot ODS -13 ODSK -13i KupH Plan: ODSK -13i KupH wp05.a Standard Proposal Report 04 November, 2009 r MINIMMI . 1 1 HALLIBURTON l Sperry Drilling Services 1) 1 • ' WELL DETAIL REFERENCE LNFORMATION i MAL.LIBUi�`TdfV S ODSK -13i Co-ordinate (N/E) Reference: well ODSK -13i - Slot ODS -13, True North Ground Level: 13.5 Vertical (TVD) Reference: 42.7' + 13.5' @ 56 28 (Nabors 19AC) NATURAL RESOURC -4 Spert'V Or'11llrty +N / -S +E / -W Northing Easting Latittude Longitude Slot Measured Depth Reference: 42.T +13.5'@ 56.2ft (Naborsl9AC) 0.0 0.0 6031076.06 469845.81 70° 29' 45.498 N 150° 14' 47.653 W ODS -13 Calculation Method: Minimum Curvature COMPANY DETAILS: Well Planning - Pioneer - Oooguruk WELLBORE TARGET DETAILS (MAP CO-ORDINATES) Project: Oooguruk Development Calculation Method: Minimum Curvature Site: Oooguruk k Drill Site Name TVD +N / -S +E / -W Northing Easting Shape Error System: ISCWSA g KupHi v5 T1 5963.2 6475.7 - 4181.5 6037568.00 465691.00 Circle (Radius: 200.0) Scan Method: Tray. Cylinder North Well: ODSK -13i Error Surface: Elliptical Conic Wellbore: ODSK -13i KupH Warning Method: Rules Based Plan: ODSK -13i KupH wp05.a - 600 _ SECTION DETAILS - / CASING DETAILS t =� Start Dir 1.00/100' 300.00' MD, 300.00' TVD Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target 1 42.7 0.00 0.00 42.7 0.0 0.0 0.00 0.00 0.0 0 - TVD MD Name Size . - - - - 2 300.0 0.00 0.00 300.0 0.0 0.0 0.00 0.00 0.0 - 3000.0 3769.4 10 3/4" 10.750 _ - - - - Start Dir 2.00/100' 600.00' MD, 599.90' TVD 3 600.0 3.00 305.00 599.9 4.5 -6.4 1.00 305.00 7.3 6400.8 11173.0 7 5/8" 7.625 - - 4 750.0 6.00 305.00 749.4 11.3 -16.1 2.00 0.00 18.2 _ _ - _ _ - - - - 5 1016.7 14.00 305.00 1011.8 37.8 -54.0 3.00 0.00 61.0 ID 600 Start Dir 3.00/100' 750.00' MD, 749.40' TVD 6 1692.8 24.14 305.00 1650.0 164.3 -234.7 1.50 0.00 265.1 7 1802.4 24.14 305.00 1750.0 190.1 -271.4 0.00 0.00 306.6 - 8 3210.1 63.58 329.07 2751.2 929.7 -858.1 3.00 32.92 1245.9 - - - - - Start Dir 1.501100' 1016.70' MD, 1011.80' TVD 9 10429.6 63.58 329.07 5963.2 6475.7 - 4181.5 0.00 0.00 7708.4 KupHi v5 T1 1200- 10 10472.3 63.58 329.07 5982.2 6508.5 - 4201.2 0.00 0.00 7746.6 20° 11 11173.5 42.55 329.07 6401.2 6986.6 - 4487.7 3.00 180.00 8303.7 - End Dir 1692.80' MD, 1650.00' TVD Base of Permafrost - - - 1800- - -- - - -- -- - - _ _ FORMATION TOP DETAILS - Start Dir 3.0/100' 1802.40' MD, 1750.00' TVD _ D� TVDPath TVDssPath MDPath Formation - 1666.2 1610.0 1710.6 Base of Permafrost c 2400- - End Dir 3210.10' MD, 2751.20' TVD 2281.2 2225.0 2435.1 Top West Sak O _ _ _ - 2951.2 2895.0 3659.7 Tuffaceous Shales c) Top W est Sak _ _ 4308.2 4252.0 6709.7 Book 2b O - p - - 5075.2 5019.0 8433.7 Top Torok 1.0 -- 10 3/4" 5292.2 5236.0 8921.4 Base Torok 3000 -- DDI = 6.11 . 5698.2 5642.0 9834.0 Top HRZ 5823.2 5767.0 10114.9 Base HRZ o- - 5908.2 5852.0 10306.0 Kalubik Marker N _ 5963.2 5907.0 10429.6 Kup C O 3600 - 5982.2 5926.0 10472.3 Base Kup C (LCU) 0 Tuffaceous Shales 6193.2 6137.0 10867.4 Top Nuiqsut C - 6281.2 6225.0 11003.4 Base Nuiqsut > 4200 - i 6292.2 6236.0 11019.7 Top Nechelik 0) - 6359.2 6303.0 11115.7 Base Nechelik D - Book 2b • 4800- Start Dir 3.0/100' 10472.30' MD, 5982.20' TVD H Top Torok _ I KupHi v5 T1 End Dir 11173.50' MD, 6401.20' TVD 5400 - Base Torok - Total Depth at 11173.50' MD, 6401.20' TVD _ Top HRZ - 6000 - - - _ Base HRZ - - --' ,<P Kalubik Marker - ,,' i - - 75/8" 6600 Kup C BCU SURVEY PROGRAM , ' B ase Nechelik Base Kup C (LCU) 7200- - - Date: 2009- 11- 04T00:00:00 Validated: Yes Version: Top Nuiqsut Top Necheli ODSK -13i KupH wp05.a - Depth From Depth To Survey /Plan Tool 42.7 1500.0 ODSK -131 KupH wp05.a SR- Gyro-SS Base Nuiqsut 7800 - 1500.0 11173.5 ODSK- 13i KupH wp05.a MWD +IFR2 +MS +sag - - 111111 - - : - I gilli1111111111111111 _ 1111111111111111HI T T IIIIIIIIII IIIIIIIIHIII 11 IIFt1IIII11111H 11 , 7 IIIIIII1IT - 3000 - 2400 - 1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 Vertical Section at 327.29° (1500 ft/in) PIONEER HALLIBURTON WELL DETAILS: ODSK -13i REFERENCE INFORMATION Ground Level: 13.5 Co- ordinate (WE) Reference: Well ODSK -13i - Slot ODS -13, True North Sperry Drilling +N / -S +E/ -W Northing Fasting Latittude Longitude Slot ea ered (TVD) Reference: 42.T+ 13.5' @ 56.2 (Nabors 19AC) 0.0 0.0 603107606 469845.81 70° 29' 45.498 N 150° 14' 47.653 W ODS -13 Measured Depth Reference: 42.7' + 13.5 @ 56.26 (Nabors 19AC) - - - - -- Caiculaton Method: Minimum Curvature WELLBORE TARGET DETAILS (MAP CO-ORDINATES) COMPANY DETAILS: Well Planning - Pioneer - Ooogunik Proje Name TVD +N / -S +E / -W Northing Easting Shape Calculation Method: Minimum Curvature PCO j Oooguruk Development KupHi v5 T1 5963.2 6475.7 - 4181.5 6037568.00 465691.00 Circle (Radius: 200.0) Error System: ISCWSA Site: Oooguruk Drill Site Scan Method: Tray. Cylinder North Error Surface: Elliptical Conic Well: ODSK -13, W arcing Method: Rules Based Wellbore: ODSK -13i KupH Plan: ODSK -13i KupH wp05.a SURVEY PROGRAM Total Depth at 11173.50' MD, 6401.20' TVD Date: 2009- 11- 04T00:00:00 Validated: Yes Version: ODSK -13i KupH wp05.a 'End Dir 7 5/8" 11173.50' MD, 6401.20' TVD Depth From Depth To Survey /Plan Tool 7200 -- 42.7 1500.0 ODSK -13i KupH wp05.a SR- Gyro -SS - - _ 1500.0 11173.5 ODSK -13i KupH wp05.a MWD +IFR2 +MS +sag _ :DD Target 95 DDI = 6.11 6600 - iek__._ - v - Start Dir 3.0/100' 10472.30' MD, 5982.20' TVD SECTION DETAILS _ KupHi v5 Ti Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target 6000- 1 42.7 0.00 0.00 42.7 0.0 0.0 0.00 0.00 0.0 2 300.0 0.00 0.00 300.0 0.0 0.0 0.00 0.00 0.0 5 500 3 600.0 3.00 305.00 599.9 4.5 -6.4 1.00 305.00 7.3 4 750.0 6.00 305.00 749.4 11.3 -16.1 2.00 0.00 18.2 5400 - 5 1016.7 14.00 305.00 1011.8 37.8 -54.0 3.00 0.00 61.0 6 1692.8 24.14 305.00 1650.0 164.3 -234.7 1.50 0.00 265.1 7 1802.4 24.14 305.00 1750.0 190.1 -271.4 0.00 0.00 306.6 - 0 8 3210.1 63.58 329.07 2751.2 929.7 -858.1 3.00 32.92 1245.9 4800 - S� 9 10429.6 63.58 329.07 5963.2 6475.7 - 4181.5 0.00 0.00 7708.4 KupHi v5 T1 10 10472.3 63.58 329.07 5982.2 6508.5 - 4201.2 0.00 0.00 7746.6 11 11173.5 42.55 329.07 6401.2 6986.6 - 4487.7 3.00 180.00 8303.7 C 0 4200 -- 0 _ N g0 0 in CASING DETAILS "3600- TVD MD Name Size • = 3000.0 3769.4 10 3/4" 10.750 p _ 6400.8 11173.0 7 5/8" 7.625 p0 00 '7 3000 - -E. - - 0 cA 2400- - End Dir 3210.10' MD, 2751.20' TVD yS Start Dir 3.0 /100' 1802.40' MD, 1750.00' TVD 1800 - / End Dir 1692.80' MD, 1650.00' TVD 103/4 "___,5000 / '' Start Dir 1.50 /100' 1016.70' MD, 1011.80' TVD 1200 _ Staff Dir 3.00 /100' 750.00' MD, 749.40' TVD 600- tiS ip � - Start Dir 2.00/100' 600.00' MD, 599.90' TVD - ti - - - - - _ .- _ Start Dir 1.00 /100' 300.00' MD, 300.00' TVD 0- ._- - - 600 - - ill i I! I I I I I I I I I I I I I I l i l l l l l iiiililiiiiilll lip' li i -6000 -5400 -4800 -4200 -3600 -3000 -2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 West( -) /East( +) (1500 ft/in) I • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSK - 13i - Slot ODS - 13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' © 56.2ft (Nabors 19AC) Site Oooguruk Drill Site North Reference: True Well: ODSK -13i Survey Calculation Method: Minimum Curvature Weiibore: ODSK -13i KupH Design: ODSK -13i KupH wp05.a Project Oooguruk Development 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 Oooguruk Drill Site Site Position: Northing: 6,031,151.32ft Latitude: 70° 29' 46.242 N From: Map Easting: 469,920.45ft Longitude: 150° 14' 45.465 W' Position Uncertainty: 0.0 ft Slot Radius: in Grid Convergence: - 0.23 ? Well ODSK - 13i - Slot ODS - 13 Well Position +N / - 0.0 ft Northing: 6,031,076.06ft • Latitude: 70° 29' 45.498 N +E / - 0.0 ft Easting: 469,845.81 ft • Longitude: 150° 14' 47.653 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft • Wellbore ODSK - 13i KupH Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) ( ?) (nT) IGRF200510 4/14/2009 22.31 80.81 57,730 Design ODSK -13i KupH wp05.a Audit Notes: Version: Phase: PLAN Tie On Depth: 42.7 Vertical Section: Depth From (TVD) +NI-S +E/ -W Direction (ft) (ft) (ft) ( ?) 42.7 0.0 0.0 327.29 I Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azlm th Dept SyStem +NI-S +E/-W Rate Rate Rate Tool Face (ft) ( ?) ( ?) (ft) ' ft (ft) (ft) ( ?I100ft) ( ?/100ft) ( ?/100ft) ( ?) 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 0.00 0.00 0.00 0.00 300.0 0.00 0.00 300.0 243.8 0.0 0.0 0.00 0.00 0.00 0.00 600.0 3.00 305.00 599.9 543.7 4.5 -6.4 1.00 1.00 0.00 305.00 750.0 6.00 305.00 749.4 693.2 11.3 -16.1 2.00 2.00 0.00 0.00 1,016.7 14.00 305.00 1,011.8 955.6 37.8 -54.0 3.00 3.00 0.00 0.00 1,692.8 24.14 305.00 1,650.0 1,593.8 164.3 -234.7 1.50 1.50 0.00 0.00 1,802.4 24.14 305.00 1,750.0 1,693.8 190.1 -271.4 0.00 0.00 0.00 0.00 3,210.1 63.58 329.07 2,751.2 2,695.0 929.7 -858.1 3.00 2.80 1.71 32.92 10,429.6 63.58 329.07 5,963.2 5,907.0 6,475.7 - 4,181.5 0.00 0.00 0.00 0.00 10,472.3 63.58 329.07 5,982.2 5,926.0 6,508.5 - 4,201.2 0.00 0.00 0.00 0.00 11,173.5 42.55 329.07 6,401.2 6,345.0 6,986.6 - 4,487.7 3.00 -3.00 0.00 180.00 11/4/2009 10:25:57AM Page 2 COMPASS 2003.16 Build 42 Halliburton Company HALL1BURTON Standard Proposal Report Database: .Pioneer Alaska Local Co - ordinate Reference: Well ODSK -13i - Slot ODS -13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7 + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK - 13i Survey Calculation Method: Minimum Curvature Welibore: ODSK -13i KupH Design: ODSK -13i KupH wp05.a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N /-S +E/ -W Northing Easting DLS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) -13.50 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 6,031,076.06 469,845.81 0.00 0.00 100.0 0.00 0.00 100.0 43.8 0.0 0.0 6,031,076.06 469,845.81 0.00 0.00 200.0 0.00 0.00 200.0 143.8 0.0 0.0 6,031,076.06 469,845.81 0.00 0.00 300.0 0.00 0.00 300.0 243.8 0.0 0.0 6,031,076.06 469,845.81 0.00 0.00 Start Dir 1.00/100' 300.00' MD, 300.00' TVD 400.0 1.00 305.00 400.0 343.8 0.5 -0.7 6,031,076.56 469,845.10 1.00 0.81 500.0 2.00 305.00 500.0 443.8 2.0 -2.9 6,031,078.07 469,842.96 1.00 3.23 600.0 3.00 305.00 599.9 543.7 4.5 -6.4 6,031,080.59 469,839.40 1.00 7.27 Start Dir 2.00/100' 600.00' MD, 599.90' TVD 700.0 5.00 305.00 699.6 643.4 8.5 -12.1 6,031,084.61 469,833.70 2.00 13.72 750.0 6.00 305.00 749.4 693.2 11.3 -16.1 6,031,087.38 469,829.79 2.00 18.15 Start Dir 3.00/100' 750.00' MD, 749.40' TVD 800.0 7.50 305.00 799.0 742.8 14.6 -20.9 6,031,090.77 469,824.99 3.00 23.59 900.0 10.50 305.00 897.8 841.6 23.6 -33.7 6,031,099.79 469,812.21 3.00 38.06 1,000.0 13.50 305.00 995.6 939.4 35.5 -50.7 6,031,111.78 469,795.23 3.00 57.30 1,016.7 14.00 305.00 1,011.8 955.6 37.8 -54.0 6,031,114.07 469,792.00 3.00 60.97 Start Dir 1.50/100' 1016.70' MD, 1011.80' TVD 1,100.0 15.25 305.00 1,092.4 1,036.2 49.9 -71.2 6,031,126.20 469,774.81 1.50 80.44 1,200.0 16.75 305.00 1,188.5 1,132.3 65.7 -93.8 6,031,142.10 469,752.30 1.50 105.94 1,300.0 18.25 305.00 1,283.9 1,227.7 82.9 - 118.4' 6,031,159.45 469,727.74 1.50 133.76 1,400.0 19.75 305.00 1,378.5 1,322.3 101.6 -145.1 6,031,178.23 469,701.15 1.50 163.89 1,500.0 21.25 305.00 1,472.1 1,415.9 121.7 -173.8 6,031,198.43 469,672.55 1.50 196.29 1,600.0 22.75 305.00 1,564.8 1,508.6 143.2 -204.5 6,031,220.04 469,641.96 1.50 230.95 1,692.8 24.14 305.00 1,650.0 1,593.8 164.3 -234.7 6,031,241.34 469,611.79 1.50 265.13 End Dir 1692.80' MD, 1650.00' TVD 1,700.0 24.14 305.00 1,656.5 1,600.3 166.0 -237.1 6,031,243.03 469,609.39 0.00 267.84 1,710.6 24.14 305.00 1,666.2 1,610.0 168.5 -240.7 6,031,245.53 469,605.86 0.00 271.85 Base of Permafrost 1,800.0 24.14 305.00 1,747.8 1,691.6 189.5 -270.6 6,031,266.63 469,575.99 0.00 305.69 1,802.4 24.14 305.00 1,750.0 1,693.8 190.1 -271.4 6,031,267.20 469,575.18 0.00 306.60 Start Dir 3.0/100' 1802.40' MD, 1750.00' TVD 1,900.0 26.64 308.55 1,838.2 1,782.0 215.1 -304.9 6,031,292.42 469,541.82 3.00 345.80 2,000.0 29.29 311.59 1,926.5 1,870.3 245.4 -340.7 6,031,322.77 469,506.11 3.00 390.59 2,100.0 31.98 314.16 2,012.5 1,956.3 280.1 -378.0 6,031,357.61 469,468.95 3.00 439.94 2,200.0 34.73 316.37 2,096.0 2,039.8 319.1 -416.7 6,031,396.84 469,430.45 3.00 493.71 2,300.0 37.51 318.29 2,176.8 2,120.6 362.5 -456.6 6,031,440.35 469,390.72 3.00 551.76 2,400.0 40.31 319.98 2,254.6 2,198.4 410.0 -497.7 6,031,488.03 469,349.85 3.00 613.93 2,435.1 41.30 320.53 2,281.2 2,225.0 427.6 -512.3 6,031,505.73 469,335.25 3.00 636.70 Top West Sak 2,500.0 43.14 321.49 2,329.3 2,273.1 461.5 -539.8 6,031,539.73 469,307.97 3.00 680.04 2,600.0 45.98 322.85 2,400.5 2,344.3 517.0 -582.8 6,031,595.32 469,265.18 3.00 749.92 2,700.0 48.84 324.08 2,468.2 2,412.0 576.1 -626.6 6,031,654.65 469,221.61 3.00 823.37 2,800.0 51.72 325.20 2,532.1 2,475.9 638.8 -671.1 6,031,717.56 469,177.38 3.00 900.20 2,900.0 54.60 326.25 2,592.0 2,535.8 705.0 -716.1 6,031,783.86 469,132.60 3.00 980.19 3,000.0 57.49 327.22 2,647.9 2,591.7 774.3 -761.6 6,031,853.39 469,087.40 3.00 1,063.12 11/4/2009 10:25:57AM Page 3 COMPASS 2003.16 Build 42 • 1 1110 Halliburton Company HA LL1BURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK - 13i - Slot ODS - 13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK - 13i Survey Calculation Method: Minimum Curvature Wellbore: ODSK -13i KupH Design: ODSK -13i KupH wp05.a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/ -W Northing Easting DLS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) 2,643.26 3,100.0 60.39 328.13 2,699.5 2,643.3 846.7 -807.4 6,031,925.95 469,041.91 3.00 1,148.77 3,200.0 63.29 328.98 2,746.7 2,690.5 921.9 -853.4 6,032,001.33 468,996.24 3.00 1,236.90 3,210.1 63.58 329.07 2,751.2 2,695.0 929.7 -858.1 6,032,009.10 468,991.62 3.00 1,245.93 End Dir 3210.10' MD, 2751.20' TVD 3,300.0 63.58 329.07 2,791.2 2,735.0 998.7 -899.4 6,032,078.32 468,950.52 0.00 1,326.40 3,400.0 63.58 329.07 2,835.7 2,779.5 1,075.5 -945.5 6,032,155.32 468,904.80 0.00 1,415.91 3,500.0 63.58 329.07 2,880.1 2,823.9 1,152.4 -991.5 6,032,232.32 468,859.08 0.00 1,505.43 3,600.0 63.58 329.07 2,924.6 2,868.4 1,229.2 - 1,037.5 6,032,309.32 468,813.36 0.00 1,594.94 3,659.7 63.58 329.07 2,951.2 2,895.0 1,275.0 - 1,065.0 6,032,355.28 468,786.07 0.00 1,648.38 Tuffaceous Shales 3,700.0 63.58 329.07 2,969.1 2,912.9 1,306.0 - 1,083.6 6,032,386.31 468,767.65 0.00 1,684.46 3,769.4 63.58 329.07 3,000.0 2,943.8 1,359.3 - 1,115.5 6,032,439.74 468,735.92 0.00 1,746.57 10 3/4" 3,800.0 63.58 329.07 3,013.6 2,957.4 1,382.8 - 1,129.6 6,032,463.31 468,721.93 0.00 1,773.97 3,900.0 63.58 329.07 3,058.1 3,001.9 1,459.6 - 1,175.6 6,032,540.31 468,676.21 0.00 1,863.48 4,000.0 63.58 329.07 3,102.6 3,046.4 1,536.5 - 1,221.7 6,032,617.31 468,630.49 0.00 1,953.00 4,100.0 63.58 329.07 3,147.1 3,090.9 1,613.3 - 1,267.7 6,032,694.31 468,584.77 0.00 2,042.51 4,200.0 63.58 329.07 3,191.6 3,135.4 1,690.1 - 1,313.8 6,032,771.31 468,539.05 0.00 2,132.03 4,300.0 63.58 329.07 3,236.1 3,179.9 1,766.9 - 1,359.8 6,032,848.30 468,493.34 0.00 2,221.54 4,400.0 63.58 329.07 3,280.6 3,224.4 1,843.7 - 1,405.8 6,032,925.30 468,447.62 0.00 2,311.06 4,500.0 63.58 329.07 3,325.1 3,268.9 1,920.6 - 1,451.9 6,033,002.30 468,401.90 0.00 2,400.57 4,600.0 63.58 329.07 3,369.6 3,313.4 1,997.4 - 1,497.9 6,033,079.30 468,356.18 0.00 2,490.08 4,700.0 63.58 329.07 3,414.0 3,357.8 2,074.2 - 1,543.9 6,033,156.30 468,310.46 0.00 2,579.60 4,800.0 63.58 329.07 3,458.5 3,402.3 2,151.0 - 1,590.0 6,033,233.30 468,264.75 0.00 2,669.11 4,900.0 63.58 329.07 3,503.0 3,446.8 2,227.8 - 1,636.0 6,033,310.30 468,219.03 0.00 2,758.63 5,000.0 63.58 329.07 3,547.5 3,491.3 2,304.7 - 1,682.0 6,033,387.29 468,173.31 0.00 2,848.14 5,100.0 63.58 329.07 3,592.0 3,535.8 2,381.5 - 1,728.1 6,033,464.29 468,127.59 0.00 2,937.66 5,200.0 63.58 329.07 3,636.5 3,580.3 2,458.3 - 1,774.1 6,033,541.29 468,081.87 0.00 3,027.17 5,300.0 63.58 329.07 3,681.0 3,624.8 2,535.1 - 1,820.1 6,033,618.29 468,036.15 0.00 3,116.68 5,400.0 63.58 329.07 3,725.5 3,669.3 2,611.9 - 1,866.2 6,033,695.29 467,990.44 0.00 3,206.20 5,500.0 63.58 329.07 3,770.0 3,713.8 2,688.8 - 1,912.2 6,033,772.29 467,944.72 0.00 3,295.71 5,600.0 63.58 329.07 3,814.5 3,758.3 2,765.6 - 1,958.2 6,033,849.29 467,899.00 0.00 3,385.23 5,700.0 63.58 329.07 3,859.0 3,802.8 2,842.4 - 2,004.3 6,033,926.28 467,853.28 0.00 3,474.74 5,800.0 63.58 329.07 3,903.4 3,847.2 2,919.2 - 2,050.3 6,034,003.28 467,807.56 0.00 3,564.25 l 5,900.0 63.58 329.07 3,947.9 3,891.7 2,996.0 - 2,096.3 6,034,080.28 467,761.85 0.00 3,653.77 6,000.0 63.58 329.07 3,992.4 3,936.2 3,072.9 - 2,142.4 6,034,157.28 467,716.13 0.00 3,743.28 6,100.0 63.58 329.07 4,036.9 3,980.7 3,149.7 - 2,188.4 6,034,234.28 467,670.41 0.00 3,832.80 6,200.0 63.58 329.07 4,081.4 4,025.2 3,226.5 - 2,234.4 6,034,311.28 467,624.69 0.00 3,922.31 6,300.0 63.58 329.07 4,125.9 4,069.7 3,303.3 - 2,280.5 6,034,388.28 467,578.97 0.00 4,011.83 6,400.0 63.58 329.07 4,170.4 4,114.2 3,380.1 - 2,326.5 6,034,465.27 467,533.26 0.00 4,101.34 6,500.0 63.58 329.07 4,214.9 4,158.7 3,457.0 - 2,372.6 6,034,542.27 467,487.54 0.00 4,190.85 6,600.0 63.58 329.07 4,259.4 4,203.2 3,533.8 - 2,418.6 6,034,619.27 467,441.82 0.00 4,280.37 6,700.0 63.58 329.07 4,303.9 4,247.7 3,610.6 - 2,464.6 6,034,696.27 467,396.10 0.00 4,369.88 6,709.7 63.58 329.07 4,308.2 4,252.0 3,618.1 - 2,469.1 6,034,703.77 467,391.64 0.00 4,378.61 Book 2b 11/4/2009 10:25:57AM Page 4 COMPASS 2003.16 Build 42 • • Halliburton Company HALL1BURTON Standard Proposal Report Database: .Pioneer Alaska Local Co Reference: Well ODSK -13i - Slot ODS -13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) Project Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK - 13i Survey Calculation Method: Minimum Curvature Wellbore: ODSK -13i KupH Design: ODSK -13i KupH wp05.a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/ -W Northing Fasting DLS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) 4,292.15 6,800.0 63.58 329.07 4,348.4 4,292.2 3,687.4 - 2,510.7 6,034,773.27 467,350.38 0.00 4,459.40 6,900.0 63.58 329.07 4,392.8 4,336.6 3,764.2 - 2,556.7 6,034,850.27 467,304.66 0.00 4,548.91 7,000.0 63.58 329.07 4,437.3 4,381.1 3,841.1 - 2,602.7 6,034,927.26 467,258.95 0.00 4,638.42 7,100.0 63.58 329.07 4,481.8 4,425.6 3,917.9 - 2,648.8 6,035,004.26 467,213.23 0.00 4,727.94 7,200.0 63.58 329.07 4,526.3 4,470.1 3,994.7 - 2,694.8 6,035,081.26 467,167.51 0.00 4,817.45 7,300.0 63.58 329.07 4,570.8 4,514.6 4,071.5 - 2,740.8 6,035,158.26 467,121.79 0.00 4,906.97 7,400.0 63.58 329.07 4,615.3 4,559.1 4,148.3 - 2,786.9 6,035,235.26 467,076.07 0.00 4,996.48 7,500.0 63.58 329.07 4,659.8 4,603.6 4,225.2 - 2,832.9 6,035,312.26 467,030.36 0.00 5,086.00 7,600.0 63.58 329.07 4,704.3 4,648.1 4,302.0 - 2,878.9 6,035,389.26 466,984.64 0.00 5,175.51 7,700.0 63.58 329.07 4,748.8 4,692.6 4,378.8 - 2,925.0 6,035,466.25 466,938.92 0.00 5,265.02 7,800.0 63.58 329.07 4,793.3 4,737.1 4,455.6 - 2,971.0 6,035,543.25 466,893.20 0.00 5,354.54 7,900.0 63.58 329.07 4,837.8 4,781.6 4,532.4 - 3,017.0 6,035,620.25 466,847.48 0.00 5,444.05 8,000.0 63.58 329.07 4,882.2 4,826.0 4,609.3 - 3,063.1 6,035,697.25 466,801.76 0.00 5,533.57 8,100.0 63.58 329.07 4,926.7 4,870.5 4,686.1 - 3,109.1 6,035,774.25 466,756.05 0.00 5,623.08 8,200.0 63.58 329.07 4,971.2 4,915.0 4,762.9 - 3,155.1 6,035,851.25 466,710.33 0.00 5,712.59 8,300.0 63.58 329.07 5,015.7 4,959.5 4,839.7 - 3,201.2 6,035,928.25 466,664.61 0.00 5,802.11 8,400.0 63.58 329.07 5,060.2 5,004.0 4,916.5 - 3,247.2 6,036,005.24 466,618.89 0.00 5,891.62 8,433.7 63.58 329.07 5,075.2 5,019.0 4,942.4 - 3,262.7 6,036,031.18 466,603.49 0.00 5,921.78 Top Torok 8,500.0 63.58 329.07 5,104.7 5,048.5 4,993.4 - 3,293.2 6,036,082.24 466,573.17 0.00 5,981.14 8,600.0 63.58 329.07 5,149.2 5,093.0 5,070.2 - 3,339.3 6,036,159.24 466,527.46 0.00 6,070.65 8,700.0 63.58 329.07 5,193.7 5,137.5 5,147.0 - 3,385.3 6,036,236.24 466,481.74 0.00 6,160.17 8,800.0 63.58 329.07 5,238.2 5,182.0 5,223.8 - 3,431.4 6,036,313.24 466,436.02 0.00 6,249.68 8,900.0 63.58 329.07 5,282.7 5,226.5 5,300.7 - 3,477.4 6,036,390.24 466,390.30 0.00 6,339.19 8,921.4 63.58 329.07 5,292.2 5,236.0 5,317.1 - 3,487.3 6,036,406.73 466,380.51 0.00 6,358.37 Base Torok 9,000.0 63.58 329.07 5,327.2 5,271.0 5,377.5 - 3,523.4 6,036,467.24 466,344.58 0.00 6,428.71 9,100.0 63.58 329.07 5,371.6 5,315.4 5,454.3 - 3,569.5 6,036,544.23 466,298.86 0.00 6,518.22 9,200.0 63.58 329.07 5,416.1 5,359.9 5,531.1 - 3,615.5 6,036,621.23 466,253.15 0.00 6,607.74 9,300.0 63.58 329.07 5,460.6 5,404.4 5,607.9 - 3,661.5 6,036,698.23 466,207.43 0.00 6,697.25 9,400.0 63.58 329.07 5,505.1 5,448.9 5,684.8 - 3,707.6 6,036,775.23 466,161.71 0.00 6,786.77 9,500.0 63.58 329.07 5,549.6 5,493.4 5,761.6 - 3,753.6 6,036,852.23 466,115.99 0.00 6,876.28 9,600.0 63.58 329.07 5,594.1 5,537.9 5,838.4 - 3,799.6 6,036,929.23 466,070.27 0.00 6,965.79 9,700.0 63.58 329.07 5,638.6 5,582.4 5,915.2 - 3,845.7 6,037,006.22 466,024.56 0.00 7,055.31 9,800.0 63.58 329.07 5,683.1 5,626.9 5,992.0 - 3,891.7 6,037,083.22 465,978.84 0.00 7,144.82 9,834.0 63.58 329.07 5,698.2 5,642.0 6,018.1 - 3,907.3 6,037,109.38 465,963.31 0.00 7,175.23 Top HRZ 9,900.0 63.58 329.07 5,727.6 5,671.4 6,068.9 - 3,937.7 6,037,160.22 465,933.12 0.00 7,234.34 10,000.0 63.58 329.07 5,772.1 5,715.9 6,145.7 - 3,983.8 6,037,237.22 465,887.40 0.00 7,323.85 10,100.0 63.58 329.07 5,816.6 5,760.4 6,222.5 - 4,029.8 6,037,314.22 465,841.68 0.00 7,413.36 10,114.9 63.58 329.07 5,823.2 5,767.0 6,234.0 - 4,036.7 6,037,325.71 465,834.86 0.00 7,426.72 Base HRZ 10,200.0 63.58 329.07 5,861.1 5,804.9 6,299.3 - 4,075.8 6,037,391.22 465,795.97 0.00 7,502.88 10,300.0 63.58 329.07 5,905.5 5,849.3 6,376.1 - 4,121.9 6,037,468.22 465,750.25 0.00 7,592.39 11/4/2009 10:25:57AM Page 5 COMPASS 2003.16 Build 42 • • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co - ordinate Reference: Well ODSK -13i - Slot ODS -13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5 @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK - 13i Survey Calculation Method: Minimum Curvature Welibore: ODSK -13i KupH Design: ODSK -13i KupH wp05.a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/ -W Northing Easting DLS Vert Section (ft) ( ?) ( ?) (ft) ft (ft) (ft) (ft) (ft) 5,852.00 10,306.0 63.58 329.07 5,908.2 5,852.0 6,380.7 - 4,124.6 6,037,472.81 465,747.52 0.00 7,597.74 Kalubik Marker 10,400.0 63.58 329.07 5,950.0 5,893.8 6,453.0 - 4,167.9 6,037,545.21 465,704.53 0.00 7,681.91 10,429.6 63.58 329.07 5,963.2 5,907.0 6,475.7 - 4,181.5 6,037,568.00 465,691.00 0.00 7,708.40 Kup C - KupHi v5 T1 10,472.3 63.58 329.07 5,982.2 5,926.0 6,508.5 - 4,201.2 6,037,600.88 465,671.48 0.00 7,746.62 Start Dir 3.0/100' 10472.30' MD, 5982.20' TVD - Base Kup C (LCU) 10,500.0 62.75 329.07 5,994.7 5,938.5 6,529.7 - 4,213.9 6,037,622.14 465,658.86 3.00 7,771.33 10,600.0 59.75 329.07 6,042.8 5,986.6 6,604.9 - 4,259.0 6,037,697.51 465,614.11 3.00 7,858.95 10,700.0 56.75 329.07 6,095.4 6,039.2 6,677.8 - 4,302.7 6,037,770.61 465,570.70 3.00 7,943.94 10,800.0 53.75 329.07 6,152.4 6,096.2 6,748.3 - 4,344.9 6,037,841.24 465,528.76 3.00 8,026.05 10,831.4 52.81 329.07 6,171.2 6,115.0 6,769.9 - 4,357.9 6,037,862.91 465,515.89 3.00 8,051.24 BCU 10,867.4 51.73 329.07 6,193.2 6,137.0 6,794.3 - 4,372.5 6,037,887.36 465,501.38 3.00 8,079.66 Top Nuiqsut 10,900.0 50.75 329.07 6,213.6 6,157.4 6,816.1 - 4,385.5 6,037,909.22 465,488.40 3.00 8,105.08 11,000.0 47.75 329.07 6,278.9 6,222.7 6,881.1 - 4,424.5 6,037,974.35 465,449.73 3.00 8,180.79 11,003.4 47.65 329.07 6,281.2 6,225.0 6,883.3 - 4,425.8 6,037,976.54 465,448.43 3.00 8,183.34 Base Nuiqsut 11,019.7 47.16 329.07 6,292.2 6,236.0 6,893.5 - 4,431.9 6,037,986.82 465,442.32 3.00 8,195.30 Top Nechelik 11,100.0 44.75 329.07 6,348.0 6,291.8 6,943.0 - 4,461.6 6,038,036.45 465,412.86 3.00 8,252.99 11,115.7 44.28 329.07 6,359.2 6,303.0 6,952.5 - 4,467.3 6,038,045.90 465,407.25 3.00 8,263.97 Base Nechelik 11,173.0 42.56 329.07 6,400.8 6,344.6 6,986.3 - 4,487.5 6,038,079.77 465,387.13 3.00 8,303.35 7 5/8" 11,173.5 42.55 329.07 6,401.2 6,345.0 6,986.5 - 4,487.7 6,038,080.03 465,386.98 3.00 8,303.66 End Dir 11173.50' MD, 6401.20' TVD - Total Depth at 11173.50' MD, 6401.20' TVD Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/ -W Northing Easting - Shape - (7) (7) (ft) (ft) (ft) (ft) (ft) KupHi v5 T1 0.00 0.00 5,963.2 6,475.7 - 4,181.5 6,037,568.00 465,691.00 - plan hits target - Circle (radius 200.0) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 3,769.4 3,000.0 10 3/4" 10.750 13.500 11,173.0 6,400.8 7 5/8" 7.625 9.875 11/4/2009 10:25:57AM Page 6 COMPASS 2003.16 Build 42 • • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co- ordinate Reference: Well ODSK - 13i - Slot ODS - 13 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK - 13i Survey Calculation Method: Minimum Curvature Welibore: ODSK -13i KupH Design: ODSK -13i KupH wp05.a Formations Measured Vertical Vertical Dip Depth Depth , Depth SS Dip Direction (ft) (ft) ft Name Lithology ( ?) ( ?) 9,834.0 5,698.2 Top HRZ 0.00 1,710.6 1,666.2 Base of Permafrost 0.00 10,429.6 5,963.2 Kup C 0.00 8,433.7 5,075.2 Top Torok 0.00 3,659.7 2,951.2 Tuffaceous Shales 0.00 10,831.4 6,171.2 BCU 0.00 10,114.9 5,823.2 Base HRZ 0.00 6,709.7 4,308.2 Book 2b 0.00 11,019.7 6,292.2 Top Nechelik 0.00 2,435.1 2,281.2 Top West Sak 0.00 8,921.4 5,292.2 Base Torok 0.00 11,115.7 6,359.2 Base Nechelik 0.00 10,472.3 5,982.2 Base Kup C (LCU) 0.00 11,003.4 6,281.2 Base Nuiqsut 0.00 10,867.4 6,193.2 Top Nuiqsut 0.00 10,306.0 5,908.2 Kalubik Marker 0.00 Plan Annotations Measured Vertical Local'Ceordlnates Depth Depth *WS +Et W (ft) (ft) . (ft) (ft) Comment 300.0 300.0 0.0 0.0 Start Dir 1.00/100' 300.00' MD, 300.00' TVD 600.0 599.9 4.5 -6.4 Start Dir 2.00/100' 600.00' MD, 599.90' TVD 750.0 749.4 11.3 -16.1 Start Dir 3.00/100' 750.00' MD, 749.40' TVD 1,016.7 1,011.8 37.8 -54.0 Start Dir 1.50/100' 1016.70' MD, 1011.80' TVD 1,692.8 1,650.0 164.3 -234.7 End Dir 1692.80' MD, 1650.00' TVD 1,802.4 1,750.0 190.1 -271.4 Start Dir 3.0/100' 1802.40' MD, 1750.00' TVD 3,210.1 2,751.2 929.7 -858.1 End Dir 3210.10' MD, 2751.20' TVD 10,472.3 5,982.2 6,508.5 - 4,201.2 Start Dir 3.0/100' 10472.30' MD, 5982.20' TVD 11,173.5 6,401.2 6,986.5 - 4,487.7 End Dir 11173.50' MD, 6401.20' TVD 11,173.5 6,401.2 6,986.5 - 4,487.7 Total Depth at 11173.50' MD, 6401.20' TVD 11/4/2009 10 :25 :57AM Page 7 COMPASS 2003.16 Build 42 • Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -13i ODSK -13i KupH ODSK -13i KupH wp05.a • Sperry Drilling Services Clearance Summary Anticollision Report 04 November, 2009 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - ODSK -13i KupH - ODSK -13i KupH wp05.a Well Coordinates: 6,031,076.06 N, 469,845.81 E (70° 29' 45.50" N, 150° 14' 47.65" W) • Datum Height: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Scan Range: 42.7 to 1,600.0 ft. Measured Depth. Scan Radius is 1,313.1 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURT ®N Sperry Drilling Services SURVEY PROGRAM ANTI - COLLISION SETTINGS -- - - -- rte - - e..t._ > . Date: 2009-11-04T00:00:00 Validated: Yes Version: FOR USE FROM Interpola Method: MD, interval: 25.0 Depth Range From: 42.7 To 1600.0 Depth From Depth To Survey /Plan Tool Results Limited By: Centre Distance: 1313.1 42.7 1500.0 ODSK -13i KupH wp05.a SR- Gyro-SS Reference: Plan: ODSK -13i KupH wp05.a (ODSK -13i /ODSK -13i KupH) 1500.0 11173.5 ODSK -13i KupH wp05.a MWD +IFR2 +MS+sag Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference OOSN -2 PO ODSN -4 PSc ODSN -9i 159 From Color To MD o ODSN -11i IS1 ` ODSN -6 PS5 i 100 or I ODS -29i IN 1 ` `\ O0SN -3i 13 � 43 250 ODSN -11i IS1 ODSN -8 250 500 330 30 I 30 Ma Risk 150 330 _ 1 30 � \ 1 i Range , ` \ i ODSN - Si IS¢ 500 750 i / 40111 75 �, ` 1 i 1 O S r 30 PN 750 .. 1000 ,; -r r- - - 1 � �, 1 I I / i OM - - - - 1250 1500 � /#1* t �� - 300 60 OD PN i 1500 1750 300 • T - 6( , � r ' ' , [ 1750 2000 1 ' ,(ODSN- 321PB1 !Nil 2000 2250 t '� l,' l " I 2250 2500 - / J • , ' 2500 2750 `i ___ / 1 2750 --. 3000 270 . / ' O SN -32i IN ' 3000 4000 / j 4 - ,v, ', ,' ' _j _ 4000 5000 • ` • , 90 . r l - • • • � 0 • , � ;' 1l' � , ODSN 141N9 5000 6000 270 tS. , , _ ,. i, 6000 __ 7000 t e T 4 ) ]14 \ 1 , � - M tiY� ODSN 12P310 A. ' � - ,i' ', OP' 1 8000 9000 240 r , I 7000 8000 ' ` �� \\\v . �` �0 Abp �� i ^t ' .,P 1,' 9000 10000 , �'1ii'' 1, N : ' - ` �`�� i 1 ` ,► i ,, t . �� 1 Range 0 - 750 , (r ODSN -12 PSI 0000 11000 !;f f 4, p � ♦�p,1 Major Risk `, f �jj► ' = . 1 11000 12000 1`,( / � rl t . V = . f ® � ���ir OD SK - 33Ku r, 4`� 1 ® I l t , .� r <• 12000 13000 • ' ''', /fi r. ® � " 13000 la000 210\ a ` 0 t 150 240 r' s ' � . i 2o ODSN -3i - , v { .r. • . • ' • •r• -- d r .? la000 17000 - - - - - _ _ _ _ ODSN -15i IS13 ODSK -14 Ku j ` . t k ' � I "- - -- " r DSK -381 KupD15o00 16000 180 `\ Range O -1250 Range 0 -1 : I .' - _ 4 r r < ODSK -14 Kup Minor Risk 1/20 ) g 16000 17000 Minor Risk 1/1 :' a ;* , Range 0.150 ODSN -16 P31 ■ �0 �,, ,) -- _ ODSN -151 IS13 17000 18000 Minor Risk 1/1 . / •viii- • Ar. Ran 1600 Range 0 -12 "Is.. , Ait i5t . 1900 or Risk 1 8000 0 Major • ,,; 7! Minor Risk 11200 1 210 v f ie �� � � i. 150 \ � - 19000 20000 ODSn-48 SW 1 1. 1 07 y 40 20000 21000 _ _ _ ■ „ \ . I ODSN -16 PS14 Travelling Cylinder Azimuth (TFO+AZI) l ?j vs Centre to Centre Separation 120 ft /inl ODSN -47 SW11 wp01 - - - a80 ' ' \ - - �ODSN -17i !SI ODSN-4 PN1Ft ODSN -39i IN1 } ODSN -46 IN1 ODSD101-44 Disposal ODSK -42i KupG ODSN -18 PS16 ODSK -41 Kup~L ODSN -43 PN7 s ODSDW2 -20 DIsposill Travelling Cylinder Azimuth (TFO +AZI) [ ?] vs Centre to Centre Separation [50 ft/in] SECTION DETAILS REFERENCE INFORMATION Well Planning - Pioneer - Oooguruk i 427 Inc 000 4z� X 00 X 00 000 000 �' 00 Target e' 2 300.0 000 000 300.0 00 0.0 000 0.00 0.0 3 600.0 300 305.00 599 9 4 5 6.4 1 00 305.00 7 3 Co- ordinate (N /E) Reference: Well ODSK -13i - Slot ODS -13, True North Calculation Method: Minimum Curvature 4 7500 6.00 30500 7494 n 3 -16.1 200 000 162 Vertical (1V) 7' O Reference: 42. + 13.5' 56.2ft (Nabors 19AC 5 1016.7 14.00 30590 10118 378 640 3.00 000 610 `'- ( ) Error System: ISCWSA 6 18928 24.14 305 16500 1643 -2347 1.50 0.00 2651 Section (VS) Reference: Slot - ODS- 13(0.0N, 0.0E) 7 18024 2414 30500 17500 1901 -2714 000 0.00 3066 Scan Method: Tray. Cylinder North 8 32101 6358 329.07 27512 9297 -8581 300 32.92 12459 Measured Depth Reference: 42.7' +13.5'@ 56.28 (Naborsl9AC) Error Surface: Elliptical Conic 9 296 0104 6358 X2907 59632 6 -42812 00 0 00 0 77484 Kw"'v5T1 Calculation Method: Minimum Curvature Warning Method: Rules Based 11 111735 4255 32907 64012 69866 14877 300 18000 8303.7 NAD 27 ASP Zone 4 : WELL DETAILS: ODSK -13i Ground Level: 13.5 +N / -S +E/ -W Northing Easting Latittude Longitude Slot 0.0 0.0 6031076.06 469845.81 70 29' 45.498 N 150° 14' 47.653 W ODS -13 SURVEY PROGRAM Well Planning - Pioneer - Oooguruk ANTI COLLISION SETTINGS Date: 2009 -11- 04700:00:00 Validated: Yes Version: Calculation Method: Minimum Curvature Interpolation Method: MD, interval: 25.0 Error System: ISCWSA Depth Range From: 0.0 To 2000.0 Depth From Depth To Survey /Plan Tool Scan Method: Tray. Cylinder North Results Limited By: Centre Distance: 1313.1 i 42.7 1500.0 ODSK -13i KupH wp05.a SR- Gyro -SS Error Surface: Elliptical Conic Reference: Plan: ODSK - 13i KupH wp05.a (ODSK - 13i /ODSK - 13i KupH) 1500.0 11173.5 ODSK -13i KupH wp05.a MWD +IFR2 +MS+sag Warning Method: Rules Based Scan Type: NO GLOBAL FILTER: Using user defined selection & filtering criteria 1- - / /411 105- ._ - ... i , I _ Ot 90 ,/� co - ODS 45A Moral e -■._ O I /� c 75- ODSD 1 -44 Dis.. i/ • m - �® a - ODS -31 PN6 IIIIIIIIIIIIIIIIIII 40 0, ( ' , /� r - - ODS ' -33 KupA ODS 4 -42i Ku•G E IMPR1!������� O 45 - CDs } 2 nc� O a 7�-� -rnr c �' ' li 1 U 30- - + _ ... _________i_ . Equivelant Magnetic Distance i 15- - ODSK -14 KupB 0 1i11i1111 III 1ILIi 111111lirril iIII 11rl . iiiii 1iri 1 1IITI1 1 iitIiiii1i ii1 1 1111 11I1Iliiiiiiiiiiiir 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 Measured Depth (200 ft/in) REFERENCE INFORMATION Co- ordinate (NIE) Reference: Well ODSK -13i - Slot ODS -13, True North Vertical (TVD) Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Section (VS) Reference: Slot - ODS- 13(0.0N, 0.0E) SECTION DETAILS Measured Depth Reference: 42.7'+ 13.5' @ 56.2ft (Nabors 19AC) s« 610 Inc An TVD .N. -s .Er -w BLe9 Tcpre user Target Calculation Method: Minimum Curvature 1 427 000 0.00 42.7 00 00 000 0.00 00 2 3000 000 000 300.0 00 00 000 0.00 0.0 3 600 0 300 305.00 599.9 4 5 .6.4 100 305 00 7 3 4 7500 600 305.00 749.4 113 -161 200 000 182 5 10167 14.00 305.00 1011 8 37.8 -540 300 000 61.0 6 1692 8 24.14 305 00 1650 0 164.3 -234.7 1.50 0.00 265. 7 1802 4 24 14 30500 1750 0 190.1 -271.4 0 00 0.00 308.6 8 32101 6358 32907 27512 9297 -858.1 3.00 3292 12459 9 104296 63.58 32907 59632 64757 -41815 0.00 0. 00 77084 6u41905 T1 10 10472.3 63.58 329.07 5982 2 6508 5 -42012 000 0.00 7746.8 NAD 27 ASP Zone 4 : WELL DETAILS: ODSK -13i 11 111735 4265 32907 64012 69866 -0487.7 300 180 00 83037 Ground Level: 13.5 +N/-S +E / -W Northing Easting Latittude Longitude Slot 0.0 0.0 6031076.06 469845.81 70° 29' 45.498 N 150° 14' 47.653 W ODS -13 Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -13i - ODSK -13i KupH wp05.a Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - ODSK -13i KupH - ODSK -13i KupH wp05.a Scan Range: 42.7 to 1,600.0 ft. Measured Depth. Scan Radius is 1,313.1 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning I I Comparison Well Name - Welibore Name - Design (ft) (ft) (ft) (ft) ft Oooguruk Drill Site • ODSDW1 -44 - ODSDW1 -44 Disposal - ODSDW1 -44 C 42.7 68.3 42.7 67.3 42.7 67.536 Centre Distance Pass - Major Risk ODSDW1 -44 - ODSDW1 -44 Disposal- ODSDW1 -44 C 598.9 71.0 598.9 60.6 600.0 6.844 Clearance Factor Pass - Major Risk ODSDW2 -20 - ODSDW2 -20 Disposal - ODSDW2 -20 C 625.2 59.1 625.2 47.6 625.0 5.137 Centre Distance Pass - Major Risk ODSDW2 -20 - ODSDW2 -20 Disposal - ODSDW2 -20 C 749.6 59.9 749.6 46.0 750.0 4.310 Clearance Factor Pass - Major Risk ODSK -14 - ODSK -14 KupB - ODSK -14 KupB wp04.a 300.0 7.0 PA, WV tit 40 300.0 3.219 Centre Distance Pass - Minor Risk 1110 ODSK -14 - ODSK - 14 KupB - ODSK - 14 KupB wp04.a 525.0 7.4 : '. 525.0 " ,. 525.0 2.523 Clearance Factor Pass - Minor Risk 1/10 ODSK - - ODSK -33 KupA - ODSK -33 KupA 298.7 50.2 298.7 44.8 300.0 9.395 Centre Distance Pass - Major Risk ODSK -33 - ODSK -33 KupA - ODSK -33 KupA 768.5 56.1 768.5 42.4 775.0 4.090 Clearance Factor Pass - Major Risk ODSK -33 - ODSK -33 PB1 KupA - ODSK -33 PB1 KupF 298.7 50.2 298.7 44.8 300.0 9.395 Centre Distance Pass - Major Risk ODSK -33 - ODSK -33 PB1 KupA - ODSK -33 PB1 Kupt 768.5 56.1 768.5 42.4 775.0 4.090 Clearance Factor Pass - Major Risk ODSK -35 - ODSK -35 KupB - ODSK -35 KupB Surveys 150.0 41.0 150.0 38.2 150.0 14.996 Centre Distance Pass - Major Risk ODSK -35 - ODSK -35 KupB - ODSK -35 KupB Surveys 424.2 42.5 424.2 35.0 425.0 5.686 Clearance Factor Pass - Major Risk ODSK -38i - ODSK -38i KupD - ODSK -38i KupD Survey 198.7 33.2 198.7 29.6 200.0 9.195 Centre Distance Pass - Major Risk ODSK -38i - ODSK -38i KupD - ODSK -38i KupD Survey 373.3 34.4 373.3 27.7 375.0 5.118 Clearance Factor Pass - Major Risk ODSK -41 - ODSK -41 KupF - ODSK -41 KupF Surveys 48.7 43.2 48.7 42.1 50.0 39.350 Centre Distance Pass - Major Risk ODSK -41 - ODSK -41 KupF - ODSK -41 KupF Surveys 398.2 45.2 398.2 38.0 400.0 6.246 Clearance Factor Pass - Major Risk ODSK -41 - ODSK -41 PB1 KupF - ODSK -41 PB1 KupF 48.7 43.2 48.7 42.1 50.0 39.350 Centre Distance Pass - Major Risk • ODSK -41 - ODSK -41 PB1 KupF - ODSK -41 PB1 KupF 398.2 45.2 398.2 38.0 400.0 6.246 Clearance Factor Pass - Major Risk ODSK -42i - ODSK -42i KupG - ODSK -42i KupG wp10.t 100.0 48.0 100.0 46.1 100.0 26.172 Centre Distance Pass - Major Risk ODSK -42i - ODSK -42i KupG - ODSK -42i KupG wp10.1 474.1 50.8 474.1 42.3 475.0 6.007 Clearance Factor Pass - Major Risk ODSK -42i - ODSK -42i KupG - ODSK -42i KupG 75.0 47.9 75.0 46.4 75.0 31.598 Centre Distance Pass - Major Risk ODSK -42i - ODSK -42i KupG - ODSK -42i KupG 374.7 49.3 374.7 42.5 375.0 7.198 Clearance Factor Pass - Major Risk ODSN -1 - ODSN -1 - ODSN -1 NE3 wp01 300.0 106.0 300.0 100.4 300.0 18.891 Centre Distance Pass - Major Risk ODSN -1 - ODSN -1 - ODSN -1 NE3 wp01 399.7 107.0 399.7 99.6 400.0 14.427 Clearance Factor Pass - Major Risk ODSN -10 - ODSN -10 PS12 - ODSN -10 PS12 wp10 - 6 300.0 32.0 300.0 26.4 300.0 5.706 Centre Distance Pass - Major Risk ODSN -10 - ODSN -10 PS12 - ODSN -10 PS12 wp10 - 6 699.0 34.8 699.0 21.9 700.0 2.704 Clearance Factor Pass - Major Risk ODSN -11i - ODSN -11i 1511 - ODSN -11i IS11 wp11 tes 599.8 25.0 599.8 14.0 600.0 2.269 Centre Distance Pass - Major Risk ODSN -11 i - ODSN -11 i IS11 - ODSN -11 i IS11 wp11 tes 849.0 26.7 849.0 10.6 850.0 1.664 Clearance Factor Pass - Major Risk 04 November, 2009 - 11:42 Page 2 of 8 COMPASS Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -13i - ODSK -13i KupH wp05.a Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - ODSK -13i KupH - ODSK -13i KupH wp05.a Scan Range: 42.7 to 1,600.0 ft. Measured Depth. Scan Radius is 1,313.1 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft ODSN -12 - ODSN -12 PS10 - ODSN -12 PS10 wp12 300.0 18.0 300.0 12.5 300.0 3.261 Centre Distance Pass - Major Risk ODSN -12 - ODSN -12 PS10 - ODSN -12 PS10 wp12 724.3 20.1 724.3 6.9 725.0 1.523 Clearance Factor Pass - Major Risk ODSN - 15i - ODSN - 15i IS13 - ODSN - 15i IS13 wp08 300.0 14.0 300.0 11.3x '. *.0 5.257 Centre Distance Pass - Risk 11200 ODSN -15i - ODSN -15i 1S13 - ODSN -15i IS13 wp08 750.2 15.3 n „_ 750.2 10.0 2.893 Cietwaroe Factor Pass - Risk 11200 ODSN - - ODSN - PS14 - ODSN - PS14 wp09 500.0 20.7 500.0 11.4 500.0 2.231 Centre Distance Pass - M jor Risk ODSN -16 - ODSN -16 PS14 - ODSN -16 PS14 wp09 674.8 21.9 674.8 9.5 675.0 1.763 Clearance Factor Pass - M jor Risk ODSN -17i - ODSN -17i IS15 - ODSN -17i IS15 wp08 425.1 27.8 425.1 19.9 425.0 3.524 Centre Distance Pass - M jor Risk ODSN -17i - ODSN -17i IS15 - ODSN -17i IS15 wp08 625.1 29.4 625.1 18.0 625.0 2.582 Clearance Factor Pass - M jor Risk ODSN -18 - ODSN -18 PS16 - ODSN -18 PS16 wp08 300.0 34.9 300.0 29.3 300.0 6.228 Centre Distance Pass - M jor Risk ODSN -18 - ODSN -18 PS16 - ODSN -18 PS16 wp08 800.5 40.1 800.5 25.2 800.0 2.692 Clearance Factor Pass - Major Risk ODSN -2 - ODSN -2 PS1 - ODSN -2 PS1 wp08 300.0 99.0 300.0 93.4 300.0 17.643 Centre Distance Pass - M.jor Risk ODSN -2 - ODSN -2 PS1 - ODSN -2 PS1 wp08 474.4 100.0 474.4 91.2 475.0 11.377 Clearance Factor Pass - M.jor Risk ODSN -25 - ODSN -25 - ODSN -25 NE4 wp02 298.7 110.9 298.7 105.3 300.0 19.843 Centre Distance Pass - Major Risk ODSN -25 - ODSN -25 - ODSN -25 NE4 wp02 373.1 111.6 373.1 104.7 375.0 16.186 Clearance Factor Pass - Major Risk ODSN -26 - ODSN -26 PN1 - ODSN -26 PN1 wp06 300.0 104.2 300.0 98.6 300.0 18.575 Centre Distance Pass - Major Risk ODSN -26 - ODSN -26 PN1 - ODSN -26 PN1 wp06 448.7 105.4 448.7 97.0 450.0 12.664 Clearance Factor Pass - Major Risk ODSN -27i - ODSN -27i IN2 - ODSN -27i IN2 wp06 300.0 97.6 300.0 92.0 300.0 17.391 Centre Distance Pass - Major Risk ODSN -27i - ODSN -27i IN2 - ODSN -27i IN2 wp06 498.3 99.3 498.3 90.1 500.0 10.747 Clearance Factor Pass - Major Risk ODSN -28 - ODSN -28 PN3 - ODSN -28 PN3 wp07.a 300.0 91.1 300.0 85.5 300.0 16.228 Centre Distance Pass - M..jor Risk III ODSN -28 - ODSN -28 PN3 - ODSN -28 PN3 wp07.a 374.4 91.7 374.4 84.8 375.0 13.290 Clearance Factor Pass - M.:jor Risk ODSN -29i - ODSN -29i IN4 - ODSN -29i IN4 wp06 300.0 84.6 300.0 79.0 300.0 15.075 Centre Distance Pass - M.:jor Risk ODSN -29i - ODSN -29i IN4 - ODSN -29i IN4 wp06 424.0 85.4 424.0 77.5 425.0 10.859 Clearance Factor Pass - M..jor Risk ODSN -30 - ODSN -30 PN5 - ODSN -30 PN5 wp05 300.0 78.2 300.0 72.6 300.0 13.929 Centre Distance Pass - M..jor Risk ODSN -30 - ODSN -30 PN5 - ODSN -30 PN5 wp05 473.6 79.7 473.6 70.9 475.0 9.065 Clearance Factor Pass - M..jor Risk ODSN -31 - ODSN -31 PB1 PN6 - ODSN -31 PB1 PN6 S 300.0 61.8 300.0 56.3 300.0 11.195 Centre Distance Pass - M :jor Risk ODSN -31 - ODSN -31 PB1 PN6 - ODSN-31PB1 PN6 S 374.5 62.3 374.5 55.6 375.0 9.228 Clearance Factor Pass - Major Risk ODSN -31 - ODSN -31 PN6 - ODSN -31 PN6 Surveys 300.0 61.8 300.0 56.3 300.0 11.195 Centre Distance Pass - M :jor Risk ODSN -31 - ODSN -31 PN6 - ODSN -31 PN6 Surveys 374.5 62.3 374.5 55.6 375.0 9.228 Clearance Factor Pass - M :jor Risk ODSN -32i - ODSN -32i IN7 - ODSN -32i IN7 Surveys 150.0 56.0 150.0 53.3 150.0 20.511 Centre Distance Pass - M :jor Risk ODSN -32i - ODSN -32i IN7 - ODSN -32i IN7 Surveys 399.2 57.1 399.2 50.0 400.0 7.975 Clearance Factor Pass - Major Risk 04 November, 2009 - 11:42 Page 3 of 8 COMPASS Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -13i - ODSK -13i KupH wp05.a Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - ODSK -13i KupH - ODSK -13i KupH wp05.a 1,600.0 ft. Measured Depth. Range: 42.7 to ,600 0 ft th. p 9 Scan Radius is 1,313.1 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft ODSN -32i - ODSN- 32iPB1 IN7 - ODSN- 32iPB1 IN7 150.0 56.0 150.0 53.3 150.0 20.511 Centre Distance Pass - Major Risk ODSN -32i - ODSN- 32iPB1 IN7 - ODSN- 32iPB1 IN7 399.2 57.1 399.2 50.0 400.0 7.975 Clearance Factor Pass - Major Risk ODSN -34i - ODSN -34 IN9 - ODSN -34i IN9 Surveys 300.0 43.8 300.0 38.3 300.0 8.023 Centre Distance Pass - Major Risk • ODSN -34i - ODSN -34 IN9 - ODSN -34i IN9 Surveys 374.5 44.2 374.5 37.6 375.0 6.625 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB1 IN9 - ODSN- 34iPB1 IN9 300.0 43.8 300.0 38.3 300.0 8.023 Centre Distance Pass - Major Risk ODSN -34i - ODSN- 34iPB1 IN9 - ODSN- 34iPB1 IN9 374.5 44.2 374.5 37.6 375.0 6.625 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB2 IN9 - ODSN- 34iPB2 IN9 300.0 43.8 300.0 38.3 300.0 8.023 Centre Distance Pass - Major Risk ODSN -34i - ODSN- 34iPB2 IN9 - ODSN- 34iPB2 IN9 374.5 44.2 374.5 37.6 375.0 6.625 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB3 IN9 - ODSN- 34iPB3 IN9 300.0 43.8 300.0 38.3 300.0 8.023 Centre Distance Pass - Major Risk ODSN -34i - ODSN- 34iPB3 IN9 - ODSN- 34iPB3 IN9 374.5 44.2 374.5 37.6 375.0 6.625 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 - ODSN -36 PN10 Surveys 200.0 37.0 200.0 33.3 200.0 10.077 Centre Distance Pass - Major Risk ODSN -36 - ODSN -36 - ODSN -36 PN10 Surveys 324.8 37.4 324.8 31.6 325.0 6.495 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 PB1 - ODSN -36 PB1 PN10 200.0 37.0 200.0 33.3 200.0 10.077 Centre Distance Pass - Major Risk ODSN -36 - ODSN -36 PB1 - ODSN -36 PB1 PN10 324.8 37.4 324.8 31.6 325.0 6.495 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 PB2 - ODSN -36 PB2 PN10 200.0 37.0 200.0 33.3 200.0 10.077 Centre Distance Pass - Major Risk ODSN -36 - ODSN -36 PB2 - ODSN -36 PB2 PN10 324.8 37.4 324.8 31.6 325.0 6.495 Clearance Factor Pass - Major Risk ODSN -37 - ODSN -37 - ODSN -37 Surveys 349.7 31.9 349.7 25.5 350.0 4.981 Centre Distance Pass - Major Risk ODSN -37 - ODSN -37 - ODSN -37 Surveys 399.4 32.2 399.4 24.9 400.0 4.450 Clearance Factor Pass - Major Risk ODSN -39i - ODSN -39i IN11 - ODSN -39i IN11 wp16 42.7 35.6 42.7 34.7 42.7 . 36.970 Centre Distance Pass - Major Risk • ODSN -39i - ODSN -39i IN11 - ODSN -39i IN11 wp16 324.9 37.5 324.9 31.6 325.0 6.328 Clearance Factor Pass - Major Risk ODSN -39i - ODSN -39i IN11 - ODSN -39i IN11 42.7 35.6 42.7 34.7 42.7 36.970 Centre Distance Pass - Major Risk ODSN -39i - ODSN -39i IN11 - ODSN -39i IN11 324.9 37.5 324.9 31.6 325.0 6.328 Clearance Factor Pass - Major Risk ODSN -3i - ODSN -3i IS2 - ODSN -3i IS2 wp08 300.0 92.0 300.0 86.4 300.0 16.519 Centre Distance Pass - Major Risk ODSN -3i - ODSN -3i 152 - ODSN -3i IS2 wp08 549.2 93.3 549.2 83.1 550.0 9.200 Clearance Factor Pass - Major Risk ODSN -4 - ODSN -4 PS3 - ODSN -4 PS3 wp07 300.0 85.0 300.0 79.4 300.0 15.156 Centre Distance Pass - Major Risk ODSN -4 - ODSN -4 PS3 - ODSN -4 PS3 wp07 449.6 86.4 449.6 78.0 450.0 10.347 Clearance Factor Pass - Major Risk ODSN -40 - ODSN -40 PN12 - ODSN -40 PN12 Surveys 42.7 38.9 42.7 37.9 44.0 40.328 Centre Distance Pass - Major Risk ODSN -40 - ODSN -40 PN12 - ODSN -40 PN12 Surveys 323.6 40.2 323.6 34.3 325.0 6.836 Clearance Factor Pass - Major Risk ODSN -40 - ODSN -40PB1 PN12 - ODSN -40PB1 PN12 42.7 38.9 42.7 37.9 44.0 40.328 Centre Distance Pass - Major Risk ODSN -40 - ODSN -4OPB1 PN12 - ODSN -40PB1 PN12 323.6 40.2 323.6 34.3 325.0 6.836 Clearance Factor Pass - Major Risk 04 November, 2009 - 11:42 Page 4 of 8 COMPASS Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -13i - ODSK -13i KupH wp05.a Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - ODSK -13i KupH - ODSK -13i KupH wp05.a Scan Range: 42.7 to 1,600.0 ft. Measured Depth. Scan Radius is 1,313.1 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Welibore Name - Design (ft) (ft) (ft) (ft) ft ODSN -40 - ODSN -40PB2 PN12 - ODSN -40PB2 PN12 42.7 38.9 42.7 37.9 44.0 40.328 Centre Distance Pass - Major Risk ODSN -40 - ODSN -40PB2 PN12 - ODSN -40PB2 PN12 323.6 40.2 323.6 34.3 325.0 6.836 Clearance Factor Pass - Major Risk ODSN -43 - ODSN -43 PN14 - ODSN -43 PN14 wp12 298.7 62.2 298.7 56.6 300.0 11.132 Centre Distance Pass - Major Risk • ODSN -43 - ODSN -43 PN14 - ODSN -43 PN14 wp12 373.4 62.8 373.4 56.0 375.0 9.206 Clearance Factor Pass - Major Risk ODSN -45 - ODSN -45A Moraine - ODSN -45A Surveys 42.7 74.5 42.7 73.5 42.7 73.681 Centre Distance Pass - Major Risk ODSN -45 - ODSN -45A Moraine - ODSN -45A Surveys 324.9 76.6 324.9 70.5 325.0 12.544 Clearance Factor Pass - Major Risk ODSN -45 - ODSN -45i IN13 PB1 - ODSN -45i IN13 PB1 42.7 74.5 42.7 73.5 42.7 73.681 Centre Distance Pass - Major Risk ODSN -45 - ODSN -45i IN13 PB1 - ODSN -45i IN13 PB1 324.9 76.6 324.9 70.5 325.0 12.544 Clearance Factor Pass - Major Risk ODSN -46 - ODSN -46 IN11 - ODSN -46 IN11 wp17 300.0 80.9 300.0 75.2 300.0 14.409 Centre Distance Pass - Major Risk ODSN -46 - ODSN -46 IN11 - ODSN -46 IN11 wp17 374.7 81.5 374.7 74.6 375.0 11.906 Clearance Factor Pass - Major Risk ODSN -47 - ODSN -47 SW11 wp01 - ODSN -47 SW11 v 298.7 87.4 298.7 81.8 300.0 15.632 Centre Distance Pass - Major Risk ODSN -47 - ODSN -47 SW11 wp01 - ODSN -47 SW11 v 373.5 88.0 373.5 81.2 375.0 12.894 Clearance Factor Pass - Major Risk ODSN -48 - ODSn -48 SW9 - ODSN -48 SW9 wp01 298.7 93.9 298.7 88.3 300.0 16.790 Centre Distance Pass - Major Risk ODSN -48 - ODSn -48 SW9 - ODSN -48 SW9 wp01 373.5 94.4 373.5 87.6 375.0 13.826 Clearance Factor Pass - Major Risk ODSN -5i - ODSN -5i IS4 - ODSN -5i IS4 wp08 300.0 78.0 300.0 72.4 300.0 13.903 Centre Distance Pass - Major Risk ODSN -5i - ODSN -5i IS4 - ODSN -5i IS4 wp08 524.4 79.5 524.4 69.8 525.0 8.181 Clearance Factor Pass - Major Risk ODSN -6 - ODSN -6 PS5 - ODSN -6 PS5 wp09 300.0 71.0 300.0 65.4 300.0 12.658 Centre Distance Pass - Major Risk ODSN -6 - ODSN -6 PS5 - ODSN -6 PS5 wp09 499.6 72.8 499.6 63.6 500.0 7.876 Clearance Factor Pass - Major Risk ODSN -7i - ODSN -7i IS7 - ODSN -7i IS7 wp08 300.0 53.0 300.0 45.4 300.0 6.978 Centre Distance Pass - Major Risk • ODSN -7i - ODSN -7i IS7 - ODSN -7i IS7 wp08 673.6 56.5 673.6 38.6 675.0 3.157 Clearance Factor Pass - Major Risk ODSN -8 - ODSN -8 PS8 - ODSN -8 PS8 wp09 - 6K hor 300.0 46.0 300.0 40.5 300.0 8.332 Centre Distance Pass - Major Risk ODSN -8 - ODSN -8 PS8 - ODSN -8 PS8 wp09 - 6K' hor 574.5 48.1 574.5 37.6 575.0 4.564 Clearance Factor Pass - Major Risk ODSN -9i - ODSN -9i IS9 - ODSN -9i IS9 wp12 - 6K Hor 300.0 39.0 300.0 33.5 300.0 7.060 Centre Distance Pass - Major Risk ODSN -9i - ODSN -9i IS9 - ODSN -9i IS9 wp12 - 6K' Hor 674.5 42.3 674.5 29.8 675.0 3.402 Clearance Factor Pass - Major Risk 04 November, 2009 - 11:42 Page 5 of 8 COMPASS Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -13i - ODSK -13i KupH wp05.a Survey tool nroaram From To Survey /Plan Survey Tool (ft) (ft) 42.7 1,500.0 ODSK -13i KupH wp05.a SR- Gyro -SS 1,500.0 11,173.5 ODSK -13i KupH wp05.a MWD +IFR2 +MS +sag Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. • Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 04 November, 2009 - 11:42 Page 6 of 8 COMPASS Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK -13i ODSK -13i KupH ODSK -13i KupH wp05.a • Sperry Drilling Services Clearance Summary Anticollision Report • 04 November, 2009 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - ODSK -13i KupH - ODSK -13i KupH wp05.a Well Coordinates: 6,031,076.06 N, 469,845.81 E (70° 29' 45.50" N, 150° 14' 47.65" W) • Datum Height: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Scan Range: 1,600.0 to 11,173.5 ft. Measured Depth. Scan Radius is 1,313.1 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services SURVEY PROGRAM ANTI- COLLISION SETTINGS Date: 2009 - 11 - 04700:00:00 Validated: Yes Version: Interpolation Method: MD, interval: 25.0 Depth Range From: 1600.0 To 11173.5 Depth From Depth To Survey /Plan Tool Results Limited By: Centre Distance: 1313.1 42.7 1500.0 ODSK - 13i KupH wp05.a SR Gyro - SS Reference: Plan: ODSK -13i KupH wp05.a (ODSK -13i /ODSK -13i KupH) 1500.0 11173.5 ODSK - 13i KupH wpOS.a MWD+IF132 +MS+sag Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 0 From Color To MD 0 100 330 "'j-_. 1' 30 43 250 330. _ _ - 30 --- --/- _ 250 ' - 500 • � .. 500 750 750 __ 1000 �,, 2 0 �, Iciv_ ` ` 1000 1250 , , , 300 , �,, 60 1250 1500 / / , • 300 � , so 60 1500 1750 �� * ___ ,,,-- 1750 2000 mh ` , �� 2000 zzso tit, 2250 2500 / - \ / / _ - 2500 2750 _ .- 1 270 270 A ; I 2# ��\ / I 7000 eaoo __ _ s000 240 s000 �� 101 1089 11000 OSN 1 Rngs 11000 lz000 ` i Mor is 12000 13000 240 ���� "V , P= = � 120 13000 14000 • • �� 14000 15000 180 , 1 �� - 15000 16000 NN t /�.,, /: ` . ODSK -14 KupB ittt" ' •� ` ODSN - 15i IS13 16000 17000 , ;ii ' • tSV.%`, ` Range 1600 - 1750 U\ \���� � 177 i , -�� ,/ `.,', r- � . Range 1600 - 207 17000 18000 ,. ♦ , _ Major Risk i ��� �� 16000 15000 Major Risk ) ref � , ,�� • - 1 • 210 , •••...."... 150 I' I� ' ��r 19000 20000 r %� �., ��� 20000 21000 Travelling Cylinder Azimuth (TFO +AZI) I71 vs Centre to Centre Separation 120 ft /in( 4, 180 ODSK -14 KupB Range 1600 -2251 Major Risk Travelling Cylinder Azimuth (TFO +AZI) ( ?l vs Centre to Centre Separation 150 ft /in] SECTION DETAILS REFERENCE INFORMATION Well Planning - Pioneer - Oooguruk see MD o 0 o T. 427 �NOO •EI- a o` o o.00 VSe Target 427 3000 000 000 300.0 00 00 0.00 000 00 Co- ordinate (N /E) Reference: Well ODSK -13i - Slot ODS -13, True North Calculation Method: Minimum Curvature 75500 600 30500 599 4994 11 a -lei 2.00 30 000 182 Vertical (TVD) Reference: 42.7' + 13.5' @ 56.2ft (Nabors 19AC) Error S stem: ISCWSA 10167 1400 30500 1011 8 378 -540 300 000 610 Section (VS) Reference: Slot - ODS -13 0.0N, 0.0E y 16928 2414 30500 1650.0 1643 -2347 1.50 0.00 2651 l ) ( 0.0E) 1692 24.14 305.00 1750 0 190 1 -271 4 0 00 0.00 306.6 Measured Depth Reference: 42.7 +13.5' @56.2ft (Nabors 19AC) can Method: Tray. Cylinder North 32101 6358329.07 27512 9297 -8581 300 3292 1245.9 Calculation Method: Minimum Curvature Error Surface: Elliptical Conic 104296 6358 32907 59632 64757 41815 000 0.00 77084 Kupl,v5T1 0 10472 3 63 58 329 07 5982.2 6508 5 -4201.2 0 00 0 00 77486 Warning Method: Rules Based 1 1,1735 4255 32907 64012 69866 44877 300 18000 93037 NAD 27 ASP Zone 4 : WELL DETAILS: ODSK -13i Ground Level: 13.5 +N / -S +E / -W Northing Easting Latittude Longitude Slot 0.0 0.0 6031076.06 469845.81 70° 29' 45.498 N 150° 14' 47.653 W ODS -13 Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -13i - ODSK -13i KupH wp05.a Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - ODSK -13i KupH - ODSK -13i KupH wp05.a Scan Range: 1,600.0 to 11,173.5 ft. Measured Depth. Scan Radius is 1,313.1 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Welibore Name - Design (ft) (ft) (ft) (ft) ft Oooguruk Drill Site • ODSDW1 -44 - ODSDW1 -44 Disposal - ODSDW1 -44 E 1,600.0 289.8 1,600.0 261.2 1,675.0 10.131 Clearance Factor Pass - Major Risk ODSDW2 -20 - ODSDW2 -20 Disposal - ODSDW2 -20 E 1,607.5 321.7 1,607.5 293.5 1,700.0 11.434 Clearance Factor Pass - Major Risk ODSK - 14 - ODSK - 14 KupB - ODSK - 14 KupB wp04.a 1,623.0 ' -": ." 14.7 1, r LL ` 1.387 Clearmse Factor Pass - Major Risk ODSK - - ODSK -33 KupA - ODSK -33 KupA 1,604.1 178.2 1,604.1 150.4 1,650.0 6.418 Clearance Factor Pass - Major Risk ODSK -33 - ODSK -33 PB1 KupA - ODSK -33 PB1 Kup, 1,604.1 178.2 1,604.1 150.4 1,650.0 6.418 Clearance Factor Pass - Major Risk 1 ODSK -35 - ODSK -35 KupB - ODSK -35 KupB Surveys 1,604.0 270.1 1,604.0 243.2 1,675.0 10.017 Clearance Factor Pass - Major Risk ODSK -38i - ODSK -38i KupD - ODSK -38i KupD Survey 1,600.0 445.3 1,600.0 417.8 1,750.0 16.201 Clearance Factor Pass - Major Risk ODSK -41 - ODSK -41 KupF - ODSK -41 KupF Surveys 1,600.0 448.3 1,600.0 420.1 1,750.0 15.948 Clearance Factor Pass - Major Risk ODSK -41 - ODSK -41 PB1 KupF - ODSK -41 PB1 KupF 1,600.0 448.3 1,600.0 420.1 1,750.0 15.949 Clearance Factor Pass - Major Risk ODSK -42i - ODSK -42i KupG - ODSK -42i KupG wp10.I 1,611.6 440.2 1,611.6 410.5 1,750.0 14.807 Clearance Factor Pass - Major Risk ODSK -42i - ODSK -42i KupG - ODSK -42i KupG 1,615.6 432.0 1,615.6 401.2 1,750.0 14.022 Clearance Factor Pass - Major Risk ODSN -1 - ODSN -1 - ODSN -1 NE3 wp01 1,610.3 461.2 1,610.3 426.8 1,725.0 13.406 Clearance Factor Pass - Major Risk ODSN -10 - ODSN -10 PS12 - ODSN -10 PS12 wp10 - E 1,621.6 146.2 1,621.6 116.1 1,650.0 4.860 Clearance Factor Pass - Major Risk ODSN -11 i - ODSN -11 i IS11 - ODSN -11 i IS11 wp11 tee 1,613.5 72.2 1,613.5 40.6 1,625.0 2.284 Clearance Factor Pass - Major Risk ODSN -12 - ODSN -12 PS10 - ODSN -12 PS10 wp12 1,600.0 131.3 1,600.0 103.4 1,625.0 4.700 Clearance Factor Pass - Major Risk ODSN -15i - ODSN -15i IS13 - ODSN -15i IS13 wp08 1,615.3 72.0 1,615.3 38.9 1,625.0 2.177 Clearance Factor Pass - Major Risk • ODSN -16 - ODSN -16 PS14 - ODSN -16 PS14 wp09 1,600.0 133.6 1,600.0 103.5 1,625.0 4.450 Clearance Factor Pass - Major Risk ODSN -17i - ODSN -17i IS15 - ODSN -17i 1515 wp08 1,622.3 162.2 1,622.3 127.9 1,650.0 4.740 Clearance Factor Pass - Major Risk ODSN -18 - ODSN -18 PS16 - ODSN -18 PS16 wp08 1,613.5 110.7 1,613.5 72.1 1,625.0 2.871 Clearance Factor Pass - Major Risk ODSN -2 - ODSN -2 PS1 - ODSN -2 PS1 wp08 1,618.6 426.5 1,618.6 390.9 1,725.0 11.957 Clearance Factor Pass - Major Risk ODSN -25 - ODSN -25 - ODSN -25 NE4 wp02 1,613.1 611.4 1,613.1 579.5 1,825.0 19.169 Clearance Factor Pass - Major Risk ODSN -26 - ODSN -26 PN1 - ODSN -26 PN1 wp06 1,614.8 478.8 1,614.8 444.3 1,750.0 13.878 Clearance Factor Pass - Major Risk ODSN -27i - ODSN -27i IN2 - ODSN -27i IN2 wp06 1,616.2 460.9 1,616.2 428.6 1,750.0 14.265 Clearance Factor Pass - Major Risk ODSN -28 - ODSN -28 PN3 - ODSN -28 PN3 wp07.a 1,600.0 576.3 1,600.0 544.7 1,800.0 18.256 Clearance Factor Pass - Major Risk ODSN -29i - ODSN -29i IN4 - ODSN -29i 1N4 wp06 1,611.9 503.9 1,611.9 473.2 1,775.0 16.458 Clearance Factor Pass - Major Risk ODSN -30 - ODSN -30 PN5 - ODSN -30 PN5 wp05 1,605.4 504.2 1,605.4 474.6 1,775.0 17.034 Clearance Factor Pass - Major Risk ODSN -31 - ODSN -31 PB1 PN6 - ODSN-31PB1 PN6 S 1,600.0 555.7 1,600.0 526.7 1,800.0 19.167 Clearance Factor Pass - Major Risk ODSN -31 - ODSN -31 PN6 - ODSN -31 PN6 Surveys 1,600.0 555.7 1,600.0 526.7 1,800.0 19.167 Clearance Factor Pass - Major Risk 04 November, 2009 - 11:48 Page 2 of 6 COMPASS Well Planning - Pioneer - Oooguruk ment Oooguruk Development g p Anticollision Report for ODSK -13i - ODSK -13i KupH wp05.a Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Oooguruk Drill Site - ODSK -13i - ODSK -13i KupH - ODSK -13i KupH wp05.a Scan Range: 1,600.0 to 11,173.5 ft. Measured Depth. Scan Radius is 1,313.1 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft ODSN -32i - ODSN -32i IN7 - ODSN -32i IN7 Surveys 1,613.7 480.1 1,613.7 450.5 1,775.0 16.241 Clearance Factor Pass - Major Risk ODSN -32i - ODSN- 32iPB1 IN7 - ODSN- 32iPB1 IN7 1,613.7 480.1 1,613.7 450.5 1,775.0 16.241 Clearance Factor Pass - Major Risk 1 ODSN -34i - ODSN -34 IN9 - ODSN -34i IN9 Surveys 1,600.0 544.1 1,600.0 516.0 1,800.0 19.404 Clearance Factor Pass - Major Risk 1 ODSN -34i - ODSN- 34iPB1 IN9 - ODSN- 34iPB1 IN9 1,600.0 544.1 1,600.0 516.0 1,800.0 19.403 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB2 IN9 - ODSN- 34iPB2 IN9 1,600.0 544.1 1,600.0 516.0 1,800.0 19.404 Clearance Factor Pass - Major Risk ODSN -34i - ODSN- 34iPB3 IN9 - ODSN- 34iPB3 IN9 1,600.0 544.1 1,600.0 516.0 1,800.0 19.404 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 - ODSN -36 PN10 Surveys 1,609.0 883.9 1,609.0 854.8 2,050.0 30.416 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 PB1 - ODSN -36 PB1 PN10 1,609.0 883.9 1,609.0 854.8 2,050.0 30.416 Clearance Factor Pass - Major Risk ODSN -36 - ODSN -36 PB2 - ODSN -36 PB2 PN10 1,609.0 883.9 1,609.0 854.8 2,050.0 30.416 Clearance Factor Pass - Major Risk ODSN -37 - ODSN -37 - ODSN -37 Surveys 1,600.0 534.2 1,600.0 505.2 1,800.0 18.446 Clearance Factor Pass - Major Risk ODSN -39i - ODSN -39i IN11 - ODSN -39i IN11 wp16 1,607.8 538.6 1,607.8 510.0 1,800.0 18.818 Clearance Factor Pass - Major Risk ODSN -39i - ODSN -39i IN11 - ODSN -39i IN11 1,607.8 538.6 1,607.8 510.0 1,800.0 18.818 Clearance Factor Pass - Major Risk ODSN -3i - ODSN -3i IS2 - ODSN -3i IS2 wp08 1,600.0 340.1 1,600.0 304.2 1,675.0 9.462 Clearance Factor Pass - Major Risk ODSN -4 - ODSN -4 PS3 - ODSN -4 PS3 wp07 1,614.5 245.9 1,614.5 205.9 1,650.0 6.151 Clearance Factor Pass - Major Risk ODSN -40 - ODSN -40 PN12 - ODSN -40 PN12 Surveys 1,611.9 613.7 1,611.9 585.0 1,850.0 21.411 Clearance Factor Pass - Major Risk ODSN -40 - ODSN -40PB1 PN12 - ODSN -40PB1 PN12 1,611.9 613.7 1,611.9 585.0 1,850.0 21.411 Clearance Factor Pass - Major Risk ODSN -40 - ODSN -40PB2 PN12 - ODSN -40PB2 PN12 1,611.9 613.7 1,611.9 585.0 1,850.0 21.411 Clearance Factor Pass - Major Risk ODSN -43 - ODSN -43 PN14 - ODSN -43 PN14 wp12 1,610.1 674.0 1,610.1 643.3 1,875.0 21.973 Clearance Factor Pass - Major Risk ODSN -45 - ODSN -45A Moraine - ODSN -45A Surveys 1,613.8 505.3 1,613.8 475.3 1,775.0 16.857 Clearance Factor Pass - Major Risk IIIII ODSN -45 - ODSN -45i IN13 PB1 - ODSN -45i IN13 PB1 1,613.8 505.3 1,613.8 475.3 1,775.0 16.857 Clearance Factor Pass - Major Risk ODSN -46 - ODSN -46 IN11 - ODSN -46 IN11 wp17 1,614.5 518.4 1,614.5 485.1 1,775.0 15.584 Clearance Factor Pass - Major Risk ODSN -47 - ODSN -47 SW11 wp01 - ODSN -47 SW11 v 1,600.0 558.2 1,600.0 524.8 1,775.0 16.693 Clearance Factor Pass - Major Risk ODSN -48 - ODSn -48 SW9 - ODSN -48 SW9 wp01 1,612.8 510.9 1,612.8 475.9 1,750.0 14.614 Clearance Factor Pass - Major Risk ODSN -5i - ODSN -5i IS4 - ODSN -5i IS4 wp08 1,608.0 239.8 1,608.0 205.9 1,650.0 7.074 Clearance Factor Pass - Major Risk ODSN -6 - ODSN -6 PS5 - ODSN -6 PS5 wp09 1,604.5 197.0 1,604.5 158.8 1,625.0 5.148 Clearance Factor Pass - Major Risk ODSN -7i - ODSN -7i IS7 - ODSN -7i IS7 wp08 1,600.0 285.7 1,600.0 247.5 1,675.0 7.477 Clearance Factor Pass - Major Risk ODSN -8 - ODSN -8 PS8 - ODSN -8 PS8 wp09 - 6K' hor 1,620.4 178.4 1,620.4 144.3 1,650.0 5.231 Clearance Factor Pass - Major Risk ODSN -9i - ODSN -9i IS9 - ODSN -9i IS9 wp12 - 6K' Hor 1,610.1 117.4 1,610.1 82.1 1,625.0 3.327 Clearance Factor Pass - Major Risk 04 November, 2009 - 11:48 Page 3 of 6 COMPASS Well Planning - Pioneer - Oooguruk HALLIBURTON Oooguruk Development Anticollision Report for ODSK -13i - ODSK -13i KupH wp05.a Survey tool program From To Survey /Plan Survey Tool (ft) (ft) 42.7 1,500.0 ODSK -13i KupH wp05.a SR- Gyro -SS 1,500.0 11,173.5 ODSK -13i KupH wp05.a MWD +IFR2 +MS +sag Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. • 04 November, 2009 - 11:48 Page 4 of 6 COMPASS - I' I 0 N E E R Project: Oooguruk Development 9000– o °'N3, 'NS Site: Oooguruk Drill Site - NATI �R,' _ ODSK- 3� KupH! 151 I CDS 31PB1 P I. 7500 — ___N■ - , • ■�N ■� —�■■n� �E _ N - .. • ■ r ' ■■■■■■ ■ . ■ ■1■■■ 1 _ O�SN-37 PN: hi 6000 _h ■__ .._■ Li 11111 11111 _■■11■ ' : - I :. 1■ ® 1111■■■ ■ 11111.11111111.1 � ' _ 1■ 111111•111111 4500 = III • DS -14 Kgp6 p0 .a It • , - -381 Ku 1D 3000 ■ 1 , ,t�� ■■■ II Nb0 LII I kik 1 1 . ■■11 NEE 1500 o !i h1uh1 U 'R p 0 – ODSNdoPM'2 • PSD'W1-44D sposa co _ s� - � ' i1 II .►��� ■� �: ■� 1■1111111 Mal V\ i - z -1500 • • L ' Aiih . - �11 ■11 0 _ ■ ■1 - - 1 - ■ tigg ■!i X111 11 t _C- _ _ NI mom= mgrArrim ..:0 ,,„„--4,- • ••••••••• ____ Es ___ �N■ ■ ODSN TZL�� \ ���■ ■ �■O� ■�•• 11111 • • . _ , . �► ,, . Em ■ ■o ►. Al 111 ■■ m il -3000 = i , • • . -�, it%ce1 , y. .. P•V O V 33 , • ■ OPSN-4(1 PN12 11. ■ -6000 ■ ® ■ _ ■■ 11 11■ ■■■111 1 . . 7500 ■�� II 111111 - i ii �i 1 ■ ■ i ®iii _ _ OD' K -4 1PB1 upF -9000 ■ I -10500 I l i, ! I I I I I I I I I I I I I I I I I I r I I I I I i 1 i 7 r r I 1 1 I f I I I! 1 1 1 1 - 1 1 1 1 1 1 1 1 1 1 1 11 1 11 I 1 1 1 1 1 II -16500 -15000 -13500 -12000 -10500 -9000 -7500 -6000 -4500 -3000 -1500 0 1500 3000 4500 6000 7500 9000 10500 West( -) /East( +) (3000 ft/in) is ii I Legend ti ° . 'h o 1 1 J ii. ' liti 41 As —built Conductor R ° 4 3 • ` ProJset eetlon to o Iii • ° ° tig -' — 9 4 1 N !a 1. - ri• . i 'I .. M ..Nri . \o 4 44 41' 0 ° e do Location Map GRAPHIC SCALE <V • 30 0 30 o 4s 446 4,‘00141111411u . • 1 «.> .,� • / • • C •' •d •• ••''Ss4. 11 I 1 WO -aob �g 0 /. 0� 0 ,y � •r (— e e • '7 016 or 4‘ 0 4* e.g.,' , - . , (4 , a 0• N • • . ......a • ; O ° o t; % I lip G. Davis i Nil. .% No. 4110.S •c, •• j s • • 4' 419 • •„ Ilo 0 0 •9 ��p�M O s E ESSIONAL ti `� 'Po e•••e• �Pa+ 4' • 0 4% 0 e b i 4V I'll • ll' � 0 _ {�i .11 t • ° 0 i r , o _... { o 0 0 Pioneer Natural Resouoes JOB NAME: Oooguruk Drill Site DRAWN BY: BL 'CHECKED BY: M,ID • LOCATION: Protracted Section 11 SCALE: 1 " -3o' Township 13 North Range 7 East DATE: 7 -12 -07 Umiot Meridian Notes: NANUQ JOB NO. SHEET Coordinates are listed on sheets 3 and 4 DESCRIPTION: Alaska Nod 27, Zone 4 Conductor As —built Plan 05204 1 of 4 • i s 1° 1 + • _ . 3 I 1 t s 1 i t , • _ �islrict Boundry _ , , i ` � OO SITE Corner of a - Protracted Section" 11 I as y= /1 " 7 s a o 1 • Coordinates I i i N 6028111.04 i I E 470989:01 I . n Ii w -25 . ■ • I ' , i Ref: AK BLM % • I, cc ; " S • ` 1 f Harrison. Bay Tract "A" -24\ - .. Drawing a a 1 a l� Offshore Iterood =5.99 Mlles ♦,. `\ �� • eor Shore leerood =3.82 a 1 3 e PI 20 to a • • •. ruk Site •• PI 7 to PI 20 : x - A a as y* N. y , a k: - a . • P.1-2fi 1 /'" P! — ) 1 74 �, )116 i % ` .7.- ^ ,_ Pi-17 Tundra leers; . ..h p._ ; ♦ i)S 1 - m .. a . �� PI- - I ' Roods to I d /fv',t I PI - 1 1)1-19 ' I Sli.. - ). s • Basis of Location j�r PP" 8 U C � ) f ;' i - Basis West Monument Pr q • ' V ;a • - { Coordinates Audi JI ; rs N 6001016.61 - - E 498081.23 •STAKED PI INFORMATION ONLY ' p 4 . n: "• ° . 11 m ! \ = l! * „ Ref. Lownsbury &Assoc. L eo D ':,C I c Drawing No. ill + mix _ --- NSK 6.01 —d672 '` �� N OF A •( 1 ti y • I/ •.• Cam. • .'•. ,� A rM a� R / * � _ , � *� 1 f i„ t i I / • 4 ti f o relyr id . gas. ID 1,k" $ • nip G. Davis : o • 141 } • �t No.4110.5 -1 " , 1 1 9 4 0 •N • . ... »..••• �� e' OPESSIOt4M. ‘•.�► �ta..w.• Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 East DATE: 7 -12 -07 Umiat Meridian NANUQ JOB NO. SHEET DESCRIPTION: Basis of Location • 05204 2 of 4 Alaska State Plw • lt Latitude u „,, E . . c7L -.ec i n .ne elf . e- , ev, We NQ, ---_____* - - __ - ___ I__:_ - _:..______. _- tidN9 Longtude _-__:___:_-____ Pad i - -- V X - - .- - • F FEL .* 1 5,031,151,32 469,920,4.5 70 29 46,24150 150 14 45,46468 3035 1077 -- 13,50 -4-- ' 6,031,145,35 9,912 70 29 46,19252 150 14 45,60922 3on - 1082 , 1$,s11 .. . , . 6,031,141,39 469,910,59 70 29 46,14354 150 14 45,75375 3025 1007 •- 4 .. 6,031,136.46 469,905,57 • 70 29 46.09485 15014 45,89799 3020 1092 13.50 5 6,031,131:45 469,90.74 204604538 15014 45,04252 3015 - 1097 - 13,50 6 5,031,126,51 469,895,0 70 29 45,99660 150 14 46,18735 3010 1102 13,50 7 6,031,113,73 469,083,13 70 29 45,87039 150 14 45,55079 2997 1115 ' 13,50 8 --- 6,031,108,73 469,075.21 70 29 45,82102 150 T4 46,7030 2992 1120 7-7 11:50 - . 9 6,03 469,873,26 70 29 45.77184 150 14 46,84814 2987 1125 , 13,50 : . 10 6,031,098,79 469,868,36 70 29 45,72256 150 14 46,99179 2902 1130 T • 13,50' . 11 6,031,093,04 469,663,39 70 29 45,67396 150 14 47,13750 2977 1135 - 13,50 - 12 6,031,088,57 469,658,47 70 29 45,62490 150 14 47,25174 2972 1140 1 - >■•• 13 6,031,076,06 469,845,01 70 29 45,49640 150 14 47,65288 2960 . 1152 • 13,50 14 6,031,071,09 469,640,67 70 29. 45,44932 150 14 47,7977CY 2955 1157 •13,50 • •• 15 6,031,066.15 469,635,96. 70 29 45,40053 150 14 47,94165 2950 1162 - 13,50 16 6,031,061,18 - 469,831,04 70 29 45,35145 150 14 48,06558 no 1157 13,50 17 6,031,056,25 469,826,11 70 29 45,30277 150 14 48,23042 2940 1172 13,50 13 6,031,051,27 469,621,10 70 29 45,25359 150 14 48,37495 2935 1177 13,50 19 6,031,038,52 ---- 469,808,50 70 2945,12768 150 14 4V4563 1169 luo 20 6,031,033,50 - 469,303,59 70 2945,078117 150 14 45,8906f 2917 . 1194 1350 • • . 21 6,031,026:53 469,798,62 70 29 45,02903 150 14 49,03632 2912 1199 13,50 - 22 6,031,023,58 469,793,67 70 29 44,98014 150 14 49,16144 2907 1204 . 13,50 • , 23 6,031,018,57 469,788,76 70 29 44,93067 150 14 49,32537 2902 1209 • • 13.50 • 24 6,031,013,60 459,78384 70 29 44,00159 150 14 49,46960 2897 1214 13,50 . .74s. " . _to . ,-p- ' %• .7 4 .-* 1 • : 9T .,'` • or . . ,.......row - _ _: -,::-:---, • , • • • ••• --tart ra : Philip G. Davis I,/ • - r :4-*2.,,..:.:;.:.:::::.f.,, 7 .,:. No 41104 " 441 ...- ''..1 kAV , 4 :::. ' '' ' .: '? 'P • . ..."Alit : . 7 0 W Oe .......f " 7 e 4 '',;.: ..:'..-:.) :*'-'.W" ;.: k 11: SteN Ott. %.1'' 4r . liekOMMI•14111' .. •iL :14 % • 'V .. C, ...t ,i 'Zi!; 4 47 '. 4; - :• 1: . . • N-.):: . - ,t''' ..' • ''%& --, ,`;t4"_ ,. . , • • Notes; ...44, 1, Elovotions QM bosod on BP Mean Sea Level, --.._: 2, Coordinates are based on Alaska State Plane Nod 27, Zone 4, , 3, Alt conductors are • within Protracted Section 11, . Pioneer Natural Re-sauces . • JOB NAME; 0.oQgurt,4k C)rill Site Conductors DRAWN BY: BL CHECKED BY: MD LOCATION; Protracted Section 11 SCALE: N/A Township 13 North * an 7 Edst DATE: 7-12-07 • V_ rniot Meridian • NANIJC) JOB NO. SHEET -- DESCRIPTION: As-built Coordi • notes 05204 3 of 4 _____ Well No. - Alaska State P Section Line Offset Latitude (N) Longitude Pad Elev. FSL FEL 25 6,031,128.32 469,943.64 70 29 46.01630 150 14 44.77930 3013 1055 13.50 26 6,031,123.35 469, 938.69 70 29 45.96722 150 14 44.92442 3008 1060 13.50 27 6,031,118.33 469, 933.76 70 29 45.91765 150 14 45.06895 300 1065 13.50 28 6,031,113.39 469, 928.86 70 29 45.86887 150 14 45.21260 2997 1070 13.50 29 . " 6,031,108.44 469, 923.95 70 29 45.81999 150 14 45.35655 2992 1075 13.50 30 6,031,103.45 469,919.01 70 29 45.77071 150 14 45.50137 2988 1079 13.50 31 6,031,090.65 469,906.38 70 29 45.64431 15014 45.87163 2975 1092 13.50 32 6,031,085.68 469,901.39 70 29 45.59523 150 14 46.01793 2970 1097 13.50 33 6,031,080.67 469,896.50 70 29 45.54576 150 14 46.16128 2965 1102 13.50 34 6, 031, 075.73 469, 891.57 70 29 45.49698 150 14 46.30581 2960 1106 13.50 35 6, 031, 070.76 469, 886.60 70 29 45.44789 150 14 46.45152 2955 1111 13.50 36 6,031,065.83 469,881.69 70 29 45.39921 150 14 46.59547 2950 1116 13.50 37 6,031,053.00 469,869.00 70 29 45.27251 150 14 46.96749 2937 1129 13.50 38 6,031,047.99 469,864.14 70 29 45.22304 150 14 47.10995 2932 1134 13.50 39 6,031,043.03 469,859.20 70 29 45.17406 150 14 47.25478 2927 1139 13.50 40 6,031,038.10 469,854.21 70 29 45.12537 150 14 47.40108 2922 1144 . 13.50 41 6, 031, 033.05 469, 849.29 70 29 45.07551 150 14 47.54530 2917 1149 13.50 42 6, 031, 028.13 469,844.38 70 29 45.02692 150 14 47.68925 2912 . 1154 13.50 43 6, 031, 015.46 469,831.70 70 29 44.90180 150 14 48.06099 2899 1166 13.50 44 6,031,010.49 469,826.79 70 29 44.85272 150 14 48.20493 2894 1171 13.50 45 6,031,005.53 469,821.86 70 29 44.80373 150 14 48.34946 2889 1176 13.50 46 6,031,000.54 469,816.94 70 29 44.75446 150 14 48.49369 2884 1181 13.50 47 6,030,995.50 469,811.98 70 29 44.70469 150 14 48.63910 2879 1186 13.50 48 6,030,990.58 469,807.07 70 29 44.65610 150 14 48.78304 2874 1191 13.50 SURVEYOR'S CERTIFICATE 4� 1i ; �P. �. OF "••.lam. �, I HEREBY CERTIFY THAT I AM - '3 / ` . • • ti -pp PROPERLY REGISTERED AND • / it 4 ' N * LICENSED TO PRACTICE LAND ••• ••'• SURVEYING IN THE STATE OF O . . • ilia G. .Davis ALASKA AND THAT THIS PLAT � . c REPRESENTS A SURVEY DONE BY .' • No. 41104 ; a4 ME OR UNDER MY SUPERVISION . t ti ' • _ • SJ ,0 � AND THAT I BELIEVE THAT ALL s 'r d iv r �; / ; 4 0 fSS10N 70)"x► DIMENSIONS AND OTHER DETAILS i� � ` ��,� w ye► ARE CORRECT AS SUBMITTED TO r ME BY NANUQ, INC. AS OF JULY zr 12TH, 2007. Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD, LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 East DATE: 7 -12 -07 Umiat Meridian NANUQ JOB NO. SHEET DESCRIPTION: As -built Coordinates 05204 4 of 4 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 AEO 2 6000000 - - -- - - -_ - - _ ODSK -13i l AEO 1 5950000 9 5900000 40 CFR 147.102 (b)(3) 5850000 400000 500000 600000 700000 800000 Oooguruk ODSK -13 Injector — Area of Review Commingled Injector, Nuiqsut and Kuparuk Oil Pools ODSN -31 080030 15990 ,D,„, Nuiqsut Pool OD 1 1 3 4 Kuparuk Pool > .Q moo V, ODSN -37 , 0 0 • •81570 15708 p ODSN -34 / ODSN -32 6 840 17179 - 080040 13344 isw 3 16030 2 u0ro ,... 1 13000 11000 10003 1a000 i :am S ODSK -35 , �: o � 0 ° °`° G •071810 14790 „000 1.000 ... A 7 z" 8 0 ODSN -39 .1000 0 813 . 7r: t • !800 17328 133u0 X. r Otto . 10000 v Y � 3000 0000 3000 • X00 1 000 r .as, oDSN 40 s00o 00 1 ,1t. - " 080390 10807 I • 1 1000 i i 1 .. ...�'•' f ' ' 0 10003 a a. fill* ALUBIKi.' ,O 0130 8273 M ). ODSN - 43 X33 �°°° � %►. ' ?8 1390 22837 t r y ...... S • DSK -33PB1 ''': , ?,6ft30 8730 - -1=' — .4, A me AOGCC SFD 11/18/2009 • TRANSMITTAL LETTER CHECKLIST WELL NAME Oooguruk ODSK -13 PTD# 209146 Development X Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: Oooguruk POOL: Oooguruk - Kuparuk Oil Pool Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , Permit No. (If last two digits in API No. . Production should continue to be API number are reported as a function of the original API number stated above. between 60 -69) PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 ,."1,,.r— -_.- t t Field & Pool 000GURUK, KUPARUK OIL - 576100 000GURUK, NUIQSUT OIL - `. Well Name: 000GURUK KUP ODSK -13 Program SER Well bore seg ❑ PTD#: 2091460 Company PIONEER NATURAL RESOURCES ALASKA INC Initial Class /Type SER / PEND GeoArea 973 Unit 1.1550- On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Entire well will lie within ADL 355036 3 Unique well name and number Yes Oooguruk- Kuparuk injector that will eventually become a commingled injector into the Nuiqsut pool as well. 4 Well located in a defined pool Yes 000GURUK, KUPARUK OIL - 576100 governed by CO 596 and, eventually, 5 Well located proper distance from drilling unit boundary Yes 000GURUK, NUIQSUT OIL - 576150 governed by CO 597. 6 Well located proper distance from other wells Yes No restrictions in either CO 596 or CO 597 other than >500' from external property line 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is welibore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes SFD 11/18/2009 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For Yes AIO 33 and 34 • 15 All wells within 1/4 mile area of review identified (For service well only) Yes None 16 Pre-produced injector: duration of pre production less than 3 months (For service well only) Yes 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A -D) NA 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs NA No Aquifers... 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg No TOC planned for 9929' and 22 CMT will cover all known productive horizons Yes Production casing cemented and perfed 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells._ 125 If a re- drill, has a 10-403 for abandonment been approved NA 26 Adequate welibore separation proposed Yes Proximity analysis performed. Minor risk with ODSK -14 . 1 27 If diverter required, does it meet regulations NA Diverter Waiver approved per AAC 15.035 (h) (2) Appr Date 1 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure= 3186 psi (9.7 ppg EMW) .. Will drill with 10.5 ppg and MPD for hole Stability GLS 11/19/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 2491psi Will test BOPs to 4500 psi 131 Choke manifold complies w /API RP -53 (May 84) Yes • 32 Work will occur without operation shutdown No 33 Is presence of H2S gas probable No Np H2S on Pad. Rig has alarms and sensors. 34 Mechanical condition of wells within AOR verified (For service well only) Yes AOR complete. No wells in Kup or Nuiqsut with 1/4 mile. 35 Permit can be issued w/o hydrogen sulfide measures Yes None anticipated, but sensors will be employed. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is up to 9.7 ppg EMW; will be drilled using 10.5 ppg mud Appr Date 37 Seismic analysis of shallow gas zones NA and managed pressure drilling technique to maintain borehole stability. SFD 11/18/2009 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering i' ■ •lic Pre - produced Oooguruk - Kuparuk injector that will, upon Commission approval, eventually be converted to a dual, commingled Commissioner: Date: Com ission Date l . l Date injector for the Oooguruk - Kuparuk and Oooguruk - Nuiqsut Oil Pools. i iii —� oner if -z.?- o cv.... . --- 9. .aq - ‘44Cp JUN 17 LOU 21,3 k5 CI LETTER OF TRANSMITTAL CA1 DATA LOGGED n � y Alaska ,o,23,zow M.K.BEN& te® 30 0 47.011 0t S4paimmommillill DATE: June 16, 2016 V arommummimmillii OGCC Shannon Koh a ttn: Makana Bender Caelus Energy Alaska 333 W. 7th Avenue, Suite 100 3700 Centerpoint Dr., Suite 500 •nchorage, AK 99501 a nchorage, AK 99503 INFORMATION TRANSMITTED ❑ Maps ❑ Letter Other- Binders ❑ CD-R ❑ Agreement DETAIL DESCRIPTION QTY Palynostratigraphy of a short section: ODSN-031(50-703-20689-0000) 3 binders (CD included) ODSNf07i(50 703-20725-0000) 22300 ft.—23208 ft. ODSK-13PB2(50-703-20607-7100) 10700 ft.— 11178 ft. '/4412 05., A Date: Received by: / Please sign and return one copy to: Caelus Energy Alaska ATTN: Shannon Koh 3700 Centerpoint Dr., Suite 500, Anchorage, AK 99503 907-343-2193 fax 907-343-2128 phone shannon.koh caelusener .corn Palynostratigraphy of a Short Section in the Pioneer Natural Resources K13PP2 Well Oooguruk Area, Alaska North Slope (10,700 ft - 11,178 ft) 1 ) !1 ---7, .,----:- 't_3 1 • 4„ #. ( ...___ _. .._..... )) -c - fy , } I f l r;...- '.4j4!*,,,r 11117211. - fir - �, .. - f 1 ji f :1.. -'7-- 4::: . • May 2016 Offi, the irf group, inc. consulting paleontologists anchorage • houston • dallas • toronto • tulsa /2-40°s -\.2cp Palynostratigraphy of a RECEIVELP Short Section in the JUN 17 20 Pioneer Natural Resources .4 es K13PB2 Well, Oooguruk Area, Alaska North Slope (10,700 ft — 11,178 ft) May 2016 r the irf group, inc. consulting paleontologists 6721 round tree drive anchorage, ak 99507 907.346.4090 www.irfgroup.com anchorage • houston • dallas • toronto • tulsa 1 Palynostratigraphy of a Short Section in the Pioneer Natural Resources K13PB2 Well, Oooguruk Area Alaska North Slope, (10,700 ft — 11,178 ft) the irf group, inc. May 2016 Synthesis A biostratigraphic profile is developed for a short interval in the Pioneer Natural Resources K13PB2 well (Figure 1), North Slope, Alaska, based on organic-walled microfossils. The goals of the study are to build a chronostratigraphic framework (Figure 2)for the well section and to develop a comprehensive suite of biological attributes (Figures 3,4 and 5) that can be utilized in future sequence stratigraphic, depositional framework, and regional correlation models. The entire section examined between 10,700 ft and 11,178 ft and lies within the upper Kingak • Formation, and is Kimmeridgian (Late Jurassic) to questionably Callovian (Middle Jurassic) in age. The samples contain well-preserved and diverse palynomorph populations (consisting of dinoflagellates, acritarchs, pollen, spores,fungal cells,and miscellaneous algae). A total of 146 microfossil taxa were identified in the well; the palynology assemblages also contain a moderately diverse population of reworked specimens. Quantitative palynological census data were collected for all samples. These data sets, along with a variety of summary paleontological tracks and statistical analyses, are used both to develop the initial age interpretation for the well, and to provide a robust and useful framework for future regional correlation studies. Results The uppermost occurrence of the key Oxfordian (Upper Jurassic) stage indicator marine dinoflagellate cyst Nannoceratopsis pellucida is at 10,850/75 ft. We interpret this distribution as indicating that the section examined from 10,700 ft to 10,850 ft lies within the Kimmeridgian stage. Virtually everywhere in the North Slope region, Kimmeridgian and Oxfordian strata are characterized by a very rich and diverse marine dinocyst population, and many other characteristic forms are present, including Chytroeisphaeridia hyalina, C. cerastes, Atopodinium prostatum, Pluriarvalium osmingtonense, Rhynchodiniopsis cladophora, Valvaeodinium groenlandicum, Rigaudella filamentosa, Scriniodinium galeritum reticulatum. and Fromea tornatilis. Also present, and characteristic of the North • Slope area, is a marine acritarch form believed not to be described formally in published literature, here designated Nummus sp. 1. PNR K13 PB2 the irf group,inc. 2 • The uppermost occurrence of the as yet undescribed dinocyst designated here as Chytroeisphaeridia "verrucosa" is at 10,950/75 ft. This form has been seen in many wells around the Colville Delta area, and constitutes one of the more important stratigraphic indicators in this section. It appears to occupy a very narrow stratigraphic interval, and we regard its uppermost observed occurrence (in this well at 1,0950/75 ft) as questionably indicative of the Callovian stage. One other stratigraphically important dinocyst, designated Balcattia-1 (again not formally described in publication), which is often seen at a horizon slightly above that of C. "verrucosa", and present in many Colville Delta area wells, was not observed in K13PB2. Terrestrial forms (pollen and spores) are also abundant, but most are long-ranging types that are known to extend upward into Cretaceous strata. One exception is another undescribed probable gymnosperm pollen designated here as "monosaccate trilete sp. 1", only seen in Upper Jurassic strata in the region. Reworked Mississippian plant spores derived from the Kekiktuk Formation are abundant, typical for the upper Kingak section everywhere. The K13PB2 well is a more nearly vertical penetration, and as a consequence, contains a large percentage of material clearly caved from overlying Lower Cretaceous strata of the Kalubik Formation. This material is easily recognized, however, as the Kalubik palynological • population, especially for marine species, contains virtually nothing in common with the older upper Kingak population; accordingly, such forms were not recorded in the data. Overall, the K13PB2 palynological population and distribution compares closely with that observed in a stratigraphically similar section of the NO3i and N07i wells, examined concurrently. I,f -i a . ,. 3 J Ss , ;;,..;„, ,t.,:0,4. , ...:;,_, '.,�l Y.,,,Y--.4,A7-4: .47 ,4 6 1 . fir. • Chytroeisphaeridia "verrucosa" Nannoceratopsis pellucida P P PNR K13 PB2 the irf group,inc. 3 • Palynological analysis was performed by Robert L. Ravn (the irf group), while report integration, numerical analyses, and graphics were completed by David Goodman (the irf group). Analytical Approach Our intent is to present the biological data within the context of a dynamic interpretation environment in which all original and derived data sets are documented and displayed in a style that permits evaluation of the results of this study and re-interpretation at any time in the future. These data sets are the result of a complex set of biological and physical parameters, and a suite of reasonable interpretations can be formulated within the constraints of the acquired data. Thus, we propose our preferred interpretations, but both realize and invite alternate views by other analysts and interpreters. We strongly feel that this dynamic interpretive mode is vastly superior to the more typical (and effectively static) approach of providing an age interpretation over a specified stratigraphic interval with little or no supporting documentation other than listing several range events that occur within the interval. • Our fundamental approach to biostratigraphy differs from that utilized by many other consulting groups. We purposely separate the tasks of data acquisition (sample analysis) and interpretation (chronostratigraphic models, statistical analyses, and biofacies calculations). all biological components in the samples based on detailed systematic identification, and (2) attention to detail in collecting census data on all species, or other taxonomic entities, identified. This results in an initial data set for the well which exhibits considerable dimensionality and for which no a priori decisions have been made by the analyst that would exclude taxa with biostratigraphic, chronostratigraphic, or paleoenvironmental significance. The assemblage summary attributes (group total abundances, percentage abundances, selected ratios) and other statistical parameters (similarity coefficients, diversity indexes,) derived from the initial data matrix exploit this more complex dimensionality and therefore have enhanced potential for more detailed stratigraphic characterization, subdivision, and correlation than is possible with reduced occurrence data sets. Analytical Parameters Each sample was evaluated in terms of a quantitative census analysis of the organic-walled microfossils. Quantitative census data increase the "dimensionality" of the final data set and allow a wide range of numerical and statistical analyses to be performed on the data set, in contrast to either "presence-absence" or "semi-quantitative" (also known as abundance estimates), for which further statistical analyses are either not possible, or produce invalid or misleading results. A sample set of approximately 200 identifiable specimens was counted for each sample wherever possible; additional species not encountered in the initial 200 grain • count, but identified during subsequent examination of the microscope slides, were added to the final counts, thereby affecting the number of specimens and increasing the counts to more PNR K13 PB2 the irf group,inc. 4 than 200 in most of the samples. A complete listing of all 146 species identified in the well is given in Appendix I. Primary data include the quantitative and stratigraphic distribution of the microfossils. Twenty-three derivative data sets, or assemblage attributes, are also included in this report (Figure 3). These derivative tracks are used to enhance the primary data and to summarize the geological and biological history of the well section in terms that are more useful than simple range data alone. These tracks can be used to make more detailed interpretations of depositional system architecture, identify possible stratal discontinuities, and to characterize stratigraphic intervals using biological content. The summary tracks recorded for the KI3PB2 section include: • Marine Percentage Abundance • Marine Total Abundance • Dinoflagellate Total Abundance • Acritarch Total Abundance • Microforam Total Abundance • Terrestrial Total Abundance • Pollen Total Abundance • Spore Total Abundance • Miscellaneous Algae Total Abundance • Total In Situ Diversity • Marine Species Diversity • Terrestrial Species Diversity • • Marine Richness Ratio • Terrestrial Richness Ratio • Marine Simpson Diversity Index • Terrestrial Simpson Diversity Index • Marine Shannon-Weaver Diversity Index • Terrestrial Shannon-Weaver Diversity Index • Reworked Total Abundance • Reworked Devonian Abundance • Reworked Kekituk(Mississippian)Abundance • Reworked Lower Mesozoic Abundance • Reworked Diversity 1111 PNR K13 PB2 the irf group,inc. 5 • Display Panels Biostratigraphic results for the well section are illustrated in the following display panels: Figure 1. Location Map. Figure 2. Well Summary. Figure 3. Palynology Assemblage Parameters. Figure 4. Palynomorph Quantitative Distribution Chart. Figure 5. Palynomorph Interval Range Chart. Appendixes Appendix 1. Species list, sorted by major microfossil group. Appendix 2. Range events. • Data Archive (CD) All hardcopy components of this report are included as digital files on the attached CD. The files are platform-independent files: RICH TEXT FORMAT (.rtf), EXCEL (.xls), or PORTABLE DOCUMENT FORMAT (.pdf). The CD files include: K13PB2Rept.doc - Report Text K13PB2App1.r doc - Appendix 1 K13PB2App2. doc - Appendix 2 Ki3PB2Data.xls - Occurrence Data K13PB2Sums.xls -Assemblage Statistics K13PB2Figl.pdf - Figure 1 K13PB2Fig2.pdf - Figure 2 K13PB2Fig3.pdf - Figure 3 K13PB2Fig4.pdf - Figure 4 K13PB2Fig5.pdf - Figure 5 Local Correlation A local correlation model based on biostratigraphic data will follow. The model incorporates data from a number of earlier wells in the area, and will include a detailed statistical RASC (Ranking & SCaling) model to identify and sequence additional range events (range tops and bases) recognized to provide enhanced age calibration and regional correlation parameters • for the Kimmeridgian through Callovian Kingak section in the area of interest. The following PNR K13 PB2 the irf group,inc. 6 • twelve wells (four new wells analyzed in 2016 and eight earlier regional control wells) are included in the RASC analysis and regional synthesis : Colville Delta 2 DW144 Ivik 1 K 13PB2 2016 K42i Kalubik 1 Kalubik 3 N01A 2016 NO3i 2016 N07i 2016 Oooguruk 1 Thetis Island 1 • • PNR K13 PB2 the li f group,inc. Pioneer K13PB2 Appendix 1 Species List - - "I Pioneer Natural Resources K13PB2 Appendix 1: Species List (146 taxa recovered) Marine Palynomorphs (55 taxa) Acritarchs & Tasmanitids (6 taxa) cf. Gorgonisphaeridium spp. - indet. Micrhystridium sp. - indet. Pterospermella aureolata Pterospermella australiensis "Veryhachium" sp. - large, triangular "Veryhachium" sp. - small, triangular Dinoflagellates (49 taxa) • Atopodinium prostatum Caddasphaera halosa cf. Comparodinium sp. - granulose Chlamydophorella ectotabulata "Chlamydophorella" sp. 2 - large, irregular Chytroeisphaeridia "verrucosa" Chytroeisphaeridia cerastes Chytroeisphaeridia hyalina Crussolia deflandrei Domasia liassica Egmontodinium diminutum Ellipsoidictyum sp. -indet. Escharisphaeridia pocockii Escharisphaeridia sp. - indet. Evansia sp. - indet. Fromea tornatilis Gochteodinia villosa multifurcata Gonyaulacysta oligodentata Jansonia jurassica Kalyptea stegasta Lithodinia borealis Lithodinia cf. callomonii S Lithodinia sp. - indet. Meiourogonyaulax cf. decapitata -2- • Nannoceratopsis pellucida Nummus sp. 1 Paragonyaulacysta calloviensis Pareodinia brachythelis Pareodinia ceratophora Pareodinia sp. E of Wiggins 1975 Pareodinia spp. - indet. Pluriarvalium osmingtonense Rhynchodiniopsis cladophora Rhynchodiniopsis spp. -indet. Rigaudella filamentosa Rosswangia holotabulata Scriniocassis weberi Scriniodinium crystallinum Scriniodinium galeritum galeritum Scriniodinium galeritum reticulatum Sentusidinium asymmetricum Sentusidinium sp. - indet. Tubotuberella apatela Tubotuberella lurida Tubotuberella rhombiformis Valensiella magna S Valensiella ovula Valensiella spp. - indet. Valvaeodinium groenlandicum Terrestrial Palynomorphs (49 taxa) Pollen (11 taxa) bisaccate gymnosperm pollen - indet. Cerebropollenites macroverrucosus Corollina torosa Cycadopites nitidus Cycadopites sp. -indet. Eucommiidites troedssonii Exesipollenites tumulus Perinopollenites elatoides Podocarpidites canadensis Podocarpidites multesimus Podocarpidites spp. - indet. -3 - • Spores (37 taxa) Alisporites grandis Anapiculatisporites cf. telephorus Antulsporites clavus Antulsporites? sp. - indet. Biretisporites potoniei Calamospora nigrata Callialasporites dampieri Callialasporites lucidus Callialasporites segmentatus Callialasporites trilobatus Concentrisporites angulosus Crassitudisporites problematicus Deltoidospora mesozoica Deltoidospora spp. -indet. Densoisporites velatus Densosporites "tralaui" Foraminisporis jurassicus Gleicheniidites minor Ischyosporites spp. - indet. Laevigatosporites spp. - indet. • Leptolepidites verrucatus Matonisporites sp. - indet. monosaccate trilete sp. 1 Nevesisporites cf. vallatus Osmundacidites wellmanii Retitriletes clavatoides Retitriletes gracilis Retitriletes spp. - indet. Rogalskaisporites cicatricosus Sculptisporis sp. - indet. Sestrosporites pseudoalveolatus Staplinisporites caminus Stereisporites cf. australis Stereisporites perforatus Stereisporites spp. -indet. Trachysporites fuscus Vitreisporites pallidus Miscellaneous Freshwater Algae (2 taxa) Lecaniella cf. foveata - coarse ornament Lecaniella sp. - indet. -4- • Reworked Palynomorphs (41 taxa) Reworked Devonian (4 taxa) Grandispora sp. - indet. Retispora cassicula Retispora lepidophyta Samarisporites sp. - indet. Reworked Kekituk (32 taxa) Callialasporites turbatus Cingulizonates sp. 1 of Ravn 1991 Cirratriradites? sp. 1 of Ravn 1991 Corbulispora cancellata Corbulispora margodentata Crassispora sp. - indet. Cristatisporites sp. -indet. Densosporites pseudoannulatus Densosporites spp. - indet. Densosporites variomarginatus • Gorgonispora multiplicabiis Grandispora cf. echinata of Ravn 1991 Knoxisporites triradiatus Labiadensites fimbriatus Lophozonotriletes appendices Lophozonotriletes spp. - indet. Lophozonotriletes triangulatus Lycospora pusilla Lycospora subtriquetra Monilospora moniliformis Murospora aurita Murospora complicata Murospora intorta Murospora tripulvinata Platyptera incisotriloba Punctatisporites spp. - indet. Radiizonates cf. aligerens Reticulatisporites sp. -indet. Retusotriletes spp. - indet. Spelaeotriletes cf. triangulus "Spelaeotriletes" spp. - indet., small Waltzispora polita • -5- • Reworked Lower Mesozoic (5 taxa) Kyrtomisporis laevigatus Lunatisporites noviaulensis Radiizonates "asperatus" taeniate bisaccate pollen - indet. Uvaesporits sp. - indet. • • Pioneer K13PB2 Appendix 2 Range Events • Pioneer Natural Resources K13PB2 Appendix 2: Range Events Key LAD: Last Occurrence Datum (range top) FAD: First Occurrence Datum (range base) Range Event Depth (ft) bisaccate gymnosperm pollen - indet. [LAD] 10700 Deltoidospora spp. - indet. [LAD] 10700 Osmundacidites wellmanii [LAD] 10700 Retitriletes spp. - indet. [LAD] 10700 Corollina torosa [LAD] 10700 Exesipollenites tumulus [LAD] 10700 Callialasporites dampieri [LAD] 10700 Stereisporites spp. - indet. [LAD] 10700 Deltoidospora mesozoica [LAD] 10700 Matonisporites sp. - indet. [LAD] 10700 • Densoisporites velatus [LAD] 10700 Trachysporites fuscus [LAD] 10700 Lecaniella sp. - indet. [LAD] 10700 Chytroeisphaeridia hyalina [LAD] 10700 Pareodinia sp. E of Wiggins 1975 [LAD] 10700 Valensiella spp. - indet. [LAD] 10700 Rhynchodiniopsis spp. - indet. [LAD] 10700 Densosporites spp. - indet. [LAD] 10700 Lycospora pusilla [LAD] 10700 Punctatisporites spp. - indet. [LAD] 10700 Knoxisporites triradiatus [LAD] 10700 Densoisporites velatus [FAD] 10700 Trachysporites fuscus [FAD] 10700 Lecaniella sp. - indet. [FAD] 10700 Cerebropollenites macroverrucosus [LAD] 10725 Alisporites grandis [LAD] 10725 Perinopollenites elatoides [LAD] 10725 Staplinisporites caminus [LAD] 10725 Sculptisporis sp. - indet. [LAD] 10725 Eucommiidites troedssonii [LAD] 10725 Ischyosporites spp. - indet. [LAD] 10725 Pluriarvalium osmingtonense [LAD] 10725 • "Veryhachium sp. - small, triangular [LAD]" 10725 Scriniodinium galeritum reticulatum [LAD] 10725 2 • Range Event Depth (ft) Chytroeisphaeridia cerastes [LAD] 10725 Lithodinia borealis [LAD] 10725 cf. Gorgonisphaeridium spp. - indet. [LAD] 10725 Retispora lepidophyta [LAD] 10725 Antulsporites clavus [LAD] 10750 Vitreisporites pallidus [LAD] 10750 Concentrisporites angulosus [LAD] 10750 Sestrosporites pseudoalveolatus [LAD] 10750 Callialasporites segmentatus [LAD] 10750 Lecaniella cf. foveata-coarse ornament [LAD] 10750 Biretisporites potoniei [LAD] 10750 Caddasphaera halosa [LAD] 10750 Nummus sp. 1 [LAD] 10750 Tubotuberella apatela [LAD] 10750 Pterospermella australiensis [LAD] 10750 Uvaesporits sp. -indet. [LAD] 10750 Murospora aurita [LAD] 10750 Cristatisporites sp. - indet. [LAD] 10750 Lycospora subtriquetra [LAD] 10750 Sestrosporites pseudoalveolatus [FAD] 10750 Callialasporites segmentatus [FAD] 10750 • Lecaniella cf. foveata-coarse ornament [FAD] 10750 Biretisporites potoniei [FAD] 10750 Tubotuberella apatela [FAD] 10750 Uvaesporits sp. - indet. [FAD] 10750 Lycospora subtriquetra [FAD] 10750 Laevigatosporites spp. - indet. [LAD] 10775 Podocarpidites canadensis [LAD] 10775 Stereisporites perforatus [LAD] 10775 Tubotuberella lurida [LAD] 10775 "Chlamydophorella sp. 2-large, irregular [LAD)" 10775 Ellipsoidictyum sp. - indet. [LAD] 10775 Crussolia deflandrei [LAD] 10775 Pareodinia spp. - indet. [LAD] 10775 Gorgonispora multiplicabiis [LAD] 10775 Corbulispora cancellata [LAD] 10775 Corbulispora margodentata [LAD] 10775 Lophozonotriletes triangulatus [LAD] 10775 Platyptera incisotriloba [LAD] 10775 Stereisporites perforatus [FAD] 10775 Tubotuberella lurida [FAD] 10775 Ellipsoidictyum sp. - indet. [FAD] 10775 Crussolia deflandrei [FAD] 10775 • Gorgonispora multiplicabiis [FAD] 10775 Corbulispora cancellata [FAD] 10775 3 • Range Event Depth (ft) Corbulispora margodentata [FAD] 10775 Podocarpidites spp. - indet. [LAD] 10800 Podocarpidites multesimus [LAD] 10800 Gochteodinia villosa multifurcata [LAD] 10800 Meiourogonyaulax cf. decapitata [LAD] 10800 Pareodinia brachythelis [LAD] 10800 Scriniodinium galeritum galeritum [LAD] 10800 Evansia sp. - indet. [LAD] 10800 Jansonia jurassica [LAD] 10800 Scriniodinium crystallinum [LAD] 10800 Matonisporites sp. - indet. [FAD] 10800 Podocarpidites canadensis [FAD] 10800 Gochteodinia villosa multifurcata [FAD] 10800 Evansia sp. - indet. [FAD] 10800 Rogalskaisporites cicatricosus [LAD] 10825 Densosporites"tralaui" [LAD] 10825 Retitriletes gracilis [LAD] 10825 Escharisphaeridia pocockii [LAD] 10825 Rigaudella filamentosa [LAD] 10825 Atopodinium prostatum [LAD] 10825 Sentusidinium sp. -indet. [LAD] 10825 • Lophozonotriletes spp. -indet. [LAD] 10825 Lophozonotriletes appendices [LAD] 10825 Monilospora moniliformis [LAD] 10825 Ischyosporites spp. - indet. [FAD] 10825 Rogalskaisporites cicatricosus [FAD] 10825 Densosporites"tralaui" [FAD] 10825 Retitriletes gracilis [FAD] 10825 Rigaudella filamentosa [FAD] 10825 Sentusidinium sp. - indet. [FAD] 10825 Lophozonotriletes appendices [FAD] 10825 Retitriletes clavatoides [LAD] 10850 Nannoceratopsis pellucida [LAD] 10850 Chlamydophorella ectotabulata [LAD] 10850 Fromea tornatilis [LAD] 10850 Pareodinia ceratophora [LAD] 10850 cf. Comparodinium sp. - granulose [LAD] 10850 Paragonyaulacysta calloviensis [LAD] 10850 Escharisphaeridia sp. - indet. [LAD] 10850 Densosporites variomarginatus [LAD] 10850 Murospora intorta [LAD] 10850 Retitriletes clavatoides [FAD] 10850 Callialasporites turbatus [LAD] 10875 • Cycadopites sp. -indet. [LAD] 10875 Valensiella magna [LAD] 10875 4 • Range Event Depth (ft) Tubotuberella rhombiformis [LAD] 10875 Radiizonates"asperatus" [LAD] 10875 Spelaeotriletes cf. triangulus [LAD] 10875 "Spelaeotriletes spp. -indet., small [LAD]" 10875 Scriniodinium crystallinum [FAD] 10875 Radiizonates"asperatus" [FAD] 10875 Callialasporites trilobatus [LAD] 10900 Rhynchodiniopsis cladophora [LAD] 10900 Valensiella ovula [LAD] 10900 Valvaeodinium groenlandicum [LAD] 10900 "Veryhachium sp. - large,triangular [LAD]" 10900 Densosporites pseudoannulatus [LAD] 10900 Grandispora sp. - indet. [LAD] 10900 Callialasporites trilobatus [FAD] 10900 Grandispora sp. -indet. [FAD] 10900 Gleicheniidites minor [LAD] 10925 Tubotuberella rhombiformis [FAD] 10925 Chytroeisphaeridia"verrucosa" [LAD] 10950 Retusotriletes spp. - indet. [LAD] 10950 Radiizonates cf. aligerens [LAD] 10950 Valvaeodinium groenlandicum [FAD] 10950 . Radiizonates cf. aligerens [FAD] 10950 monosaccate trilete sp. 1 [LAD] 10975 Leptolepidites verrucatus [LAD] 10975 Gonyaulacysta oligodentata [LAD] 10975 Sentusidinium asymmetricum [LAD] 10975 Kyrtomisporis laevigatus [LAD] 10975 Crassispora sp. -indet. [LAD] 10975 Nummus sp. 1 [FAD] 10975 Podocarpidites multesimus [FAD] 10975 Leptolepidites verrucatus [FAD] 10975 Gonyaulacysta oligodentata [FAD] 10975 Sentusidinium asymmetricum [FAD] 10975 Kyrtomisporis laevigatus [FAD] 10975 Crassitudisporites problematicus [LAD] 11000 Calamospora nigrata[LAD] 11000 Nevesisporites cf. vallatus [LAD] 11000 Pterospermella aureolata [LAD] 11000 Staplinisporites caminus [FAD] 11000 Escharisphaeridia pocockii [FAD] 11000 Paragonyaulacysta calloviensis [FAD] 11000 Nevesisporites cf. vallatus [FAD] 11000 Pterospermella aureolata [FAD] 11000 Cycadopites nitidus [LAD] 11025 • Lithodinia cf. callomonii [LAD] 11025 5 • Range Event Depth (ft) Lunatisporites noviaulensis [LAD] 11025 Cingulizonates sp. 1 of Ravn 1991 [LAD] 11025 Cirratriradites?sp. 1 of Ravn 1991 [LAD] 11025 Grandispora cf. echinata of Ravn 1991 [LAD] 11025 Reticulatisporites sp. - indet. [LAD] 11025 Deltoidospora mesozoica[FAD] 11025 Knoxisporites triradiatus [FAD] 11025 Retispora lepidophyta [FAD] 11025 Pterospermella australiensis [FAD] 11025 Murospora aurita [FAD] 11025 Cristatisporites sp. - indet. [FAD] 11025 Atopodinium prostatum [FAD] 11025 "Spelaeotriletes spp. -indet., small [FAD]" 11025 Densosporites pseudoannulatus [FAD] 11025 Crassispora sp. - indet. [FAD] 11025 Lunatisporites noviaulensis [FAD] 11025 Cingulizonates sp. 1 of Ravn 1991 [FAD] 11025 Cirratriradites?sp. 1 of Ravn 1991 [FAD] 11025 Grandispora cf. echinata of Ravn 1991 [FAD] 11025 Reticulatisporites sp. - indet. [FAD] 11025 Micrhystridium sp. - indet. (LAD] 11050 • Egmontodinium diminutum [LAD] 11050 taeniate bisaccate pollen -indet. [LAD] 11050 Labiadensites fimbriatus (LAD] 11050 Retispora cassicula [LAD] 11050 Sculptisporis sp. -indet. [FAD] 11050 Concentrisporites angulosus [FAD] 11050 Monilospora moniliformis [FAD] 11050 cf. Comparodinium sp. - granulose [FAD] 11050 Murospora intorta[FAD] 11050 Retusotriletes spp. - indet. [FAD] 11050 Crassitudisporites problematicus [FAD] 11050 Egmontodinium diminutum [FAD] 11050 Labiadensites fimbriatus [FAD] 11050 Retispora cassicula [FAD] 11050 Lithodinia sp. -indet. [LAD] 11075 Rosswangia holotabulata [LAD] 11075 Chytroeisphaeridia cerastes [FAD] 11075 "Chlamydophorella sp. 2-large,irregular [FAD]" 11075 Callialasporites turbatus [FAD] 11075 Cycadopites sp. - indet. [FAD] 11075 Calamospora nigrata [FAD] 11075 Lithodinia sp. - indet. [FAD] 11075 . Rosswangia holotabulata [FAD] 11075 Foraminisporis jurassicus [LAD] 11100 6 • Range Event Depth (ft) Scriniocassis weberi [LAD] 11100 Domasia liassica [LAD] 11100 Murospora tripulvinata [LAD] 11100 Eucommiidites troedssonii [FAD] 11100 "Veryhachium sp. - small,triangular [FAD]" 11100 Vitreisporites pallidus [FAD] 11100 Meiourogonyaulax cf. decapitata [FAD] 11100 Scriniodinium galeritum galeritum [FAD] 11100 Chlamydophorella ectotabulata [FAD] 11100 Rhynchodiniopsis cladophora [FAD] 11100 Gleicheniidites minor [FAD] 11100 Foraminisporis jurassicus [FAD] 11100 Scriniocassis weberi [FAD] 11100 Domasia liassica [FAD] 11100 Murospora tripulvinata [FAD] 11100 Waltzispora polita [LAD] 11125 Stereisporites spp. - indet. [FAD] 11125 Pareodinia sp. E of Wiggins 1975 [FAD] 11125 Perinopollenites elatoides [FAD] 11125 Laevigatosporites spp. - indet. [FAD] 11125 Pareodinia spp. -indet. [FAD] 11125 • Lophozonotriletes triangulatus [FAD] 11125 Pareodinia brachythelis [FAD] 11125 Nannoceratopsis pellucida [FAD] 11125 "Veryhachium sp. - large, triangular [FAD]" 11125 Chytroeisphaeridia"verrucosa" [FAD] 11125 Cycadopites nitidus [FAD] 11125 Waltzispora polita [FAD] 11125 Kalyptea stegasta [LAD] 11150 Murospora complicata [LAD] 11150 Lithodinia borealis [FAD] 11150 cf. Gorgonisphaeridium spp. - indet. [FAD] 11150 Antulsporites clavus [FAD] 11150 Platyptera incisotriloba [FAD] 11150 Fromea tornatilis [FAD] 11150 Pareodinia ceratophora [FAD] 11150 Densosporites variomarginatus [FAD] 11150 taeniate bisaccate pollen- indet. [FAD] 11150 Murospora complicata [FAD] 11150 Antulsporites? sp. -indet. [LAD] 11175 Callialasporites lucidus [LAD] 11175 Stereisporites cf. australis [LAD] 11175 Anapiculatisporites cf. telephorus [LAD] 11175 Samarisporites sp. -indet. [LAD] 11175 bisaccate gymnosperm pollen - indet. [FAD] 11175 7 Range Event Depth (ft) Deltoidospora spp. - indet. [FAD] 11175 Osmundacidites wellmanii [FAD] 11175 Retitriletes spp. - indet. [FAD] 11175 Corollina torosa [FAD] 11175 Exesipollenites tumulus [FAD] 11175 Callialasporites dampieri [FAD] 11175 Chytroeisphaeridia hyalina [FAD] 11175 Valensiella spp. - indet. [FAD] 11175 Rhynchodiniopsis spp. - indet. [FAD] 11175 Densosporites spp. - indet. [FAD] 11175 Lycospora pusilla [FAD] 11175 Punctatisporites spp. -indet. [FAD] 11175 Cerebropollenites macroverrucosus [FAD] 11175 Alisporites grandis [FAD] 11175 Pluriarvalium osmingtonense [FAD] 11175 Scriniodinium galeritum reticulatum [FAD] 11175 Caddasphaera halosa [FAD] 11175 Podocarpidites spp. - indet. [FAD] 11175 Jansonia jurassica [FAD] 11175 Lophozonotriletes spp. -indet. [FAD] 11175 Escharisphaeridia sp. - indet. [FAD] 11175 Valensiella magna [FAD] 11175 Spelaeotriletes cf. triangulus [FAD] 11175 Valensiella ovula [FAD] 11175 monosaccate trilete sp. 1 [FAD] 11175 Lithodinia cf. callomonii [FAD] 11175 Micrhystridium sp. - indet. [FAD] 11175 Kalyptea stegasta [FAD] 11175 Antulsporites? sp. -indet. [FAD] 11175 Callialasporites lucidus [FAD] 11175 Stereisporites cf. australis [FAD] 11175 Anapiculatisporites cf. telephorus [FAD] 11175 Samarisporites sp. - indet. [FAD] 11175 • Pioneer K13PP2 Graphics Panels TN 3I .1 1 NO3_03_TO 0 NOTI_IDJVD 0 KAI�BrK 3 TA NOM TO NO3i o 0 ° O 000GURUK-1 o C. NM X 0 Je r. 0 O .jj 0 0 - 0 0 0 0 K13PB2° . oil , r0 0 ° /0/ • ® O ®VIK-1 O 'rN1S W 0•.a 0 . 0 : i', V o Cf o \ o — o rea U2 10 00¢ ° 0' 0 Kau 48 O �+' i 0. w �. _ NATCNIQ 1 4.1 O oii/Fi U013N007E o• 0 r ir tit A A \' i 3 Figure 1 . PNR K13PB2. Location map. PNR K13PB2 ot% woe P,o ae oe oe �ae'e Pv. ek 0 oe ��e� e'� to o� as Jca�o sz- Qe�o p�e\`a orPQ'pJ� �0 ea Relative MD ��i`e O`�o��� Qo� Numerical Age (ft) Age 0 30 60 9012050 50 50 100 50 10700/800150.7 Ma 10700 (or older) _ 10750' Kimmeridgian v N CO 10800" Cu i z 7 —10880175 10850 154.1 Ma Ca .(-J Oxfordian 10900- 1 10950[75 10950' — — — — — — — — — • 159.4 Ma- 11000" V Cl) co EsMr z 11050" '-) ?Callovian d 'a 11100" 11150" 1 11 11200- Figure 2. PNR K13PB2, North Slope, Alaska. Schematic biostratigraphic framework. Selected biological assemblage summary tracks are taken from a complete suite illustrated on Figure 3. Technical Report Title Date Client: Pioneer Natural Resources Field: Oooguruk Development Rig: Nabors 19AC Date: October 7, 2011 Surface Data Logging End of Well Report ODSK-13i TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Morning Reports 4. Bit Record 5. Mud Record 6. Formation Tops 7. Survey Report 8. Days vs. Depth Digital Data to include: Final Logs Halliburton Log Viewer EMF Log Viewer End of Well Report in PDF format ADI File LAS File GENERAL WELL INFORMATION Company: Pioneer Natural Resources AK Rig: Nabors 19AC Well: ODSK-13 Field: Oooguruk Borough: North Slope Borough State: Alaska Country: United States API Number: 50-703-20607-00 Sperry Job Number: AK-AM-6852352 Job Start Date: 26 July 2011 Spud Date: 02 Jan 2010 Total Depth: ODSK-13 20550’ MD, 6475’ TVD North Reference: True Declination: 20.821 Dip Angle: 80.974 Total Field Strength: 57639 nT Date of Magnetic Data: 27 July 2011 Wellhead Coordinates N: North 70° 29’ 45.49” Wellhead Coordinates W: West 150° 14’ 47.65“ Drill Floor Elevation 42.70’ Ground Elevation: 13.50’ Permanent Datum: Mean Sea Level SDL Engineers: Colby Marks, Mark Lindloff, David Mckechnie, Javian Ervin, Oladeji Olofinboba Company Geologist: Paul Cozma, Jim Stewart Mindaugas Kuzminskas, Fletcher England Company Representatives: Rod Klepzig, Joey Cortez, Joe Polya, Jerry Haberthur SSDS Unit Number: 123 DAILY SUMMARY 7/26/2011 Mudloggers arrived on location. Rigged up CVE and calibrated gas gear. Checked cables for damage during rig move – Good. 7/27/2011 Run in hole with 33 stands of 4” drill pipe. Lay down 270 joints of 4” drill pipe. Stack out top drive on drill pipe, down time while cutting out and removing bent pipe. Continue laying down drill pipe. Begin picking up 5” drill pipe. No mud logging data to report at this time. 7/28/2011 Continue picking up 5” drill pipe. Circulate 1.5 times drill pipe volume. Shut down and monitor well, out of balance due to solids in annulus. Continue running in hole with 5” drill pipe. Trip out of hole with 5” drill pipe and rack back in derrick. Pick up and make up clean out BHA. Run in hole to 3275’. Displace well seawater to 8.5 LSND with 25 bbl high viscosity spacer. Ream and wash to 3455’. 7/29/2011 Drill cement and float equipment. Drill ahead to 3545’ and circulate and condition one bottoms up. Perform LOT to 14.2 EMW. Pump dry job and pull out of hole and lay down clean out BHA. Pick up Geo-Pilot BHA and run in hole with same. Run into hole to 3422’ and install RCD. Drill ahead from 3545’ to 3611. Trouble shoot MWD at 3556’. Drop ball and open Rhino Reamer. Drill ahead to 3899. Max gas seen was 280 units, with no down hole losses to report. 7/30/2001 Drill to 5039’. RCD failure, change out same. Drill ahead to 5578’. Pump sweep at 4025’, 30bbl Hivis/hi weight with 25% increase in cuttings. Pump sweep at 4520’, 35bbl high-viscosity /high weight with 50% increase in cuttings. Pump sweep at 5035’, 35bbl Hivis/hi weight with 35% increase in cuttings. Pump sweep at 5500’ 35bbl Hivis with 15% increase in cutting. No down hole losses. Max gas seen for this period was 334 units, with an average background of 185 units. 7/31/2011 Drill from 5578' to 6084'.. Wait on 3rd party, welding in well bay. Drill from 6084' to 6358'. Pump 50 bbl 9.3 ppg 200 high-viscosity sweep at 6084' with 15% increase in cuttings. Drill from 6358' to 6506'. Start short trip out of hole, tight at 6398'. Work tight spot, pack-off. Pull free at 6493'. Down time. Repair MPD choke line. Trip out of the hole 6398'-5858'. Back ream 5858'-4849' 75 gpm-250 gpm. Total losses to the hole for this report 175 bbls (lost due to pack off). Gas averaged 242 units till 6229' then averaged 526 units with a max gas 1263 units right before Pack Off. 8/01/2011 Circulate, condition and reciprocate from 4850' to 4659'. Pull out of hole from 4659' to 3708'. Circulate, condition and reciprocate from 3803' to 3708'. Pump two bottoms up, heavy returns at shakers. Pump a 11 ppg hi-vis sweep, minimal increase. in cuttings. Back ream, attempt to pull BHA into casing, tight. Continue to back ream to 3613'., confirm reamer closed. Back. ream to 2420'. Pack-off. Run in hole from 2420' to 2471, stage up to 400 gpm. Pump 2 times bottoms up. Back ream from 2471' to 2175'. Run in hole to 3803', pump 11.2 ppg high- viscosity sweep with 25% increase in cuttings. Run in hole to 6506', pump 50 bbl, 11.1 ppg high-viscosity sweep with 15% incr. in returns. Drill ahead to 6750' No losses to the hole to report. Gas from short trip 3503 units, Gas averaged 200 units for the last 24 hours of circulating and Gas averaged 474 units while drilling. 8/02/2011 Drilling ahead from 6750'to 7226'. Pump a 50 bbls 11.2 ppg high viscosity sweep at 7131' with 50% increase in cuttings with sweep return, sweep came to surface 500 strokes early. Service pumps. Drill ahead from 7226' to 7607'. Pump a 50 bbls high weight (non-hi-vis) and 50 bbl high viscosity (Tandem Sweep) sweep at 7515' with no increase in cuttings. Down time, change out pump pop-off. Drill ahead and pump tandem sweep (see above) with 15% increase in cuttings. Down time, change out pump pop-off. Drilling ahead to 8,083’, with minimal cuttings observed at shakers. No losses to the hole to report. Gas averaged 288 units with max gas 708 units 8/03/2011 Drill 8083'-8825'. Pumped tandem sweep at 8300': 50 bbls 11.3 ppg followed by 50 bbls 11.3 ppg, 200 vis with heavy returns seen at the shakers with returns. Sweep came to surface 600 strokes early. At 8750' pumped tandem sweep: 20 bbls with med to heavy returns. Drill 8825'-9224 TARGET DEPTH. Circulate and condition. Pump tandem sweep 50 bbl/50 bbls as above with no increase in cuttings at shakers with returns. Circulating and conditioning hole for short trip to the shoe. No losses to report for today. Gas while drilling averaged 738 while drilling the Torok with a max gas of 2173 units. Gas while circulating averaged 95 Units with a Max Gas 646 units 8/04/2011 Circulate., condition and reciprocate pipe 9129'-8939'. Trip out of the hole to 4503' with tight spot at 5151'. Circulate and condition, Run in hole from 4503' to 4551' and stage up pumps to 800 gpm. Back ream to 3930', pack-off. Circulate and condition and RIH to circulate at 3988', pack -off at 450 gpm, 700 psi. Pull out of hole from 4052' to 3772'. Circulate and condition 400 gpm, no losses. Back ream to 3500'. Drop RHINO reamer deactivation ball. Back ream 3772'-3224'. Pull out of hole to 1885', service top drive. Tripping out of hole at time of report. 82 bbls lost to the hole during pack off. Gas while circulating averaged 37 Units with a Max Gas 297 units 8/05/2011 Continue to trip out of the hole from 1804' to 662'. Monitor well, static. Lay down BHA. Jars have washout. Clean and clear rig floor. Make up Bull-nose BHA and RHINO reamer. Shallow test. Trip into hole to 3532' and circulate and condition 625 gpm, 60 rpm, pull test RHINO reamer, good. Trip into the hole to 6919'. Circulate and condition 6919' to 6954' 800 gpm with heavy cuttings returns at shakers. Screen down to prevent fluid loss. Start centrifuge and de-silter. Wash and ream into hole 6954'-7049' 800 gpm at time of report. 35 barrels lost during the trip into hole. Gas while circulating averaged at 72 units with a Max of 914 units 8/06/2011 Trip out of hole 7049'-9138' Ream/wash open hole 9136'-9224' 740gpm, 3450psi, 90rpm. Circ. & cond, pump 100 bbl hi-vis 11.5 ppg sweep, sweep around BHA, pack off at 9048', no returns. Attempt to regain circulation w/o success. RIH to 9200'. Pull out of hole to 8858' reciprocate and rotating pipe, attempting to regain circulation at 0.5 barrels per minute, no returns. Back ream 8858'-6462'. Close bag and pump down kill line to test if pack-off is inside casing, determine pack-off is in open hole. Trip out of hole to 6934', Trip in hole to 7190'. Reciprocate 7190'-7240' stage up pumps to 825 gpm with full returns. 17 barrel circulation loss due to pack-offs. Average circulated gas was 178 units with a Max gas of 844 units. 8/7/2011 Circulate Bottoms Up 750gpm, 3050psi, 20rpm, 9K torque Trip out of hole to 6219', 500 gpm. Circulate Condition stage up to 700gpm. Trip out of hole to 5717' 800gpm, intermittent pack-offs. Back-ream 5717' to 5100', 800gpm, 3200psi. Circulate, Condition. Pack-off at 5000'. Run in hole to 5090', Pump 50 barrel hi-vis sweep, heavy cuttings prior to sweep 500% increase in cuttings with sweep. Sweep came back 234 strokes early. Continue pumping out of hole. Sweeps brought back Shale and Tuff cavings 1-12cm diameter with 20% cuttings. No losses to the hole. Max gas seen for the 24 hour period was 629 units with and average background gas of 137 units. 8/8/2011 Circulate and condition the well at 500 gpm, 1,700 PSI while MPD unplugged cuttings buildup in choke lines and RSC maintains hammer mills that were packed off with clay. Circulate and condition the well. Stage up pumps to 750 GPM. with intermittent pack-offs. Circulate and stage up pumps to 850 GPM and pump 4 Bottoms ups while the hole unloaded shale. Trip out of hole from 3850' to 1913'. Mix spacer and 17.0 ppg kill pill. Trip out of hole, monitor the well and removed the RCD. Trip the rest of the way out of the hole and layed down BHA. Maintain top drive and test BOP. No losses to the hole. 8/9/2011 Test BOP PU 4" DP equip. Trip in the hole to 4,300' Circulate and condition the well. Conduct carbide test, circulate bottoms up at 850 gpm, determined 83 bbls of washout. Pump 140 bbls of 15.4 ppg high viscosity pill. Trip out of hole to 3,498'. circulate and condition, service the rig. Trip into hole to 3,900'. Pumped 71 bbls of 15.9 ppg cement and chased with 50bbls of active mud. Cement was in place at 15:10 HRS. Circulate and condition at 3,493'. Pump wiper ball and 2 bottoms ups. Trip in hole and tag cement at 3,770 at 18:30 HRS. Circulate out contaminated mud, treat and dump at surface. Pump 25 bbls of 15.9 PPG cement, chase with 52 bbls of 10.5 ppg active mud. Trip out of hole to 3498. No losses for the 24 hour interval. Max gas seen was 237 units. 8/10/2011 Trip in hole and tag cement at 3,670'. Circulate and condition. Pump 11 barrels of water, test cement lines and pump 71 barrels of 15.9 ppg cement. Encountered slight pack off during cement job. Squeezed cement at 350 psi. Trip into hole and wash down to 3,300'. Circulate and condition. Pulled out of hole and layed down drill pipe and 3rd party tools. Picked up bottom hole assembly. Uploaded and shallow tested MWD tools. Success. Trip into hole to 3,000'. Tagged cement. Circulated and conditioned mud. Clean out cement stinger. Washed down to 3,308. Drilled out cement to 3,529. Down linked and packed-off. Geo Pilot housing stuck onto the casing shoe. Jarred free at 23:30 hrs and pulled free. Circulated and conditioned. Prepare to pump dry job and pull out hole to inspect BHA. No downhole losses. Max gas 235 units. 8/11/2011 Pulled out of hole and layed down BHA/Geo Pilot. Picked up mud motor BHA. Ran into the hole at 3,490' where MWD performed a successful shallow test. Reamed and washed to bottom, drilled ahead to 3,619'. Displaced active system with new 11.0 ppg LSND. Had multiple pack-off issues. Pulled up inside the shoe and pumped a 55 bbl weighted sweep resulting in heavy cuttings across the shakers, along with 3/4" - 1" cavings. Circulated the hole clean, begin running back in hole. No losses downhole. Max gas 222 units. Average hole size for this interval is 10.63” 8/12/2011 Tripped in hole and washed down to 3,619'-encountered minor pack-off. Drilled to 4,170'. pumped a high viscosity 50 barrel sweep at 3,797'. Serviced the top drive then drilled out to 4,241'. Pumped another high viscosity 50 barrel 13.0 ppg sweep and received 100% increase in volume along with 1 1/2" to 4" tuff cavings. Pumped out of the hole to 3,480' with intermittent Pack-off events. Circulated 2 bottoms ups, continued to trip out to 1,672' and pumped out as needed. Continue tripping out of hole, and lay down BHA. Read MWD tools. No downhole losses. Max gas 60 units. 8/13/2011 Layed down BHA # 6. Picked up BHA # 7 and ran in the hole. Shallow tested MWD tools at 665' with success. Washed and reamed when needed to 3,512'. Tripped into hole to 4,241' and washed and reamed where necessary with intermittent Pack-offs along the way. Drilled out to 4,322 and activated Rhino Reamer. Drilled to 4,852 and circulated an 80 barrel 13.0 ppg high viscosity sweep at 4,675'. 100% increase in cuttings over the shakers. Performed a 220 barrel dilution with new 11.0 ppg LSND from RSC. Serviced the top drive and drilled ahead to 5,136 and pumped another High Viscosity sweep with 100% increase in cuttings over the shakers. Drill ahead. No downhole losses. Max gas 88 units. Sweep brought back 4-6” cement cavings. 8/14/2011 Drilled out to 5,175. Pumped 80 High Viscosity Sweep. 100% increase in Cuttings over the shakers. Drilled out to 5,617 and pumped an 80 bbl 13.0 ppg high vis sweep with 100% increase in volume over the shakers. Drilled to 6,181 and performed 210 bbl dilutions with new 11.0 ppg LSND from RSC. Pump 80 bbl 13.0 ppg high viscosity sweep with 100% increase in volume over shakers. Serviced top drive, drilled to 6,252', repaired mud pump. Drilled out to 6,535' and pumped another sweep with over 100% returns over shakers. Cavings reduced almost entirely throughout sweeps. Back reaming. No downhole losses. Max gas 199 units. Average hole size for this interval 10.77” 8/15/2011 Drilled out to 6,535', circulated and conditioned 1 bottoms up with ECD's at 12.0 ppg before and after circulation Pumped 80 bbls of 13.0 ppg high viscosity sweep resulting in 100% returns over shakers. Back reamed to 4,356' with intermittent pack-offs and hole unloading. Circulated and conditioned, then pumped another 80 lbs. high viscosity sweep with only 15% volume increase over the shakers. Tripped back into the hole to 6,467', reamed and washed to 6,535', staged up the pumps and rotated. Drilled out to 7,050'. Pumped 80 bbls high viscosity sweep with 10% increase over the shakers. Performed 200 lbs. dilution with new 11.0 ppg LSND from RSC. Pumped 80 bbls high vis 13.0 ppg sweep with 15% increase over the shakers. Serviced top drive. Drilled out to 7,250' and pumped another 80 bbls 13.0 ppg high vis sweep with 25% increase over the shakers. Drill ahead. No downhole losses. Max gas 235 units. No large cavings brought back with sweeps pumped during this interval. Average hole size for this interval 11.54” 8/16/2011 Drilled to 7,230' and pumped an 80 bbl, 13.0 ppg high viscosity sweep resulting in a 25% increase over the shakers. Drilled to 7,399'. Repaired mud pump washout and serviced top drive. Reciprocate drill pipe for 15 minutes during pump repair. Drilled out to 7,610' and pumped another 80 bbl high viscosity 13.0 ppg sweep with 20 percent increase over shakers. Drilled to 7,800' and performed a 200 bbl dilution with new 11.0 ppg LSND from RSC. Pumped 80 bbl 13.0 ppg high vis sweep with 20% increase at shakers. Serviced top drive. No downhole losses. Max gas 86 units. Average hole size for this interval 11.43” 8/17/2011 Drilled to 8,400', Pumped an 80 bbl 13 ppg high viscosity sweep with 10% increase in volume at the shakers. Drilled to 8,936'. Repaired pump #2 swab/liner. Drilled to 9,032' Repaired pump #1 swab/liner. Drilled to 9,100' T.D. Circulated 3 Bottoms ups and pumped an 85 bbl 13.0 ppg high viscosity sweep with 0% increase at the shakers. Circulated and conditioned, dropped 2" ball and deactivated the Rhino Reamer blades. Back reaming. No downhole losses. Max gas 715 units. Average hole size for this interval 11.1”. 8/18/2011 Repair pump #1. Trip out of hole to 6,100', Pack-off. Trip out of hole to 5,611'. Trip out of hole to 4,566'. Circulated two bottoms ups with an 80 bbl 13.0 ppg high viscosity sweep. 100% increase including large cavings. Trip out of hole to 4,378', Circulate 2 bottoms ups with 85 bbls high viscosity 13.0 ppg sweep with 10% increase at shakers. Back ream to 4,281'. Attempted to pull with elevators, but was tight. Short trip from 4,281' to 4,661'. Back reamed to 3,818'. hole unloading at 3,950'. Packed off and reciprocated pipe. Step up pumps at 3,965'. Circulate 3 bottoms ups with 80 bbl 13.0 ppg high viscosity sweep. 100% increase including large cavings. Back reamed to 3,607'. Pumped 80 bbl 13.0 ppg high viscosity sweep at 3,476' with 100+% increases at shakers with 1" to 5" shale cavings. No downhole losses. Max gas 235 units. Sweeps brought back 5-6” cavings with some larger than 12”. 8/19/2011 Tripped out of the hole to 3,512' with intermittent pack-offs. Pumped 80 bbl 13.0 ppg high viscosity sweep tripped out of the hole to 3,329', changed out swivel packing. Tripped out of the hole to 1,807'. Pumped 80 bbl high viscosities 13.0 ppg sweep with 100% increase in volume at the shakers. Tripped out of the hole and laid down the BHA. Picked up and tested BHA and Rhino Reamer with no reamer blade deactivation during the pump test. Layed down Rhino Reamer and picked up BHA #8. Tripped into hole to 3,450'. Slip and cut drill line. Circulated and conditioned bottoms up and tripped to 4,692 with no issues. Circulated and conditioned bottoms up and staged pumps with no issues. Prepare to trip out of hole. No downhole losses. No significant gas to report. Some large cavings brought back with sweep. 5-6” 8/20/2011 Tripped out to 3,512' and pumped an 80 bbl 13.0 ppg high viscosity sweep with no significant cuttings increase at the shakers. Pumped dry job. Tripped out of the hole and laid down the BHA. Monitored the well for 10 minutes. Static. Lay down BHA and download MWD. Rig up Tesco to run liner. Change the Rams on BOP's. Tested BOP's. Run in the hole with 9 5/8" liner to 3,466'. Stage pumps and circulated 1 bottoms up with good returns. Run into hole at 5,844' with liner at time of report. Max gas 15 units. Losses to the hole while running liner were 26.5 bbls for this interval. 8/21/2011 Run in hole with liner to 5,795' (Returns 80-50%) Rig down Tesco and make up Liner hanger packer running tool. Run in hole with the liner on 5" DP to 9,098. (Returns to 100%) Establish circulation, step rate with 11.0 ppg LSND. Displaced to 10.0 ppg LSND.Drop 1 3/4" ball. Seat ball and set hanger. Rig up HES cement equipment. Pumped cement per HES program. Plug did not pump. Tested floats. Circulated 1 and a half bottoms ups. Rigged down cement equipment and tripped out of the hole. Laid down the BHA, Rigged up to run in the hole with the bridge plug. Max gas 52 units. Losses while running liner for this interval were 8.2 bbls. 8/22/2011 Run in the hole with HES Bridge plug BHA to 3,222'. Set the bridge plug and perform casing test at the shoe to 3,500PSI for 30 minutes. Bled back 4 bbls and released the run tool. Tripped out of the hole to surface. Nipple down BOP's, Risers, Spacers and spool. Nipple up BOP's, change rams, repaired top drive and tested BOP's. Made up HES bridge plug retrieval tool. Tripped into the hole to 3,321 and latched the bridge plug. Released per HES representative. Close rams, Tested the casing shoe at 3,500 psi for 30 minutes. POOH to 300’. No gas or losses to report for this interval. 8/23/2011 Trip out hole. Lay down BHA. Pick up new BHA , Trip in hole to drill out cement. Wash down an ream, then drill out shoe. Tag cement at 9055' to drill to 9120'. Perform FIT test to 14.0 EMW. Circulate and Condition mud, Displace active system from 10.0ppg LSND to new 9.8 ppg LSND. Trip out hole to surface. Lay down BHA. Service Top Drive, Set test plug. Test MPD lines. Pick up BHA and GeoPilot for Run 1000. No losses for this interval. Max gas seen 20 units. 8/24/2011 Test MPD equipment. Pull test plug and install 9'' wear ring. Pick up BHA. Run in hole filling pipe at every 25 stands Wash and ream 8794' to 9120'. Drilling ahead. No loss for this interval. Max gas 337 units. 8/25/2011 Drill ahead 9555' -10127' 700 gpm 4033 psi 140 rpm. Pumped a 35bbls 12ppg high vis sweep at 9650' with no increase in cuttings returns. Pumped 80bbl 12ppg high vis sweep at 9840' returned at calculated strokes with no increase in cuttings returns. Downtime repair. Mud pump 2. Continued to drill ahead 10127' 700 gpm , 3950 psi 140 rpm. Began stringing in barafibre, baracarb and steel seal prior to entering the Kuparuk formation to prevent seepage losses. No losses to the hole. Drilling Ahead. Max gas 2558 units, this was connection gas from a connection at 10032’ MD 8/26/2011 Service rig pumps. Drill ahead 10830' to 11187' (TD). Circulate and condition, pump 80 bbls 12.1 ppg high viscosity sweep with 10% increase in cuttings. Short trip to 9270'. Pump 40bbl 12.1 ppg high viscosity sweep with 30% increase in cuttings Trip out of the hole to 8978'. Service top drive. Trip into the hole to 11187', pump 40 bbl 12.1 ppg high viscosity sweep. Take on 17.0 ppg spike fluid to inactive pit #5 and weight up to 13.0 ppg in preparation for displacement/blend to 13.0 ppg. POOH. No downhole losses. Max gas 1111 units. 8/27/2011 Circulate and reciprocate 11187'-11090' Pump 35bbl 12.1 ppg sweep 700 gpm, 400 psi, 140 rpm. With no increase in cuttings. Begin fluid blending , weight up to 13.0 ppg using 17.0 ppg spike fluid. Maintain 13.0 ppg going down hole. Change out rotating head, monitor well 10 minutes, static, Trip out hole and lay down BHA. Pick up 4" drill pipe. Trip into the hole with 4" to 1092'. Run into hole with 5" drill pipe. No losses for this interval. No gas to report. 8/28/2011 TIH to 11177', Circulate and Condition hole. Staging to 500 gpm. Rig up cement equipment. 3 stage cement plug Pump 29 bbls water. 59 bbls of cement chase with 173 bbls mud. TOOH to 10416', circulate 761 bbls. Pump 29 bbls of water. 59 bbls cement, chase with 162 bbls. TOOH 9654', circulate 592 bbls, 500 gpm. Pump 65 bbls cement, chase with 148 bbls mud TOOH to 8798. Displace well from 13.0 ppg to 9.8 ppg. 500-700 gpm, 150 rpm. TOOH Lay down Muleshoe. No losses for this interval. Max gas 74 units. 8/29/2011 Picked up BHA. Download MWD and pulse test. Trip into hole to 8644', pulse test, Slip and cut drill line. Ream 8664' to 8840'. Tag cement. Drill cement 8840' to 9098' 700 gpm 90 rpm. Circulate two bottoms up, install RCD. Drilled 9098'-9310' 650 gpm, 125 rpm. Drilled 9406' 700 gpm, 4000psi, 140 rpm 20-23k on bottom torque, 18-20 off bottom. Fresh lube added to 6% to reduce torque. Drilling Ahead. No Losses for this interval. Max gas 176 units. Average hole size for this interval 9.5”, in gauge based on sweeps pumped. 8/30/2011 Drilled ahead to 9406'. Drop ball to open RHINO reamer. Ream 9396'-9400. Drill ahead 9406'-9561 700 gpm 3000 psi, 140 rpm. Change swab on pump. Drill ahead 9561-9882. At 9600 pump 80bbl 13ppg, 200 high viscosity sweep with no increase in returns. Service rig. Drill 9882'-10299'. At 10082', pump a 80bbls 13ppg, 200 viscosity sweep with no significant increase in returns. Down-time, mud pump swab. Drill ahead 10299'-10452', 740 gpm, 4200 psi 130 rpm. Continue working on mud pump. No Losses for this interval. Max gas 1671 units from a connection depth of 10168’. Based on sweeps returning to surface on time and correlating connection gas lag, the hole is in gauge at 9.5”. 8/31/2011 Repair rig pump. Drill ahead 10453'-10732', 740 gpm, 4305 psi 130 rpm, 22k torque. At 10673', pump a 80bbls 12.4 ppg, 220viscosity sweep with 10-15% increase in cuttings. Drill ahead 10732'-10854'. Repair mud pump. Drill ahead 10854'-11119'. Shut down to inspect pumps, gear end. Trip out of the hole to the casing shoe pumping 75 gpm. Service rig pump. Trip back into hole. No Loss for this interval. Max gas 3254 units, seen after short trip. Sweeps coming back to surface on time confirmed an in gauge hole of 9.5”. 9/1/2011 Pump OOH 10834'-9050', 70 gpm. Repair rig pump. TIH 9050'-11024'. Drill 11119'-11295' 740gpm, 4300 psi. Pump 80 bbl 12.4 ppg 200vis sweep with 30% increase cuttings at 11178'. Drill 11295'-11430' (TD) ,circulate and condition. Work on mud pump. Pump 80 bbl 12.4 ppg 200 viscosity sweep with 10-15% increase in cuttings. Drop ball, close RHINO reamer Short trip to 11049' and back to bottom, circulate and condition, pump 82 bbls 12.2 ppg 220 viscosity sweep with 25% increase in cuttings. No losses for this interval. Max gas seen 3344units. Sweeps indicate in gauge hole. 9/2/2011 Circulate and condition reciprocating 11430'-11335, prepare for displacement to 13ppg kill weight. Displace well from 10.2 ppg to 13.0 ppg. Monitor well, static. Pull RCD and install trip nipple. Trip out of the hole, pumping out 11430'-9025 2-3 bbls per stand. Tight at 10660' and 10485'-10340'. Hole taking proper amount. Pump dry job and pull out of the hole to surface, lay down BHA. Testing BOP. No losses or gas to report. 9/3/2011 Run 7" liner to 2444'. Make up 7' X 9 5/8' hanger/packer. Circulate liner volume, 95bbls at 3 bpm, 100 psi. Run liner into hole on drill pipe to 11430' filling every 20 stands. Circulate and condition at 40 gpm. Pump 50 bbl 13.0 ppg 300 vis spacer and chase with 10.2ppg. Position top of liner at 8949' and drop liner setting ball. No Losses. Max gas 150 units 9/4/2011 Circulate liner hanger ball and set hanger top at 8949'. Continue to circulate well to 10.2 LSND. Cemented casing liner with 45 bbl spacer and 33 bbls 15.8 ppg cement. Sheared out and tested liner packer to 3500 psi. Circulated bottoms up at 14 bpm. Rig down cement equipment and pull out of the hole to surface. Currently out of hole at time of report. No losses to the hole. 39 Max units of trip gas. 9/5/2011 Lay down drill pipe 4940'-562', lay down BHA. Remove wear bushing and test bop. Install wear bushing. Trip into hole with mule shoe to 3527'. Slip and cut drilling line. Lay down drill pipe. Pull wear ring and rig up tesco equipment . Service rig. Run 7" casing at time of report. No losses or gas to report. 9/6/2011 Run 7" casing to 8949". Sting into seal assembly. Circulated and test 9 5/8" X 11 3/4" annulus to 3500 psi. Circulated 135bbls diesel into 7"X 9 5/8" annulus. Pressured test casing. Casing slips did not set. Service rig. Pressured test casing and rig down tesco. Installed test plug, an performed BOP test. Tripping into hole 4" Drill pipe. Currently tripping into hole. 0 losses. No gas to report 9/7/2011 Test BOP's, picked up 171 joints of 4" drillpipe. Circulated and condition drillpipe volume. Service topdrive. Tripped out hold to surface. Picked up BHA # 13. Trip into hole picking up 4" drillpipe to 10812. Drilled cement. Drilling new formation at report time. No losses to the hole. Max gas- 82 units of formation gas. 9/8/11 Tripped into the hole to 11137". Drill log cement and shoe track to 11416". Circulate and condition 10.2 ppg surface to surface. Drill cement to 11430". Circulate and condition bottoms up with 10.2 ppg EMW. Tripped out hole. MAD Pass 350 'hr from 11428' to 10400', and 9400' to 9203'. Trip out hole an lay down BHA. Repair hydrylic leak on BOP stack. Picked up BHA # 14, and currently tripping into the hole at the time of report. 9/9/2011 Ran into the hole to 11400'. Slip and cut drill line. Install MPD RCD bearing. Pump 50bbls10.2 ppg high viscosity spacer. Displace 10.2 ppg LSND to 8.6 ppg, Quick drilling fluid. Drill to 11555', Perform pore pressure PSI test with MPD. Record 9.21 ppg EMW pore psi. Rotary drill ahead to 1161'. Currently drilling ahead at time of report. No losses to report. Average gas- 50 units. Max of 695. 9/10/2011 Time drilling and rotary drilling from 11650' to 11727'. Continued drilling siderite stringers. Currently drilling ahead. Gas- 50 units on average. Max of 389. No losses to the hole. 9/11/2011 Time drilling and rotary drilling to 11854'. Troubleshoot GeoPilot , unable to downlink. Switch GeoSpan modes. Drilling to 11919'. ECD increasing 10.2 ppg to 12.0 ppg. Circulate and condition fluid. Bottoms up, flocculated an oil contaminated mud dumping over shakers. Flow out lubes at 7%. Shakers were cleaned, and continued run into hole. After Attempt to circulate, ECD increased. Circulating and conditioning the hole and trouble shooting gas chromatograph at time of report. Average gas- 40 units. Max of 114. No losses to the hole 9/12/2011 Trip out the hole to 11400'. Stand pipe pressure increasing. Adjusted drilling parameters in attempt to lower psi. Circulated bottoms up. Hole unloading oil contaminated an flocculated mud. Attempt to treat mud to surface system with no positive results. Dump and diluted 100% of the active system. Circulated new 8.5 ppg Quick Dril N surface to surface. Stage pump rate to 250 gpm. Confirm no losses to hole. Trip back to bottom holding 11.0 ppg EMW with MPD. Minor pack off at 11900' Circulated bottoms up two times at 11919'. Trip back into hole at 11796'. Perform pore psi test with MPD. Read 10.1 ppg EMW. Ream and wash to bottom holding 11.1 ppg EMW. Orient Geo Piolot. Currently drilling at report time. No Losses. Average gas- 14 units. Max- 1700 units circulated gas. 9/13/2011 Rotary drilling an time drilling from 11935 to 12883". Holding 11.0-11.1 ppg EMW, with MPD @ shoe. Mud weight 8.5 ppg in an 8.65 ppg out. Pumped a 20 bbls sweep at 12,500' with no increase in cuttings at the shakers. Pumped another 20 bbl sweep at 12,800' with no increase in volume. Drilling ahead at report time. No losses to report. Average gas- 698. Max gas- 1561 at 12,943. 9/14/2011 Rotary drilling and time drilling from 12863 to 13949. Holding 11.3 ppg EMW with MPD at shoe. Mud weight 8.5 ppg in and 8.6 ppg out. Steady fine oily sands returning on shakers while drilling. Pumping 20bbl High Viscosity 8.5 ppg sweeps every 300". Minimal increase with returns on sweeps. Currently drilling ahead at report time. No losses to the hole. Average gas- 350 units. Max gas- 2934 Formation Gas at 13933. 9/15/2011 Rotary drilling an time drilling to 14513'. Holding 11.3 ppg EMW with MPD at shoe. Lost signal to GeoPilot. Trouble shoot. Unable to regain signal. TD called. Circulated 4x Bottoms up. Pump 40 bbl Hi vis sweep. Minimal change in returns at shakers. Trip out hole to inside casing shoe at 11356'. Circulate and condition drilling fluid. Trip back to bottom, Circulate and Condition. No losses to report. Average gas- 300 units. Max gas- 558 units of formation gas at 14,453’. 9/16/2011 Circulate and condition drilling fluid inside casing shoe. Trip into hole to 14513'. Circulate bottoms up. Perform Pore PSI test to 10.73 ppg EMW. Pump 50bbls High vis 8.6 ppg sweep. Displace open hole with new quick drill in with 5% NXS lube. Trip out hole to 11949'. Circulate and condition fluid. Continued tripping out of hole to 11400', while mixing Brine at RSC. Trip back in to hole to sump, 11949'. Lay out 11.2 ppg High vis spacer 11949' to 11400'. Displace 8.6 ppg Quick Drill into 11.2 ppg NaCL/ NaBr vis brine. Observe weill static 15 minutes. Pull MPD RCD bearing. Pump Out Of Hole to 10000. Continue Pulling out hole at report time. 118 units of gas. 24 bbls lost to the hole from midnight to 4:00 AM at a rate of 2.6 bbls per hour. 9/17/2011 Tripped out of the hole to 420'. Monitored the well. Static condition- no losses. Laid down BHA. Download MWD. Pick up and flush additional 4" HWDP.Rig up to run 4.5' slotted linger. Make up liner per Weatherford rep. Trip into hole with 77 joints of liner. Trip in hole with liner on 4" DP to 6350. No Gas- No Losses to Report. 9/18/2011 Trip into hole with liner on 4" DP to 14513'. Tagged bottom. Picked up to 14511'. Circulate and condition, pump 1.75" phenolic ball. No seat. Drop 1.75" aluminum ball. No seat. Jar string. No seat. Attempt emergency seat. Apply left hand turn to 4.5k torque x 3. No release. Try manual release with out positive results. Pump 20bbl high vis sweep to attempt assist ball seat. No seat. Pump wiper ball to assist seat. PSI increase. Hanger set. Attempt release set tool. Liner moving. Work pipe. Tool released. Completed packer set per weatherford rep. Psi test shoe. Unable to hold 3500 psi. Bleed off. Circulated 2x bottoms up. Pulled out hole laying down 4" drillpipe at time of report. No Gas- No Losses. 9/19/2011 Pull out hole to BHA, Laying down 4" pipe. Monitor well 10 minutes, Static. Lay down weatherford BHA. Test BOP's. Trip into hole with Baker fishing BHA with bailer on 4" drill pipe to 11270' in an attempt to retrieve the lost nerf ball. Trip in hole to 11412'. Function hydro bailer. Stack 10,000 to open fill 2bbls. Repeat procedure 3x. Fill pipe. Circulate 2 bottoms up, No change in Mud weight in Mud weight out on 2x bottoms up. Slight crude oil returns on bottom shaker screens during circulate. Cut and slip drill line. Currently pulling out of hole. Max gas- 53 units circulated gas. 7 barrels lost to the hole. 9/20/2011 Monitor well. Static. Cut an slip drill line. Pull out of hole laying down 4" drill pipe. Hang ESP cable sheave. Continue to pull out of hole, laying down 4" drill pipe to hydro bailer BHA. Secure sheave in derrick due to high winds. Lay down bailer. No debris recovered. Rigged up ESP cable and currently running in the hole with ESP pump at time of report. No gas. 8 barrels lost to the hole. 9/21/2011 Pull ESP cable to rig floor and secure same. Splice ESP cable to motor. Make up pump assembly. Run into hole with ESP to 902', stack out. Test ESP, cable shorted out. Trip out of the hole too 613', pull on Top drive to free 30,000 over. Pull out of the hole to surface., broken stabilizer above ESP and 20' of wire missing. Currently running into hole at report time. No gas. No losses. 9/22/2011 Lay down ESP, retrieve 20' of wire. Load pipe in pipe shed. Rig down tubing equipment. Service top drive. Make up scraper magnet and trip into hole to 1480', pump 120 bbls at 250 gpm. Trip into hole to 2735'. Trip out of hole recovered bolt head and metal shards. Rig up slick line and run into hole with magnet and brush to 4000'. Pull out hole, nothing recovered. Make up gauge ring and junk basket and run into hole to 8973'. Pull out of hole with out fish. Rig down slick line. Currently running into hole with 4" drill pipe for a clean out run. No gas or losses to report. 9/23/2011 Make up magnet scraper and mule shoe and run in hole picking up 4" drill pipe to 10174'. Set packer. Pressure test casing. OA pressuring up. IA and OA are in communication. Rig up to circulate freeze protect diesel out of annulus to flow back tank Pump down IA, out OA, displace with viscosifed 11.1 brine at 2.5 gpm. Pump 60bbls and shut down to allow diesel to migrate up. Pump 13bbls, and shut dwon to allow diesel to migrate up. Confirm returns at 11.1 ppg. Rig up to pump down outer annulus taking returns from inner annulus. Running into hole to set packer at time of report. No gas or losses to report. 9/24/2011 Circulate out freeze protect at 1 bpm and ensure. 11.1 ppg. Trip out of hole. Pick up storm, valve and twin and trip into hole to 10190'. Trip into the hole on 4" drill pipe 10190'-11148'. Set packer. Trip out of hole to surface. Change rams and test. Pull 7" pack off and pull 7" casing laying down 20 joints. Service rig. Wait on orders. Test BOPE. Trip into hole to retrieve packer, and storm valve. Service top drive. Currently pulling out of at report time. No gas or losses to report. 9/25/2011 Trip into holemaking up retrieval tool. Tag up on fish at 2993'. Turn pipe 14x to the right and pull to 2992', pump 1bbl with returns. Monitor well, static. Service the rig. Trip out of the hole to surface. Lay down BHA with magnet and scraper, no significant metal on magnet. Service rig and wwait on 3rd party tools. Pick up BHA and Run in hole to 9160'. Drop 1/2" ball, pump 3 bpm. Currently pulling out of hole at report time. No Gas or losses to report. 9/26/2011 Circulate at 9160, pump 2nd aluminum ball 3 bpm, 250 psi. Attempt rotate, recip, pump surge at 406 bbls. Slack off, taking weight. Ball did not seat. Drop 1 1/4" Teflon ball, pump 914 strokes., shear not observed. Pull out of hole 9160'-9133' and test packer, bleed off, test failed. Run in hole and tagged plug at 9160', re-test. Trip out of hole to surface. Test BOPE. Pick up Baker packer retrieval tool and Trip into hole, taking weight at 900'. Trip out of hole and inspect BHA, good. Trip in hole to 1616' and stack out, damage/change out saver-sub. Continue to Trip into hole to 9130'. Set packer and test, good. Trip out of hole. Currently tripping in hole at time of report. No gas or losses. 9/27/2011 Trip out of hole to surface, monitor well, static. Lay down BHA. Make up G-model bridge plug and trip into hole, with new packer, to 9178'. Set packer at 9180' and test to 1000 psi, good. Reverse circulate 405 bbls9.0 viscosified seawater. Monitor well, static. Pump 20 bbls 11.1 ppg brine and 2850 lbs of sand in drill pipe. Waited on sand to fall. Trip into hole to 9110'. Attempt to tag sand, no go. Work pipe 9115'-9125'. Sand not on bottom. Displace well with straight seawater, monitor well and dump 16 sacks of sand down drill pipe. Circulate 5 bpm. Currently pulling out of hole at time of report. No gas or losses. 9/28/2011 Circulate and condition mud while working pipe 9064 - 9156'. Tag sand at 9156', rotate and circulate tag sand 9130'. Displace Well. Reverse circulate 465 bbls 9.0 ppg viscosified seawater, 320 gpm, 2074 psi.Trip out of hole to surface. Install 7" test joint, change out pipe rams to 7". Test BOPE. Pick up 7" casing spear BHA and trip in hole with same tagging fish at 890'. Engage fish and pull free with 215k. Line up on gas buster and displace 10.2 ppg LSND from inactive annulus behind 7" casing. Pull casing from 8962" to 8072'. Release spear. Service top drive. Still servicing top drive at report time. 88 units of max circulated gas. No losses to report. 9/29/2011 SDL Released from Oooguruk. Install upper IBOP and test same. Failed. Downtime, IBOP. Re-test same. Test BOPE. Pull and lay down 7" casing to surface. Service rig, change rams. Test BOPE. Pull and lay casing to surface without the mule shoe. Service rig, rig up fishing tool and trip back in hole to retrieve mule shoe. Tripping in hole at report time. No gas or losses to report. Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks / Mark Lindloff Ann Corr Cor Solids (lb/100ft2) 19,000 24 hr Max YP C3 16 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max 8.0 Lst C2C1 Sh H2S Data Sample Line Avg: Chromatograph (ppm) 1.0 Silt Siltst ClystCht 6079'78.60 8.60 Nabors 19AC $6,336.97 AK-AM-0006852352 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 2 07/28/2011-04:00 3525' North Slope Daily Charges Avg -- Gas (units) ml/30min Max:Ambient Air Pit Room 45 - pH Chlorides GvlCoal -Min -Avg 11.0 mg/l -AvgMin Max Max API Filt 9.00 0 4.2000 $19,797.70 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Drill Pipe Management J. Polya/ J. Haberthur -- Flow In (gpm) Current Pump & Flow Data: - - Max @ ft Current R.O.P. (ft/hr) Gas (units)-- - Depth md ADT Services start 7/28/2011 Charges for unmanned Standby from 7/16-26/2011 added Down time-stack out top drive on drill pipe. Continue to lay down drill pipe. Clean rig and service top drive. Picking up 5" drill pipe at report time. PWD Drilling All Circ Avg Diam % - Run into hole with 33 stands, Lay down 270 joints Drill Pipe. Service Top Drive. Continue to lay down drill pipe. -- Max: Hole Condition On Bot Hrs 3525'- Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air - Max: Hole Condition On Bot Hrs 3525'0.46 PWD Drilling All Circ Avg Diam solids in the annulus. Circ. surface to surface, mud weight in/out 8.5+. Shut down, monitor the well, static. Trip out of the hole 36 stands. Pick up 108 joints of 5" drill pipe to 3380'. Circ. and condition. Trip out of hole to surface. Clean and clear rig floor. Pick up Circ. 1.5 X DP volume, fine sand returns seen at the shakers on BU. Shut down and monitor well, out of balance due to Depth md and make up clean out BHA. Run into hole to 3275'. Slip and cut. Displace well seawater to 8.6 Ream and wash 3241' to 3525' Drill 20' of new formation. Perform LOT to 867 psi, 14.2 ppg. Pumped a dry job and getting ready to POOH. Sample Predominately cement Current R.O.P. (ft/hr) Gas (units)2 10 3533' 20' Drill Pipe Management J. Polya/ J. Haberthur 16 3542' Flow In (gpm) Current Pump & Flow Data: - 707 4.2000 $22,602.88 688 170 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % - 1.5 mg/l -AvgMin Max Max- pH Chlorides GvlCoal -Min -Avg ml/30min Max:Ambient Air Pit Room 51.0 62 Gas (units) 45 0.0 3 07/29/2011-04:00 3525' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft - 8.60 8.60 0.46 Nabors 19AC $6,336.97 AK-AM-0006852352 10.63 0.942 1.0 Silt Siltst ClystCht Hughes GT-C1 6079'9 Chromatograph (ppm) H2S Data Sample Line Avg: 3545' 20' C2C1 Sh 3 Sd Depth Max 8.0 Lst 3525' 200 C4 C5 Tuff Gas Breakdown Avg: Average Sst C3 API Filt 10.10 63 14 Colby Marks / Mark Lindloff Ann Corr Cor Solids (lb/100ft2) 18,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks / Mark Lindloff Ann Corr Cor Solids (lb/100ft2) 16,000 24 hr Max YP 63 C3 26 Tuff Gas Breakdown Avg: 90 Average Sst C4 C5 Sd Depth Max 5.8 Lst 3525' 200 300 HDBS FXG65s 3545' 20' C2C1 Sh 3 H2S Data Sample Line Avg: Chromatograph (ppm) 10 2.0 Silt Siltst ClystCht Hughes GT-C1 3899' 3545' 88.65 8.65 0.46 Nabors 19AC $6,336.97 AK-AM-0006852352 10.63 0.942 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 4 07/30/2011-04:00 4212' North Slope Daily Charges Avg 10.75 1.271 103.0 249 Gas (units) ml/30min Max:Ambient Air Pit Room 49 10.61 pH Chlorides GvlCoal 8.76 Min 11.26 Avg 1.6 mg/l 11.51 AvgMin Max Max API Filt 10.00 2304 4.2000 $28,939.85 746 176 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 667' Drilling J. Polya/ J. Haberthur 311 4154' Flow In (gpm) Current Pump & Flow Data: 12.15 98.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)236 145 4093' Depth md No gains or losses to report of report. Samples predominately shale with scattered Tuffaceous material, dark brown to brown, scattered dark gray pieces, coarse to gravel size grains, suib blocky to blocky, no swelling, trace calcareous head. Wash and ream at 720 gpm, 2275 psi. Drill ahead 3545' to 3611'. Trouble shoot MWD at 3556'. Drop ball and open RHINO reamer. Drill ahead to report depth (3899') 750 gpm, 2000 psi on bottom, 125 rpm, 7-8K Torque. Drilling Ahead at time PWD Drilling All Circ Avg Diam % 11.90 Pull out of the hole, lay down BHA. Pick up Geo-pilot BHA and shallow test at 770'. Run into hole to 3422'. Change rotating 25 bbls 12" Max: Hole Condition On Bot Hrs 4212'0.46 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 11.85'' Max: Hole Condition On Bot Hrs 6506'32.15 Total Losses from Midnight to 0400 10 bbls PWD Drilling All Circ Avg Diam High vis sweep at 6084' with 15% increase in cuttings. Drill 6358' -6506'. POOH, tight at 6398'. Work tight spot, pack-off. Pull free at 6493'. Repair. MPD choke line. Trip out of the hole 6398'-5858'. Back ream 5858'-4849' 75 gpm-250 gpm. Continue to drill from 5904' to6084'. Wait on 3rd party, welding in well bay. Drill 6084' -6358' 800 gpm. Pump 50 bbl Depth md Samples graded between shale, claystone and siltstone with the major portion being claystone, subrounded, platey, with tuff cavings. Total Losses from Midnight to Midnight 175 bbls (Do to Pack Of)f 4789' pumped 500 bbl High Vis Sweep. Sweep back 23 strokes early, with 5-10% increase in returns Gas moderate till 6229' then steadily increased to 1263 units right before Pack Off Current R.O.P. (ft/hr) Gas (units)0 173 6210' 602' Short Trip J. Polya/ J. Haberthur 1263 6458' Flow In (gpm) Current Pump & Flow Data: 13.02 2915 4.2000 $41,613.79 789 186 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 12.67 6.7 mg/l 11.51 AvgMin Max Max11.24 pH Chlorides GvlCoal 11.19 Min 11.64 Avg ml/30min Max:Ambient Air Pit Room 1.271 96.8 134 Gas (units) 54 0.0 6 08/01/2011-04:00 6506' North Slope Daily Charges Avg 10.75 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 9.35 9.35 0.46 Nabors 19AC $6,336.97 AK-AM-0006852352 10.63 0.942 15.0 Silt Siltst ClystCht Hughes GT-C1 6507' 3545' 11 Chromatograph (ppm) 15 H2S Data Sample Line Avg: 3545' 20' 55 C2C1 Sh 3 Sd Depth Max 5.5 Lst 3525' 200 300 HDBS FXG65s 25 C4 C5 Tuff Gas Breakdown Avg: 5 Average Sst C3 API Filt 10.00 63 28 Colby Marks / Mark Lindloff Ann Corr Cor Solids (lb/100ft2) 18,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks / Mark Lindloff Ann Corr Cor Solids (lb/100ft2) 18,000 24 hr Max YP 63 C3 23 Tuff Gas Breakdown Avg: 5 Average Sst C4 C5 Sd Depth Max 5.8 Lst 3525' 200 300 HDBS FXG65s 25 3545' 20' 55 C2C1 Sh 3 H2S Data Sample Line Avg: Chromatograph (ppm) 15 14.0 Silt Siltst ClystCht Hughes GT-C1 6750' 3545' 109.20 9.20 0.46 Nabors 19AC $6,336.97 AK-AM-0006852352 10.63 0.942 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 7 08/02/2011-04:00 6506' North Slope Daily Charges Avg 10.75 1.271 80.3 146 Gas (units) ml/30min Max:Ambient Air Pit Room 48 11.16 pH Chlorides GvlCoal 10.66 Min 11.73 Avg 5.5 mg/l 11.54 AvgMin Max Max API Filt 9.80 3145 4.2000 $47,950.76 798 188 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 602' Drilling J. Polya/ J. Haberthur 3503 Bottoms Up Flow In (gpm) Current Pump & Flow Data: 12.97 63.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)593 200 6848' Depth md Samples increase in siltstone, light gray to gray, maderately firm to firm.sub angular-subrounded, subblocky- blocky. Total Losses from Midnight to Midnight 0 bbls 11.1 ppg hi-vis sweep with 15% incr. in returns. Drill ahead at report time. Bottoms up from short trip 3503 units, Gas averaged 200 units for the last 24 hours of circulating and Gas averaged 474 units while , drilling Total Losses from Midnight to 0400 0 bbls BHA into casing, tight. Bk. ream t/3613'. confirm reamer closed. Backream to 2420' . Pack-off. RIH 2420'-2471, stage up t/400 gpm. Pump 2X BU. Back ream 2471'-2175'. TIH to 3803', pump 11.2 ppg hi-vis sweep with 25% incr. in cuttings. TIH to 6506', pump 50 bbl, PWD Drilling All Circ Avg Diam % 12.20 Pump 2X BU, heavy returns at shakers. Pump a 11 ppg hi-vis sweep, minimal incr. in cuttings. Back ream, attempt pull 11.85'' Max: Hole Condition On Bot Hrs 6506'32.15 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 11.22'' Max: Hole Condition On Bot Hrs 8287'56.12 Total Losses from Midnight to 0400 0 bbls PWD Drilling All Circ Avg Diam sweep return, sweep came to surface 500 strokes early. Service pumps. Drill ahead 7226'-7607'. Pump a 50 bbls high weight /non-hi-vis (Tandem) sweep at 7515' with no increase in cuttings. Down time, change out pump pop-off. Drill ahead, pump tandem Drilling ahead 6750'-7226'. Pump a 50 bbls 11.2 ppg high viscosity sweep at 7131' with 50% increase in cuttings with Depth md Samples predominately claystone with equal amonts of siltstone/shale & tuff, light gray to gray, moderately firm to firm.sub angular -subrounded, subblocky- blocky. Samples 70% mud additives. Total Losses from Midnight to Midnight 0 bbls sweep with 15% increase in cuttings. Change out pump pop-off. Continue drilling ahead from 7515 to 8302'. Pumped a tandem Sweep at 8287, volume increase coming back 500% (started with trace amount returning). Sweep came back 534 strokes early. Based on this sweep, average hole size is 11.22" Current R.O.P. (ft/hr) Gas (units)297 288 6848' 1781' Drilling J. Polya/ J. Haberthur 708 Bottoms Up Flow In (gpm) Current Pump & Flow Data: 11.82 3472 4.2000 $54,287.73 813 191 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 11.82 7.0 mg/l 11.50 AvgMin Max Max11.09 pH Chlorides GvlCoal 11.02 Min 11.50 Avg ml/30min Max:Ambient Air Pit Room 1.271 84.5 158 Gas (units) 49 85.0 8 08/03/2011-04:00 8287' North Slope Daily Charges Avg 10.75 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 9.35 9.35 0.46 Nabors 19AC $6,336.97 AK-AM-0006852352 10.63 0.942 12.0 Silt Siltst ClystCht Hughes GT-C1 8083' 3545' 11 Chromatograph (ppm) 15 H2S Data Sample Line Avg: 3545' 20' 55 C2C1 Sh 3 Sd Depth Max 5.8 Lst 3525' 200 300 HDBS FXG65s 25 C4 C5 Tuff Gas Breakdown Avg: 5 Average Sst C3 API Filt 9.40 63 20 Colby Marks / Mark Lindloff Ann Corr Cor Solids (lb/100ft2) 19,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks / Mark Lindloff Ann Corr Cor Solids (lb/100ft2) 20,000 24 hr Max 802 YP 124 63 3147 1505 C3 3800 27 Tuff Gas Breakdown 8300 Avg: 30 296 Average Sst 71 C4 C5 232 572 Sd Depth Max 5.8 Lst 3525' 200 300 HDBS FXG65s 45 1753 618 3545' 20' 15 C2C1 Sh 15.00 3 8450 8700 8900 1763 1030 H2S Data Sample Line Avg: 5 48641 Chromatograph (ppm) 5 6966 8235 11.0 Silt Siltst ClystCht Hughes GT-C1 8083' 3545' 9224' 109.45 9.45 5679' 0.46 Nabors 19AC $6,336.97 AK-AM-0006852352 10.63 0.942 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 9 08/04/2011-04:00 9224' North Slope 8400 8700 Daily Charges Avg 10.75 1.271 76.9 177 Gas (units) ml/30min 1944 Max:Ambient Air Pit Room 49 11.30 pH Chlorides GvlCoal 11.27 Min 11.51 Avg 7.0 mg/l 11.30 AvgMin Max Max API Filt 9.90 0 4.2000 $60,624.70 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 937' Short Trip to Shoe Rodney Klepzig,/ J. Haberthur 2173 Bottoms Up Flow In (gpm) Current Pump & Flow Data: 11.78 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 757 6848' Depth md Samples in the Torok 90% sandstone, clear, brown, white to frost, very fine to medium grain, subangular, moderately sorted, unconsolidated, predominately quartz, trace glaucanite, trace yellow fluoresence. Total Losses from Midnight to Midnight 0 bbls for short trip. No losses to report down hole. Gas while drilling averaged 738 while drilling the Torok with a max gas of 2173 units Gas while circulating averaged 95 Units with a Max Gas 646 units Total Losses from Midnight to 0400 0 bbls with medium to heavy returns Drill 8825'-9224 TARGET DEPTH. Circulate and condition. Pump tandem sweep 50 bbl/50 bbls as above with no increase in cuttings at shakers with returns. Sweep back 480 strokes early. Circulate and start POOH PWD Drilling All Circ Avg Diam % 11.78 Drilling ahead 8287'-8825'.8750' pumped tandem sweep: 20 bbls 11.4 ppg followed by 34 bbls 11.4, 200 vis 11.75'' Max: Hole Condition On Bot Hrs 9224'69.18 2173 1173 176544 151541 470 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 11.75'' Max: Hole Condition On Bot Hrs 9224'69.18 Total Losses from Midnight to 0400 0 bbls PWD Drilling All Circ Avg Diam pack-off. Circulate and condition and RIH to circulate at 3988', pack -off at 450 gpm, 700 psi. POOH 4052'-3772'. Circulate and condition 400 gpm, no losses. Back ream to 3500'. Drop RHINO reamer deactivation ball. Back ream 3772'-3224'. POOH to 1885', service Trip out of the hole to 4503' with tight spot at 5151'. Circulate and condition, RIH 4503' -4551'. Back ream to 3930', Depth md Total Losses from Midnight to Midnight 82 bbls during pack off top drive. Finish pulling pipe out of hole and currently laying down BHA Current R.O.P. (ft/hr) Gas (units)0 37 0' 0' Lay Down BHA Rodney Klepzig,/ J. Haberthur 297 Cir Flow In (gpm) Current Pump & Flow Data: 15.96 0 4.2000 $68,629.71 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 7.0 mg/l AvgMin Max Max pH Chlorides GvlCoal 12.37 Min 13.10 Avg ml/30min Max:Ambient Air Pit Room 1.271 0.0 0 Gas (units) 50 0.0 10 08/05/2011-04:00 9224' North Slope Daily Charges Avg 10.75 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 9.35 9.35 69.18 5679' 0.46 Nabors 19AC $6,336.97 AK-AM-0006852352 10.63 0.942 11.0 Silt Siltst ClystCht Hughes GT-C1 8083' 3545' 9224' 9 5 Chromatograph (ppm) 5 H2S Data Sample Line Avg: 3545' 20' 15 C2C1 Sh 15.00 3 Sd Depth Max 4.0 Lst 3525' 200 300 HDBS FXG65s 45 C4 C5 Tuff Gas Breakdown Avg: 30 Average Sst C3 API Filt 9.50 124 63 50 Colby Marks / Mark Lindloff Cost of Consumables Added Ann Corr Cor Solids (lb/100ft2) 19,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks / Mark Lindloff Ann Corr Cor Solids (lb/100ft2) 18,000 24 hr Max YP 124 C3 22 Tuff Gas Breakdown Avg: 30 Average Sst C4 C5 Sd Depth Max 5.8 Lst 3545' 300 400 Bull Nose 45 9224' 5679' 15 C2C1 Sh 15.00 H2S Data Sample Line Avg: 5 Chromatograph (ppm) 5 12.0 Silt Siltst ClystCht HDBS FXG65s 8083' 9224' 9224' 129.45 9.45 0.00 0' 69.18 Nabors 19AC $6,336.97 AK-AM-0006852352 10.75 1.271 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 11 08/06/2011-04:00 9224' North Slope Daily Charges Avg 10.75 0.000 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 47 pH Chlorides GvlCoal 9.50 Min 11.79 Avg 6.6 mg/l AvgMin Max Max API Filt 9.80 3520 4.2000 $74,966.68 762 185 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Clean Out Run R. Klepzig,/ J. Cortez 914 Cir Flow In (gpm) Current Pump & Flow Data: 12.41 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)340 72 0' Depth md Total Losses from Midnight to Midnight 35 bbls during trip 6954'-8438' Total Losses from Midnight to 0400 0 bbls and condition drilling fluid, pull test RHINO reamer, good. Trip into the hole to 6919'. Circulate and condition 6919'to 6954' with heavy cuttings returns at shakers. Screen down to prevent fluid loss. Start centrifuge and de-silter. Wash and ream into hole PWD Drilling All Circ Avg Diam % Clean and clear rig floor. Make up Bull-nose BHA and RHINO reamer. Shallow test. Trip into hole to 3532' and circulate 11.75'' Max: Hole Condition On Bot Hrs 9224'69.18 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 7 11.75'' Max:10 Hole Condition On Bot Hrs 9224' Total Losses from Midnight to 0400 0 bbls PWD Drilling All Circ Avg Diam Circulated and conditioned hole, H2S Rig evacuation at 1:35, Resumed duties at 3:00. Currently circulating at time of report Pumped 1st High Vis sweep at 8:11, 9,204', Achieved less than 10% returns Continue run to bottom for Clean Out Run - Started fighting Pack-off at 09:33. Re established cirulation at 21:00. Depth md Total Losses from Midnight to Midnight 17 bbls Circulation Loss Pumped 2nd High Vis sweep at 9:35 9,085', did not return due to pack off Pumped 3rd High Vis sweep at 00:01 9,224', Sweep came back on time but could not be evaluated due to H2S related rig evacuation. Current R.O.P. (ft/hr) Gas (units)0 178 0' 0' Clean Out Run R. Klepzig,/ J. Cortez 844 Cir Flow In (gpm) Current Pump & Flow Data: 13.68 450 4.2000 $81,303.65 166 40 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 6.6 mg/l AvgMin Max Max pH Chlorides GvlCoal 11.18 Min 11.68 Avg ml/30min 8Max:Ambient Air Pit Room 0.000 0.0 0 Gas (units) 47 0.0 11 08/07/2011-04:00 9224' North Slope Daily Charges Avg 10.75 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 9.45 9.45 0.00 0' 69.18 Nabors 19AC $6,336.97 AK-AM-0006852352 10.75 1.271 12.0 Silt Siltst ClystCht HDBS FXG65s 9224' 9224' 9224' 12 5 Chromatograph (ppm) 5 H2S Data Sample Line Avg: 9224' 5679' 15 C2C1 Sh 15.00 Sd Depth Max 5.8 Lst 3545' 300 400 Bull Nose 45 C4 C5 Tuff Gas Breakdown 4Avg: 30 Average Sst C3 API Filt 9.80 124 22 Colby Marks / Mark Lindloff Ann Corr Cor Solids (lb/100ft2) 18,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 7 11.75'' Max:10 Hole Condition On Bot Hrs 9224' Total Losses from Midnight to 0400 0 bbls PWD Drilling All Circ Avg Diam stage up to 700gpm. Trip out of hole to 5717' 800gpm, intermittent pack-offs. Back-ream 5717' to 5100', 800gpm, 3200psi. Circulate, Condition. Pack-off at 5000'. Run in hole to 5090', Pump 50 barrel hi-vis sweep, heavy cuttings prior to sweep 500% 21:50 arrived 234 strokes early. heavy cuttings prior to sweep, 500% increase upon return. Circulate Bottoms Up 750gpm, 3050psi, 20rpm, 9K torque Trip out of hole to 6219', 500 gpm. Circulate, Condition Depth md Total Losses from Midnight to Midnight 0 losses increase in cuttings with sweep. Sweep came back 234 strokes early. Pump out of hole to 4673' at time of report. Pumped 50 barrel high-vis sweep at 0:50. 50% increase upon return. Arrived 10 strokes early. Pumped second High-vis sweep at Current R.O.P. (ft/hr) Gas (units)379 137 0' 0' Clean Out Run R. Klepzig,/ J. Cortez 629 Cir Flow In (gpm) Current Pump & Flow Data: 15.26 450 4.2000 $87,640.62 703 82 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 8.1 mg/l AvgMin Max Max pH Chlorides GvlCoal 10.99 Min 12.20 Avg ml/30min 8Max:Ambient Air Pit Room 0.000 0.0 0 Gas (units) 48 0.0 13 08/08/2011-04:00 9224' North Slope Daily Charges Avg 10.75 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 9.55 9.55 0.00 0' 69.18 Nabors 19AC $6,336.97 AK-AM-0006852352 10.75 1.271 15.0 Silt Siltst ClystCht HDBS FXG65s 9224' 9224' 9224' 9 5 Chromatograph (ppm) 5 H2S Data Sample Line Avg: 9224' 5679' 15 C2C1 Sh 15.00 Sd Depth Max 6.0 Lst 3545' 300 400 Bull Nose 45 C4 C5 Tuff Gas Breakdown 4Avg: 30 Average Sst C3 API Filt 9.50 124 24 Colby Marks / Mark Lindloff Ann Corr Cor Solids (lb/100ft2) 18,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks / David Mckechnie Ann Corr Cor Solids (lb/100ft2) 18,000 24 hr Max YP 124 C3 22 Tuff Gas Breakdown 4Avg: 30 Average Sst C4 C5 Sd Depth Max 6.0 Lst 3545' 300 400 Bull Nose 45 9224' 5679' 15 C2C1 Sh 15.00 H2S Data Sample Line Avg: 5 Chromatograph (ppm) 5 15.0 Silt Siltst ClystCht HDBS FXG65s 9224' 9224' 9224' 109.60 9.60 0.00 0' 69.18 Nabors 19AC $7,242.34 AK-AM-0006852352 10.75 1.271 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 13 08/09/2011-04:00 9224' North Slope Daily Charges Avg 10.75 0.000 0.0 0 Gas (units) ml/30min 8Max:Ambient Air Pit Room 51 pH Chlorides GvlCoal 11.11 Min 11.93 Avg 8.6 mg/l AvgMin Max Max API Filt 9.40 450 4.2000 $94,882.96 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Clean Out Run R. Klepzig,/ J. Cortez 629 Cir Flow In (gpm) Current Pump & Flow Data: 14.25 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)379 137 0' Depth md Total Losses from Midnight to Midnight - 70 loss down hole Trip out of hole from 3850' to 1913'. Mix spacer and 17.0 ppg kill pill. Trip out of hole, monitor the well and removed the RCD. Trip the rest of the way out of the hole and layed down BHA. Maintain top drive and test blow out preventer. Currently testing BOP at the time of report. Total Losses from Midnight to 0400 0 bbls maintains hammer mills that were packed off with clay. Circulate and condition the well. Stage up pumps to 750 GPM. with intermittent pack-offs. Circulate and stage up pumps to 850 GPM and pump 4 Bottoms ups while the hole unloaded shale. PWD Drilling All Circ Avg Diam % Circulate and condition the well at 500 gpm, 1,700 PSI while MPD unplugged cuttings buildup in choke lines and RSC 11.75'' Max:10 Hole Condition On Bot Hrs 9224' 7 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 11.75'' Max: Hole Condition On Bot Hrs 9224' Total Losses from Midnight to 0400 0 bbls PWD Drilling All Circ Avg Diam bottoms up at 850 gpm, determined 83 bbls of washout. Pump 140 bbls of 15.4 ppg high viscosity pill. Trip out of hole to 3,498'. circulate and condition, service the rig. Trip into hole to 3,900'. Pumped 71 bbls of 15.9 ppg cement and chased with 50bbls of Test BOP PU 4" DP equip. Trip in the hole to 4,300' Circulate and condition the well. Conduct carbide test, circulate Depth md Total Losses from Midnight to Midnight - 0 losses down hole active mud. Cement was in place at 15:10 HRS. Circulate and condition at 3,493'. Pump wiper ball and 2 bottoms ups. Trip in hole and tag cement at 3,770 at 18:30 HRS. Circulate out contaminated mud, treat and dump at surface. Pump 25 bbls of 15.9 PPG cement, chase with 52 bbls of 10.5 ppg active mud. Trip out of hole to 3498. Current R.O.P. (ft/hr) Gas (units)3 12 0' 0' Cement R. Klepzig,/ J. Cortez 237 Cir Flow In (gpm) Current Pump & Flow Data: 0.00 1450 4.2300 $101,587.74 795 95 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 16.7 mg/l AvgMin Max Max pH Chlorides GvlCoal 0.00 Min 0.00 Avg ml/30min Max:Ambient Air Pit Room 0.000 0.0 0 Gas (units) 55 0.0 15 08/10/2011-04:00 9224' North Slope Daily Charges Avg 4" (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 10.70 10.70 23.58 0' 69.18 Nabors 19AC $6,336.97 AK-AM-0006852352 10.75 1.271 19.0 Silt Siltst ClystCht HDBS FXG65s 9224' 9224' 9224' 14 5 Chromatograph (ppm) 5 H2S Data Sample Line Avg: 9224' 5679' 15 C2C1 Sh 15.00 Sd Depth Max 10.5 Lst 3545' 300 450 cement stinger 45 C4 C5 Tuff Gas Breakdown Avg: 30 Average Sst C3 API Filt 10.20 79 124 26 Colby Marks / David Mckechnie Ann Corr Cor Solids (lb/100ft2) 17,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 11.75'' Max: Hole Condition On Bot Hrs 9224'0.33 Total Losses from Midnight to 04:00- 6.3 bbls lost during trip out of hole PWD Drilling All Circ Avg Diam 71 barrels of 15.9 ppg cement. Ecountered slight pack off during cement job. Squeezed cement at 350 psi. Trip into hole and wash down to 3,300'. Circulate and condition. Pulled out of hole and layed down drill pipe and 3rd party tools. Picked up bottom hole Currently pulling out of hole to inspect bottom hole assembly at time of report. Trip in hole and tag cement at 3,670'. Circulate and condition. Pump 11 barrels of water, test cement lines and pump Depth md Total Losses from Midnight to Midnight - 0 losses down hole assembly. Uploaded and shallow tested MWD tools. Success. Trip into hole to 3,000'. Tagged cement. Ciculated and conditioned mud. Clean out cement stinger. Washed down to 3,308. Drilled out cement to 3,529. Downlinked and packed-off. Geo Pilot housing stuck onto the casing shoe. Jarred free at 23:30 hrs. Circulated and conditioned. Prepare to pump dry job and Current R.O.P. (ft/hr) Gas (units)0 18 0' 17' Pull out of hole R. Klepzig,/ J. Cortez 235 Cir Flow In (gpm) Current Pump & Flow Data: 12.74 0 4.2300 $107,924.71 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 15.7 mg/l AvgMin Max Max pH Chlorides GvlCoal 10.87 Min 11.37 Avg ml/30min Max:Ambient Air Pit Room 0.0 0 Gas (units) 55 0.0 16 08/11/2011-04:00 3512' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 10.70 10.70 16.46 Nabors 19AC $6,336.97 AK-AM-0006852352 10.6 1.270 19.0 Silt Siltst ClystCht PDC 9224'14 5 Chromatograph (ppm) 5 H2S Data Sample Line Avg: 3529' 17' 15 C2C1 Sh 0.00 Sd Depth Max 10.3 Lst 3512' 500 45 C4 C5 Tuff Gas Breakdown Avg: 30 Average Sst C3 API Filt 11.70 0 26 Colby Marks / David Mckechnie Ann Corr Cor Solids (lb/100ft2) 17,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 10.63'' Max: Hole Condition On Bot Hrs 3800'0.33 Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam performed a successful shallow test. Reamed and washed to bottom, drilled ahead to 3,619'. Displaced active system with new 11.0 ppg LSND. Had multiple pack-off issues. Pulled up inside the shoe and pumped a 55 bbl weighted sweep resulting in Pulled out of hole and layed down BHA/Geo Pilot. Picked up mud motor BHA. Ran into the hole at 3,490' where MWD Depth md Total Losses from Midnight to Midnight - 0 losses down hole heavy cuttings across the shakers, along with 3/4" - 1" cavings. Circulated the hole clean, ran back onto bottom, resumed drilling and pumping second sweep at time of report. Current R.O.P. (ft/hr) Gas (units)23 21 0' 271' Drilling R. Klepzig,/ J. Cortez 222 Cir Flow In (gpm) Current Pump & Flow Data: 12.63 2600 4.2300 $114,261.68 775 560 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 12.13 11.6 mg/l 11.43 AvgMin Max Max10.90 pH Chlorides GvlCoal 5.83 Min 11.38 Avg Cmt ml/30min Max:Ambient Air Pit Room 79.0 170 Gas (units) 55 73.0 17 08/11/2011-04:00 3800' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 11.00 11.00 16.46 Nabors 19AC $6,336.97 AK-AM-0006852352 10.6 0.856 4.5 Silt Siltst ClystCht GTC1 3775'17 Chromatograph (ppm) 40 H2S Data Sample Line Avg: 3800' 271' C2C1 Sh 12.00 Sd Depth Max 4.4 Lst 3529' 600 C4 C5 Tuff Gas Breakdown Avg: 40 20 Average Sst C3 API Filt 9.70 80 42 Colby Marks / David Mckechnie Ann Corr Cor Solids (lb/100ft2) 18,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks / David Mckechnie Ann Corr Cor Solids (lb/100ft2) 18,500 24 hr Max YP 48 C3 46 Tuff Gas Breakdown Avg: 15 Average Sst C4 C5 Sd Depth Max 5.2 Lst 3529' 600 4241' 712' 70 C2C1 Sh 12.00 H2S Data Sample Line Avg: Chromatograph (ppm) 15 11.0 Silt Siltst ClystCht GTC1 4241'1610.90 10.90 38.99 Nabors 19AC $6,336.97 AK-AM-0006852352 10.6 0.856 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 18 08/13/2011-04:00 4,241.23' North Slope Daily Charges Avg 19.2 134 Gas (units) ml/30min Max:Ambient Air Pit Room 60 Cmt 11.36 pH Chlorides GvlCoal 11.11 Min 11.63 Avg 11.6 mg/l 11.68 AvgMin Max Max API Filt 9.50 0 3.5530 $120,598.65 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 441' Picking up Geo Pilot R. Klepzig,/ J. Cortez 60 Cir Flow In (gpm) Current Pump & Flow Data: 12.63 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 26 188' Depth md Total Losses from Midnight to Midnight - 0 losses down hole Pack-off events. Circulated 2 bottoms ups, continued to trip out to 1,672' and pumped out as needed. Tripped out of the hole to 625' and layed down the BHA. Read MWD tools and currently Picking up the Geo pilot at time of report. Total Losses from Midnight to 04:00- 0 bbls down hole 50 barrel sweep at 3,797'. Serviced the top drive then drilled out to 4,241'. Pumped another high viscosity 50 barrel 13.0 ppg sweep and received 100% increase in volume along with 1 1/2" to 4" tuff cavings. Pumped out of the hole to 3,480' with intermittent PWD Drilling All Circ Avg Diam % 12.10 Tripped in hole and washed down to 3,619'-encountered minor pack-off. Drilled to 4,170'. pumped a high viscosity 10.63'' Max: Hole Condition On Bot Hrs 4241'10.22 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 11.75'' Max: Hole Condition On Bot Hrs 4241'13.36 Total Losses from Midnight to 04:00- 0 bbls down hole PWD Drilling All Circ Avg Diam Washed and reamed when needed to 3,512'. Tripped into hole to 4,241' and washed and reamed where necessary with intermittent Pack-offs along the way. Driled out to 4,322 and activated Rhino Reamer. Drilled to 4,852 and circulated an 80 Layed down BHA # 6. Picked up BHA # 7 and ran in the hole. Shallow tested MWD tools at 665' with success. Depth md Total Losses from Midnight to Midnight - 0 losses down hole barrel 13.0 ppg high viscosity sweep at 4,675'. 100% increase in cuttings over the shakers Performed a 220 barrel dilution with new 11.0 ppg LSND from RSC. Serviced the top drive and drilled ahead to 5,136. pumped another High Viscosity sweep with 100% increase in cuttings over the shakers. Currently drilling ahead at 5231 at time of report. Current R.O.P. (ft/hr) Gas (units)18 26 5231' 990' Drilling R. Klepzig,/ J. Cortez 88 5215' Flow In (gpm) Current Pump & Flow Data: 12.63 3412 3.5530 $126,935.62 850 119 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 12.34 11.1 mg/l 11.84 AvgMin Max Max11.25 pH Chlorides GvlCoal 11.11 Min 11.63 Avg Cmt ml/30min Max:Ambient Air Pit Room 76.6 153 Gas (units) 65 0.0 19 08/14/2011-04:00 5231' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 11.00 11.00 24.51 Nabors 19AC $6,336.97 AK-AM-0006852352 10.6 1.270 13.0 Silt Siltst ClystCht FXG65s 5231'31 Chromatograph (ppm) 5 H2S Data Sample Line Avg: 990' 90 C2C1 Sh 6.10 Sd Depth Max 4.0 Lst 4241' 700 C4 C5 Tuff Gas Breakdown Avg: 5 Average Sst C3 API Filt 9.40 84 54 Colby Marks / David Mckechnie Ann Corr Cor Solids (lb/100ft2) 19,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks / David Mckechnie Ann Corr Cor Solids (lb/100ft2) 19,000 24 hr Max YP 137 C3 48 Tuff Gas Breakdown Avg: 15 5 Average Sst C4 C5 Sd Depth Max 2.2 Lst 4241' 700 5 2294' 70 C2C1 Sh 17.80 H2S Data Sample Line Avg: Chromatograph (ppm) 5 16.0 Silt Siltst ClystCht FXG65s 5231'3011.10 11.25 44.42 Nabors 19AC $6,336.97 AK-AM-0006852352 10.6 1.270 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 20 08/15/2011-04:00 6535' North Slope Daily Charges Avg 74.2 163 Gas (units) ml/30min Max:Ambient Air Pit Room 60 Calc 11.74 pH Chlorides GvlCoal 11.59 Min 12.04 Avg 11.1 mg/l 12.05 AvgMin Max Max API Filt 9.50 3700 3.5530 $133,272.59 850 120 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 1304' Drilling R. Klepzig,/ J. Cortez 199 6464' Flow In (gpm) Current Pump & Flow Data: 12.51 Max @ ft Current R.O.P. (ft/hr) Gas (units)30 45 5600' Depth md Total Losses from Midnight to Midnight - 0 losses down hole in volume over shakers. Serviced top drive, drilled to 6,252', repaired mud pump.Drilled out to 6,535' and pumped another sweep with over 100% returns over shakers. Cavings reduced almost entirely throughout sweeps. Back reaming at time of report. Total Losses from Midnight to 04:00- 0 bbls down hole 5,617 and pumped an 80 bbl 13.0 ppg high vis sweep with 100% increase in volume over the shakers. Drilled to 6,181 and performed 210 bbl dilution with new 11.0 ppg LSND from RSC. Pump 80 bbl 13.0 ppg high viscosity sweep with 100% increase PWD Drilling All Circ Avg Diam % 12.51 Drilled out to 5,175. Pumped 80 High Viscosity Sweep. 100% increase in Cuttings over the shakers. Drilled out to 10.77" Max: Hole Condition On Bot Hrs 6535'29.13 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks / David Mckechnie Ann Corr Cor Solids (lb/100ft2) 17,000 24 hr Max YP 142 C3 40 Tuff Gas Breakdown Avg: 5 5 Average Sst C4 C5 Sd Depth Max 2.1 Lst 4241' 700 5 3,082' 80 C2C1 Sh 26.00 H2S Data Sample Line Avg: Chromatograph (ppm) 5 18.0 Silt Siltst ClystCht FXG65s 7112'2711.00 11.00 68.14 Nabors 19AC $6,336.97 AK-AM-0006852352 10.6 1.270 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 21 08/16/2011-04:00 7323' North Slope Daily Charges Avg 61.6 93 Gas (units) ml/30min Max:Ambient Air Pit Room 64 Calc 11.55 pH Chlorides GvlCoal 11.35 Min 11.97 Avg 11.1 mg/l 11.95 AvgMin Max Max API Filt 10.00 3970 3.5530 $139,609.56 850 120 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 788' Drilling R. Klepzig,/ J. Cortez 235 7255' Flow In (gpm) Current Pump & Flow Data: 14.99 56.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)71 50 7323' Depth md Currently drilling ahead to 7,323' at time of report. Total Losses from Midnight to Midnight - 0 losses down hole volume inrease over the shakers. Tripped back into the hole to 6,467', reamed and washed to 6,535', staged up the pumps and rotated. Drilled out to 7,050'. Pumped 80 bbls high viscosity sweep with 10% increase over the shakers. Performed 200 llbs dilution with new 11.0 ppg LSND from RSC. Pumped 80 bbls high visc 13.0 ppg sweep sweep with 15% increase over the shakers. Total Losses from Midnight to 04:00- 0 bbls down hole Pumped 80 bbls of 13.0 ppg high viscosity sweep resulting in 100% returns over shakers. Back reamed to 4,356' with intermittent pack-offs and hole unloading. Circulated and conditioned, then pumped another 80 llbs high viscosity sweep with only 15% Serviced top drive. Drilled out to 7,250' and pumped another 80 bbls 13.0 ppg high visc sweep with 25% increase over the shakers. PWD Drilling All Circ Avg Diam % 12.47 Drilled out to 6,535', circulated and conditioned 1 bottoms up with ECD's at 12.0 ppg before and after circulation 11.54" Max: Hole Condition On Bot Hrs 7323'41.92 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 11.43'' Max: Hole Condition On Bot Hrs 8440'57 Total Losses from Midnight to 04:00- 0 bbls down hole PWD Drilling All Circ Avg Diam Drilled to 7,399'. Repaired mud pump washout and serviced top drive. Reciprocate drill pipe for 15 minutes during pump repair. Drilled out to 7,610' and pumped another 80 bbl high viscosity 13.0 ppg sweep with 20% increase over shakers. Drilled Drilled to 7,230' and pumped an 80 bbl, 13.0 ppg high viscosity sweep resulting in a 25% increase over the shakers. Depth md Total Losses from Midnight to Midnight - 0 losses down hole to 7,800' and performed a 200 bbl dilution with new 11.0 ppg LSND from RSC. Pumped 80 bbl 13.0 ppg high visc sweep with 20% increase at shakers. Serviced top drive and drilled ahead to 8,393'. Pumping 80 barrel 13.0 ppg high viscosity sweep at time of report. Current R.O.P. (ft/hr) Gas (units)60 55 8439' 1117' Drilling R. Klepzig,/ J. Cortez 86 8331' Flow In (gpm) Current Pump & Flow Data: 12.35 3978 3.5530 $145,946.53 845 119 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 12.35 11.1 mg/l 12.01 AvgMin Max Max11.66 pH Chlorides GvlCoal 11.51 Min 11.95 Avg Calc ml/30min Max:Ambient Air Pit Room 74.4 123 Gas (units) 67 87.0 22 08/17/2011-04:00 8440' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 11.00 11.15 57.00 Nabors 19AC $6,336.97 AK-AM-0006852352 10.6 1.270 16.0 Silt Siltst ClystCht FXG65s 8275'37 Chromatograph (ppm) 5 H2S Data Sample Line Avg: 4199' 70 C2C1 Sh 14.00 Sd Depth Max 2.2 Lst 4241' 700 C4 C5 Tuff Gas Breakdown Avg: 25 Average Sst C3 API Filt 10.00 143 52 Colby Marks / David Mckechnie Ann Corr Cor Solids (lb/100ft2) 18,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 11.11'' Max: Hole Condition On Bot Hrs 9100'66 Total Losses from Midnight to 04:00- 0 bbls down hole PWD Drilling All Circ Avg Diam 8,936'. Repaired pump #2 swab/liner. Drilled to 9,032' Repaired pump #1 swab/liner. Drilled to 9,100' T.D. Ciculated 3 Bottoms ups and pumped an 85 bbl 13.0 ppg high viscosity sweep with 0% increase at the shakers. Ciculated and conditioned, dropped 2" Drilled to 8,400', Pumped an 80 bbl 13 ppg high viscosity sweep with 10% increase in volume at the shakers. Drilled to Depth md Total Losses from Midnight to Midnight - 0 losses down hole ball and deactivated the Rhino Reamer blades. Back reaming to 6,132' at time of report. Current R.O.P. (ft/hr) Gas (units)41 218 8659' 660' Trip to shoe R. Klepzig,/ J. Cortez 715 8790' Flow In (gpm) Current Pump & Flow Data: 12.51 3800 3.5530 $152,283.50 838 119 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 0.00 11.4 mg/l 0.00 AvgMin Max Max0.00 pH Chlorides GvlCoal 11.71 Min 12.09 Avg Calc ml/30min Max:Ambient Air Pit Room 73.3 127 Gas (units) 60 0.0 23 08/18/2011-04:00 9100' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 11.00 11.15 66.00 Nabors 19AC $6,336.97 AK-AM-0006852352 10.6 1.270 14.0 Silt Siltst ClystCht FXG65s 9100'21 Chromatograph (ppm) 5 H2S Data Sample Line Avg: 9100' 4859' 80 C2C1 Sh 0.00 Sd Depth Max 2.2 Lst 4241' 700 C4 C5 Tuff Gas Breakdown Avg: 15 Average Sst C3 API Filt 10.20 91 49 Colby Marks / David Mckechnie Ann Corr Cor Solids (lb/100ft2) 18,500 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks / David Mckechnie Ann Corr Cor Solids (lb/100ft2) 18,500 24 hr Max YP 91 C3 49 Tuff Gas Breakdown Avg: 70 Average Sst C4 C5 Sd Depth Max 3.2 Lst 4241' 700 9100' 4859' 20 C2C1 Sh 0.00 H2S Data Sample Line Avg: Chromatograph (ppm) 10 20.0 Silt Siltst ClystCht FXG65s 9100'1811.00 11.15 66.00 Nabors 19AC $6,336.97 AK-AM-0006852352 10.6 1.270 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 24 08/19/2011-04:00 9100' North Slope Daily Charges Avg 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 80 Calc 0.00 pH Chlorides GvlCoal 9.96 Min 11.99 Avg 11.1 mg/l 0.00 AvgMin Max Max API Filt 10.00 0 3.5530 $158,620.47 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Triping out to 1,800' R. Klepzig,/ J. Cortez 235 circ Flow In (gpm) Current Pump & Flow Data: 15.32 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)5 9 0' Depth md Total Losses from Midnight to Midnight - 0 losses down hole Back ream to to 4,281'. Attempted to pull with elevators, but was tight. Short trip from 4,281' to 4,661'. Back reamed to 3,818'. hole unloading at 3,950'. Packed off and reciprocated pipe. Step up pumps at 3,965'. Circulate 3 bottoms ups with 80 bbl 13.0 ppg high viscosity sweep. 100% increase including large cavings. Back reamed to 3,607'. Pumped 80 bbl 13.0 ppg high viscosity Total Losses from Midnight to 04:00- 0 bbls down hole out of hole to 4,566'. Circulated two bottoms ups with an 80 bbl 13.0 ppg high viscosity sweep. 100% increase including large cavings. Trip out of hole to 4,378', Circulate 2 bottoms ups with 85 bbls high viscosity 13.0 ppg sweep with 10% increase at shakers. sweep at 3,476' with 100+% increase at shakers with 1" to 5" shale cavings. Performing rig maintenance at time of report. PWD Drilling All Circ Avg Diam % 0.00 Repair pump #1. Trip out of hole to 6,100', Pack-off. Trip out of hole to 5,611'. Repair #1 and #3. Off hi line power. Trip 11.11'' Max: Hole Condition On Bot Hrs 9100'66 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks / David Mckechnie Ann Corr Cor Solids (lb/100ft2) 20,000 24 hr Max YP 0 C3 41 Tuff Gas Breakdown Avg: 90 Average Sst C4 C5 Sd Depth Max 2.7 Lst 9100' 800 9100' 0' 10 C2C1 Sh 0.00 H2S Data Sample Line Avg: Chromatograph (ppm) 20.0 Silt Siltst ClystCht Tricone 9100'2911.00 11.15 13.98 Nabors 19AC $6,336.97 AK-AM-0006852352 10.5 2.356 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 25 08/20/2011-04:00 9100' North Slope Daily Charges Avg 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 65 Calc 0.00 pH Chlorides GvlCoal 9.83 Min 11.75 Avg 11.0 mg/l 0.00 AvgMin Max Max API Filt 10.00 0 3.5530 $164,957.44 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Trip Out of Hole R. Klepzig,/ J. Cortez 0 circ Flow In (gpm) Current Pump & Flow Data: 11.96 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)5 9 0' Depth md at time of report. Total Losses from Midnight to Midnight - 0 losses down hole Rhino Reamer with no reamer blade deactivation during the pump test. Layed down Rhino Reamer and picked up BHA #8. Tripped into hole to 3,450'. Slip and cut drill line. Circulated and conditioned a bottoms up and tripped to 4,692 with no issues. Circulated and conditioned a bottoms up and staged pumps with no issues. Tripped out to 3,450 and pumped high viscosity Total Losses from Midnight to 04:00- 0 bbls down hole of the hole to 3,329', changed out swivel packing. Tripped out of the hole to 1,807'. Pumped 80 bbl high viscosity 13.0 ppg sweep with 100% increase in volume at the shakers. Tripped out of the hole and layed down the BHA. Picked up and tested BHA and sweep with inside casing with no cutting or cavings at the shakers. Tripping out of hole and laying down heavy weight drill pipe PWD Drilling All Circ Avg Diam % 0.00 Tripped out of the hole to 3,512' with intermittent pack-offs. Pumped 80 bbl 13.0 ppg high viscosity sweep. Tripped out 11.11'' Max: Hole Condition On Bot Hrs 9100'0 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 11.11'' Max: Hole Condition On Bot Hrs 9100'0 Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam the shakers. Pumped dry job. Tripped out of the hole and layed down the BHA. Monitored the well for 10 minutes. Static. Lay down BHA and download MWD. Rig up Tesco to run liner. Change the Rams on BOP's. Tested BOP's. Run in the hole with 9 5/8" liner Tripped out to 3,512' and pumped an 80 bbl 13.0 ppg high viscosity sweep with no significant cuttings increase at Depth md Total Losses from Midnight to Midnight - 26.5 bbls during liner run to 3,466'. Stage pumps and circulated 1 bottoms up with good returns. Run into hole at 5,844' with liner at time of report. (Run in the hole with liner- Open hole returns 80-50% at 5,844 ') Current R.O.P. (ft/hr) Gas (units)0 1 0' 0' Running Liner R. Klepzig,/ J. Cortez 15 circ Flow In (gpm) Current Pump & Flow Data: 0.00 0 3.5530 $171,294.41 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 0.00 N/A mg/l 0.00 AvgMin Max Max0.00 pH Chlorides GvlCoal 0.00 Min 0.00 Avg Calc ml/30min Max:Ambient Air Pit Room 0.0 0 Gas (units) 75 0.0 26 08/21/2011-04:00 9100' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 10.00 10.00 Nabors 19AC $6,336.97 AK-AM-0006852352 9.835 12.0 Silt Siltst ClystCht Liner 9100'12 Chromatograph (ppm) H2S Data Sample Line Avg: N/A 10 C2C1 Sh N/A Sd Depth Max 4.5 Lst C4 C5 Tuff Gas Breakdown Avg: 90 Average Sst C3 API Filt 10.0015 Colby Marks / David Mckechnie Ann Corr Cor Solids (lb/100ft2) 20,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks / David Mckechnie Ann Corr Cor Solids (lb/100ft2) 20,000 24 hr Max YP C3 15 Tuff Gas Breakdown Avg: 90 Average Sst C4 C5 Sd Depth Max 4.8 Lst 10 C2C1 Sh H2S Data Sample Line Avg: Chromatograph (ppm) 12.5 Silt Siltst ClystCht N/A 9100'1310.00 10.00 Nabors 19AC $4,865.75 AK-AM-0006852352 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 27 08/22/2011-04:00 9100' North Slope Daily Charges Avg 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 48 Calc 0.00 pH Chlorides GvlCoal 0.00 Min 0.00 Avg 8.5 mg/l 0.00 AvgMin Max Max API Filt 10.00 0 3.5530 $176,160.16 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Pressure Test Casing J. Poyla,/ J. Cortez 52 circ Flow In (gpm) Current Pump & Flow Data: 0.00 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 3 0' Depth md Total Losses from Midnight to Midnight - 8.2 bbls Plug did not pump. Tested floats. Circulated 1 and a half bottoms ups. Rigged down cement equipment and tripped out of the hole. Layed down the BHA, Rigged up to run in the hole with the bridge plug. Pressure tested casing. Tripping out of the hole at time of report. Total Losses from Midnight to 04:00- 0 bbls Run in hole with the liner on 5" DP to 9,098. (Returns to 100%) Establish circulation, step rate with 11.0 ppg LSND. Displaced to 10.0 ppg LSND.Drop 1 3/4" ball. Seat ball and set hanger. Rig up HES cement equipment. Pumped cement per HES program. PWD Drilling All Circ Avg Diam % 0.00 Run in hole with liner to 5,795' (Returns 80-50%) Rig down Tesco and make up Liner hanger packer running tool. 11.11'' Max: Hole Condition On Bot Hrs 9100'0 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 11.11'' Max: Hole Condition On Bot Hrs 9100'0 Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam PSI for 30 minutes. Bled back 4 bbls and released the run tool. Tripped out of the hole to surface. Nipple down BOP's, Risers, Spacers and spool. Nipple up BOP's,change rams, repaired top drive and tested BOP's. Made up HES bridge plug retrieval tool. Run in the hole with HES Bridge plug BHA to 3,222'. Set the bridge plug and perform casing test at the shoe to 3,500 Depth md Total Losses from Midnight to Midnight - 0 bbls Tripped into the hole to 3,321 and latched the bridge plug. Released per HES representative. Close rams, Tested the casing shoe at 3,500 psi for 30 minutes. Tripped out of the hole and currently making preperations for a clean out run at the time of report. Current R.O.P. (ft/hr) Gas (units)0 0 0' 0' Rig Up for clean out run J. Polya,/ J. Cortez 0 circ Flow In (gpm) Current Pump & Flow Data: 0.00 0 3.5530 $181,025.91 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 0.00 8.6 mg/l 0.00 AvgMin Max Max0.00 pH Chlorides GvlCoal 0.00 Min 0.00 Avg Calc ml/30min Max:Ambient Air Pit Room 0.0 0 Gas (units) 49 0.0 28 08/23/2011-04:00 9100' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 10.00 10.00 Nabors 19AC $4,865.75 AK-AM-0006852352 10.0 Silt Siltst ClystCht N/A 9100'14 Chromatograph (ppm) H2S Data Sample Line Avg: 10 C2C1 ShSd Depth Max 5.0 Lst C4 C5 Tuff Gas Breakdown Avg: 90 Average Sst C3 API Filt 10.0027 Colby Marks / David Mckechnie Ann Corr Cor Solids (lb/100ft2) 18,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks / David Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 18,000 24 hr Max YP C3 16 Tuff Gas Breakdown Avg: 100 Average Sst C4 C5 Sd Depth Max 4.6 Lst 9100' 900 9120' 20' C2C1 Sh H2S Data Sample Line Avg: Chromatograph (ppm) 1.5 Silt Siltst ClystCht Tricone 9100'79.80 9.80 0.63 Nabors 19AC $5,771.12 AK-AM-0006852352 6.75 0.856 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 29 08/24/2011-04:00 9120' North Slope Daily Charges Avg 34.0 143 Gas (units) ml/30min Max:Ambient Air Pit Room 45 Cmt 0.00 pH Chlorides GvlCoal 0.00 Min 0.00 Avg 9.0 mg/l 0.00 AvgMin Max Max API Filt 10.10 0 3.5530 $186,797.03 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 20' Pick up BHA J. Polya,/ J. Cortez 17 9110' Flow In (gpm) Current Pump & Flow Data: 0.00 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 10 9103' Depth md Total Losses from Midnight to Midnight - 0 bbls Test MPD lines. Pick up BHA an Geopilot for Run 1000. Total Losses from Midnight to 04:00- 0 bbls shoe. Tag cement at 9055' to drill to 9120'. Perform FIT test to 14.0 EMW. Circulate and Condition mud, Displace active system from 10.0ppg LSND to new 9.8 ppg LSND. Trip out hole to surface. Lay down BHA. Service Top Drive , Set test plug. PWD Drilling All Circ Avg Diam % 0.00 Trip out hole. Lay down BHA. Pick up new BHA , Trip in hole to drill out cement. Wash down an ream, then drill out 11.11'' Max: Hole Condition On Bot Hrs 9120'0.63 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks /Javian Ervin Ann Corr Cor Solids (lb/100ft2) 18,000 24 hr Max YP C3 21 Tuff Gas Breakdown 9691 Avg: 45 300 TR Average Sst 151 C4 C5 BG348 Sd Depth Max 4.0 Lst 9120' 1000 1341 596 35 C2C1 Sh H2S Data Sample Line Avg: 20 30951 Chromatograph (ppm) 2.5 Silt Siltst ClystCht FXG46Ds PDC 9555'169.80 9.80 Nabors 19AC $6,336.97 AK-AM-0006852352 8.5 1.035 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 30 08/25/2011-04:00 9746' North Slope 9692 Daily Charges Avg 56.9 94 Gas (units) ml/30min Max:Ambient Air Pit Room 45 Cmt 10.62 pH Chlorides GvlCoal 10.62 Min 12.97 Avg 10.1 mg/l 13.00 AvgMin Max Max API Filt 10.30 3551 3.5530 $194,605.22 645 958 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 626' Drilling J. Polya,/ J. Cortez 337 9711' Flow In (gpm) Current Pump & Flow Data: 13.30 73.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)395 180 9681' Depth md Total Losses from Midnight to Midnight - 0 bbls Total Losses from Midnight to 04:00- 0 bbls Wash and ream 8794' to 9120'. Drilling ahead. PWD Drilling All Circ Avg Diam % 13.30 Test MPD equipment. Pull test plug and install 9'' wear ring. Pick up BHA. Run in hole filling pipe at every 25 stands 8.5" Max: Hole Condition On Bot Hrs 9746'11.02 301 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks /Javian Ervin Ann Corr Cor Solids (lb/100ft2) 17,000 24 hr Max 853 YP 1218 876 C3 3503 30 Tuff Gas Breakdown 10032 Avg: 80 1500 Average Sst GP 594 C4 C5 CG1499 433 CG Sd Depth Max 4.0 Lst 9120' 1000 7842 3053 10 C2C1 Sh 10323 10502 10502 1032 534 H2S Data Sample Line Avg: 10 212273 Chromatograph (ppm) 2346 7078 8.5 Silt Siltst ClystCht FXG46Ds PDC 10575'2410.20 10.25 Nabors 19AC $6,336.97 AK-AM-0006852352 8.5 1.035 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 31 08/26/2011-04:00 10793' North Slope 10032 10323 Daily Charges Avg 61.8 91 Gas (units) ml/30min 1972 Max:Ambient Air Pit Room 55 Cmt 12.88 pH Chlorides GvlCoal 12.74 Min 13.07 Avg 9.3 mg/l 13.07 AvgMin Max Max API Filt 10.00 4111 3.5530 $200,942.19 697 685 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 1047' Drilling J. Polya,/ J. Cortez 2558 10032' Flow In (gpm) Current Pump & Flow Data: 13.65 69.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)455 400 10760' Depth md Total Losses from Midnight to Midnight - 0 bbls in barafibre, baracarb and steelseal prior to entering the Kuparuk formation to prevent seepage losses. No losses to the hole. Drilling ahead as plan. Total Losses from Midnight to 04:00- 0 bbls increase in cuttings returns. Pumped 80bbl 12ppg high vis sweep at 9840' returned at calculated strokes with no increase in cuttings returns. Downtime repair. Mud pump 2. Continued to drill ahead 10127' 700 gpm , 3950 psi 140 rpm. Began stringing PWD Drilling All Circ Avg Diam % 13.65 Drill ahead 9555' -10127' 700 gpm 4033 psi 140 rpm. Pumped a 35bbls 12ppg high vis sweep at 9650' with no 8.5" Max: Hole Condition On Bot Hrs 10793'27.95 1809 531 172290 52338 2558 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 1111 8.5" Max: Hole Condition On Bot Hrs 11187'32.89 Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam sweep with 10% increase in cuttings. Short trip to 9270'. Pump 40bbl 12.1 ppg high viscosity sweep with 30% increase in cuttings Trip out of the hole to 8978'. Service top drive. Trip into the hole to 11187', pump 40 bbl 12.1 ppg high viscosity sweep. Take on Service rig pumps. Drill ahead 10830' to 11187' (TD). Circulate and condition, pump 80 bbls 12.1 ppg high viscosity Depth md Total Losses from Midnight to Midnight - 0 bbls 17.0 ppg spike fluid to inactive pit #5 and weight up to 13.0 ppg in preparation for displacement/blend to 13.0 ppg. Currently POOH at report time. Current R.O.P. (ft/hr) Gas (units)7 230 10991' 394' Condition/Circulating J. Polya,/ J. Cortez 1111 11020' Flow In (gpm) Current Pump & Flow Data: 17.36 3.5530 $207,279.16Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 17.36 9.4 mg/l 13.12 AvgMin Max Max12.69 pH Chlorides GvlCoal 2.76 Min 13.09 Avg Cmt ml/30min Max:Ambient Air Pit Room 79.7 97 Gas (units) 55 0.0 32 08/27/2011-04:00 11187' North Slope 11020 Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 13.50 12.50 32.89 Nabors 19AC $6,336.97 AK-AM-0006852352 8.5 1.035 8.0 Silt Siltst ClystCht FXG46Ds PDC 11187'24 10 98150 Chromatograph (ppm) H2S Data Sample Line Avg: 2797 11187' 2067' C2C1 Sh 25.00 Sd Depth Max 4.0 Lst 9120' 1000 844 C4 C5 GP1775 Tuff Gas Breakdown 11020 Avg: 90 230 Average Sst C3 API Filt 10.00 140 34 4859 Colby Marks /Javian Ervin Ann Corr Cor Solids (lb/100ft2) 18,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 8.5" Max: Hole Condition On Bot Hrs 11187'32.89 Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam in cuttings. Beging fluid blending , weight up to 13.0 ppg using 17.0 ppg spike fluid. Maintain 13.0 ppg going down hole. Change out rotating head, monitor well 10 minutes, static, Trip out hole and lay down BHA. Pick up 4" drill pipe. Trip into the hole Circulate and reciprocate 11187'-11090' Pump 35bbl 12.1 ppg sweep 700 gpm, 400 psi, 140 rpm. With no increas Depth md Total Losses from Midnight to Midnight - 0 bbls with 4" to 1092'. Run into hole with 5" drillpipe to report depth 7754'. Service rig. Circulating. Current R.O.P. (ft/hr) Gas (units)0 0 0' 0' Condition/Circulating J. Polya,/ J. Cortez 0 0' Flow In (gpm) Current Pump & Flow Data: 0.00 3.5530 $213,616.13Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 0.00 20.2 mg/l 0.00 AvgMin Max Max0.00 pH Chlorides GvlCoal 0.00 Min 0.00 Avg Cmt ml/30min Max:Ambient Air Pit Room 0.0 0 Gas (units) 62 0.0 33 08/28/2011-04:00 11187' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 13.00 13.00 32.89 Nabors 19AC $6,336.97 AK-AM-0006852352 8.5 1.035 7.5 Silt Siltst ClystCht FXG46Ds PDC 11187'35 Chromatograph (ppm) H2S Data Sample Line Avg: 11187' 2067' C2C1 Sh 25.00 Sd Depth Max 4.0 Lst 9120' 10.5 C4 C5 Tuff Gas Breakdown Avg: Average Sst C3 API Filt 9.50 140 47 Colby Marks /Javian Ervin Ann Corr Cor Solids (lb/100ft2) 17,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 8.5" Max: Hole Condition On Bot Hrs 11187'32.89 Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam Pump 29 bbls water. 59 bbls of cement chase with 173 bbls mud. fTOOH to 10416', circulate 761 bbls. Pump 29 bbls of water. 59 abbls cement, chase with 162 bbls. TOOH 9654', circulate 592 bbls, 500 gpm. Pump 65 bbls cement, chase with 148 bbls mud TIH to 11177', Circulate and Condition hole. Staging to 500 gpm. Rig up cement equipment. 3 stage cement plug Depth md Total Losses from Midnight to Midnight - 0 bbls TOOH to 8798. Displace well from 13.0 ppg to 9.8 ppg. 500-700 gpm, 150 rpm. TOOH, Lay down muleshoe. Service rig. Pick up drilling Geo-Pilot BHA/MWD tools and test same. Trip in hole Current R.O.P. (ft/hr) Gas (units)0 25 0' 0' Condition/Circulating J. Polya,/ J. Cortez 74 Circ Flow In (gpm) Current Pump & Flow Data: 0.00 3.5530 $219,953.10Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 0.00 8.1 mg/l 0.00 AvgMin Max Max0.00 pH Chlorides GvlCoal 0.00 Min 0.00 Avg Cmt ml/30min Max:Ambient Air Pit Room 0.0 0 Gas (units) 50 0.0 34 08/28/2011-04:00 11187' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 9.90 9.90 32.89 Nabors 19AC $6,336.97 AK-AM-0006852352 8.5 1.035 4.5 Silt Siltst ClystCht FXG46Ds PDC 11187'13 Chromatograph (ppm) H2S Data Sample Line Avg: 11187' 2067' C2C1 Sh 25.00 Sd Depth Max 5.0 Lst 9120' 10.5 C4 C5 Tuff Gas Breakdown Avg: Average Sst C3 API Filt 9.70 140 21 Colby Marks /Javian Ervin Ann Corr Cor Solids (lb/100ft2) 17,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks /Javian Ervin Ann Corr Cor Solids (lb/100ft2) 15,500 24 hr Max YP 140 C3 21 Tuff Gas Breakdown 9454 Avg: 100 Average Sst 19 C4 C5 25 Sd Depth Max 3.8 Lst 9098' 1100 517 234 C2C1 Sh 25.00 H2S Data Sample Line Avg: 12224 Chromatograph (ppm) 5.0 Silt Siltst ClystCht FXG46Ds PDC 9406'169.80 9.80 32.89 Nabors 19AC $6,336.97 AK-AM-0006852352 9.5 1.035 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 35 08/30/2011-04:00 9547' North Slope 9454 Daily Charges Avg 70.7 82 Gas (units) ml/30min Max:Ambient Air Pit Room 47 Cmt 9.92 pH Chlorides GvlCoal 10.64 Min 12.99 Avg 8.2 mg/l 12.21 AvgMin Max Max API Filt 11.00 2000 3.5530 $226,290.07 391 407 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 549' Drilling J. Polya,/ J. Cortez 176 Circ Flow In (gpm) Current Pump & Flow Data: 13.26 57.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)150 100 9557' Depth md Total Losses from Midnight to Midnight - 0 bbls to reduce torque. Drilling Ahead Total Losses from Midnight to 04:00- 0 bbls to 8840'. Tag cement. Drill cement 8840' to 9098' 700 gpm 90 rpm. Circulate two bottoms up, install RCD. Drilled 9098'-9310' 650 gpm, 125 rpm. Drilled 9406' 700 gpm, 4000psi, 140 rpm 20-23k on bottom torque, 18-20 off bottom. Fresh lube added to 6% PWD Drilling All Circ Avg Diam % 13.26 Picked up BHA. Download MWD and pulse test. Trip into hole to 8644', pulse test, Slip and cut drill line. Ream 8664' 9.50'' Max: Hole Condition On Bot Hrs 9561'7.76 176 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 869 70949 70949 161592 1468 9.50'' Max: Hole Condition On Bot Hrs 10452'21.5 Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam psi, 140 rpm. Vhange swab on pump. Drill ahead 9561-9882. At 9600 pump 80bbl 13ppg, 200 high viscosity sweep with no increase in returns. Service rig. Drull 9882'-10299'. At 10082', pump a 80bbls 13ppg, 200 viscosity sweep with no significant Drilled ahead to 9406'. Drop ball to open RHINO reamer. Ream 9396'-9400. Drill ahead 9406'-9561 700 gpm 3000 Depth md Total Losses from Midnight to Midnight - 0 bbls increase in returns. Down-time, mud pump swab. Drill ahead 10299'-10452', 740 gpm, 4200 psi 130 rpm. Continue working on mud pump. Current R.O.P. (ft/hr) Gas (units)323 900 10306' 905' Drilling J. Polya,/ J. Cortez 1671 10168' Flow In (gpm) Current Pump & Flow Data: 13.31 3.5530 $232,627.04Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 13.31 8.2 mg/l 13.03 AvgMin Max Max12.74 pH Chlorides GvlCoal 12.43 Min 13.02 Avg Cmt ml/30min 181 Max:Ambient Air Pit Room 64.0 90 Gas (units) 54 62.0 36 08/31/2011-04:00 10452' North Slope 10264 10168 Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 9.90 9.90 32.89 Nabors 19AC $6,336.97 AK-AM-0006852352 9.5 1.035 5.0 Silt Siltst ClystCht FXG46Ds PDC 9406'23 136372 Chromatograph (ppm) 2481 H2S Data Sample Line Avg: 10168 10357 10357 1671 1000 5159 2296 C2C1 Sh 25.00 Sd Depth Max 3.8 Lst 9098' 1100 GP 237 C4 C5 CG282 193 CG Tuff Gas Breakdown 10264 Avg: 700 Average Sst 2118 247 C3 1285 API Filt 10.40 140 30 5120 Colby Marks /Javian Ervin Ann Corr Cor Solids (lb/100ft2) 16,000 24 hr Max 190 YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 2225 350 106220 98852 2223 9.50'' Max: Hole Condition On Bot Hrs 11118'33.7 Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam 12.4 ppg, 220viscosity sweep with 10-15% increase in cuttings. Drill ahead 10732'-10854'. Repair mud pump. Drill ahead 10854'-11119'. Shut down to inspect pumps, gear end. Trip out of the hole to the casing shoe pumping 75 gpm. Service Repair rig pump. Drill ahead 10453'-10732', 740 gpm, 4305 psi 130 rpm, 22k torque. At 10673', pump a 80bbls Depth md Total Losses from Midnight to Midnight - 0 bbls rig pump. Trip back into hole. Current R.O.P. (ft/hr) Gas (units)25 588 10995' 666' Tripping J. Polya,/ J. Cortez 3254 11048' Flow In (gpm) Current Pump & Flow Data: 13.63 3.5530 $238,964.01Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 13.63 8.2 mg/l 13.02 AvgMin Max Max12.80 pH Chlorides GvlCoal 12.43 Min 13.00 Avg Cmt 224 GP259 ml/30min 141 Max:Ambient Air Pit Room 11048' 54.0 74 276361 Gas (units) 52 0.0 37 09/01/2011-04:00 11118' North Slope 3254 11023 10830 Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 9.90 9.90 32.89 Nabors 19AC $6,336.97 AK-AM-0006852352 9.5 1.035 11.0 Silt Siltst ClystCht FXG46Ds PDC 11118'33 588 119962 Chromatograph (ppm) 2382 H2S Data Sample Line Avg: 11048' 10830 10740 10740 1011 408 1477 5211 2021 1384 C2C1 Sh 25.00 Sd Depth Max 4.0 Lst 9098' 1100 CG 184 C4 C5 CG195 162 CG Tuff Gas Breakdown 11023 Avg: 500 Average Sst 848 137 C3 1009 API Filt 10.30 140 37 3124 Colby Marks /Javian Ervin Ann Corr Cor Solids (lb/100ft2) 16,000 24 hr Max 143 YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 9.50'' Max: Hole Condition On Bot Hrs 11430'39.9 Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam 80 bbl 12.4 ppg 200vis sweep with 30% increase . Cuttings at 11178'. Drill 11295'-11430' (TD) ,circulate and condition. Work on mud pump. Pump 80 bbks 12.4 ppg 200 viscocity sweep with 10-15% increase in cuttings. Drop ball, close RHINO reamer Pump OOH 10834'-9050', 70 gpm. Repair rig pump. TIH 9050'-11024'. Drill 11119'-11295' 740gpm, 4300 psi. Pump Depth md Total Losses from Midnight to Midnight - 0 bbls Short trip to 11049' and back to bottom, circulate and condition, pump 82 bbls 12.2 ppg 220 viscocity sweep with 25% increase in cuttings. Displace 10.0 ppf LSND and circulate mud 13.0 ppg. Remove RCD element & install trip nipple. Current R.O.P. (ft/hr) Gas (units)55 700 11262' 312' Tripping J. Polya,/ J. Cortez 3344 trip Flow In (gpm) Current Pump & Flow Data: 13.42 3.5530 $245,300.98Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 13.14 10.2 mg/l 13.00 AvgMin Max Max12.50 pH Chlorides GvlCoal 12.34 Min 13.00 Avg Cmt ml/30min Max:Ambient Air Pit Room 50.0 73 Gas (units) 75 0.0 38 09/02/2011-04:00 11430' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 10.20 10.20 32.89 Nabors 19AC $6,336.97 AK-AM-0006852352 9.5 1.035 14.0 Silt Siltst ClystCht FXG46Ds PDC 11430'28 Chromatograph (ppm) H2S Data Sample Line Avg: C2C1 Sh 25.00 Sd Depth Max 3.6 Lst 9098' 1100 C4 C5 Tuff Gas Breakdown Avg: Average Sst C3 API Filt 9.80 140 45 Colby Marks /Javian Ervin Ann Corr Cor Solids (lb/100ft2) 17,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks /Javian Ervin Ann Corr Cor Solids (lb/100ft2) 17,000 24 hr Max YP 140 C3 61 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max 3.8 Lst 9098' 1100 C2C1 Sh 25.00 H2S Data Sample Line Avg: Chromatograph (ppm) 9.0 Silt Siltst ClystCht FXG46Ds PDC 11430'4410.20 10.20 32.89 Nabors 19AC $6,336.97 AK-AM-0006852352 9.5 1.035 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 39 09/03/2011-04:00 11430' North Slope Daily Charges Avg 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 78 Cmt 12.50 pH Chlorides GvlCoal 12.34 Min 13.00 Avg 19.2 mg/l 13.00 AvgMin Max Max API Filt 9.20 3.5530 $251,637.95Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Tripping J. Polya,/ J. Cortez 0 trip Flow In (gpm) Current Pump & Flow Data: 13.42 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 0 0' Depth md Total Losses from Midnight to Midnight - 0 bbls surface, lay down BHA. Testing BOP. Blend exess surface volume from 13.0 ppg to 10.2 ppg. Ins5all 7" rams in lower ram cavity and test same. Rig up tesco and 7" handling equipment. Swap out the split bushings. Run in hole with 7" drilling liner. Total Losses from Midnight to 04:00- 0 bbls from 10.2 ppg to 13.0 ppg. Monitor well, static. Pull RCD and install trip nipple. Trip out of the hole, pumping out 11430'-9025' 2-3 bbls per stand. Tight at 10660' and 10485'-10340'. Hole talking proper amount. Pump dry job and pull out of the hole to PWD Drilling All Circ Avg Diam % 13.14 Circulate and condition reciprocating 11430'-11335, prepare for displacement to 13ppg kill weight. Displace well 9.50'' Max: Hole Condition On Bot Hrs 11430'0 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks /Javian Ervin Ann Corr Cor Solids (lb/100ft2) 17,000 24 hr Max YP 140 C3 42 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max 4.8 Lst 9098' 1100 C2C1 Sh 25.00 H2S Data Sample Line Avg: Chromatograph (ppm) 6.0 Silt Siltst ClystCht FXG46Ds PDC 11430'2910.20 10.20 32.89 Nabors 19AC $4,865.75 AK-AM-0006852352 9.5 1.035 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 40 09/04/2011-04:00 11430' North Slope Daily Charges Avg 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 75 Cmt pH Chlorides GvlCoal Min Avg 10.1 mg/l AvgMin Max Max API Filt 9.50 3.5530 $256,503.70Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Run Casing and Cementing J. Polya,/ J. Cortez 150 trip Flow In (gpm) Current Pump & Flow Data: 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 40 0' Depth md Total Losses from Midnight to Midnight - 0 bbls Total Losses from Midnight to 04:00- 0 bbls into hole on drill pipe to 11430' filling every 20 stands. Circulate and condition at 40 gpm. Pump 50 bbl 13.0 ppg 300 vis spacer and chase with 10.2 ppg LSND. Position top of liner at 8949' and drop liner setting ball. PWD Drilling All Circ Avg Diam % Run 7" liner to 2444'. Make up 7' X 9 5/8' hanger/packer. Circulate liner volume, 95bbls at 3 bpm, 100 psi. Run liner 9.50'' Max: Hole Condition On Bot Hrs 11430'0 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 9.50'' Max: Hole Condition On Bot Hrs 11430'0 Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam with 45 bbl spacer and 33 bbls 15.8 ppg cement. Sheared out and tested liner packer to 3500 psi. Circulated bottoms up at 14 bpm. Rig down cement equipment and pull out of the hole to surface. Currently out of hole at time of report. Circulate liner hanger ball and set hanger top at 8949'. Continue to circulate well to 10.2 LSND. Cemented casing liner Depth md Total Losses from Midnight to Midnight - 0 bbls Current R.O.P. (ft/hr) Gas (units)0 17 0' 0' Run Casing and Cementing J. Polya,/ J. Cortez 39 trip Flow In (gpm) Current Pump & Flow Data: 3.5530 $261,369.45Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 10.1 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Cmt ml/30min Max:Ambient Air Pit Room 0.0 0 Gas (units) 76 0.0 41 09/05/2011-04:00 11430' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 10.20 10.20 32.89 Nabors 19AC $4,865.75 AK-AM-0006852352 9.5 1.035 8.0 Silt Siltst ClystCht FXG46Ds PDC 11430'31 Chromatograph (ppm) H2S Data Sample Line Avg: C2C1 Sh 25.00 Sd Depth Max 4.8 Lst 9098' 1100 C4 C5 Tuff Gas Breakdown Avg: Average Sst C3 API Filt 9.50 140 38 Colby Marks /Javian Ervin Ann Corr Cor Solids (lb/100ft2) 17,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 9.50'' Max: Hole Condition On Bot Hrs 11430'0 Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam with mule shoe to 3527'. Slip and cut drilling line. Lay down drill pipe. Pull wear ring and rig up tesco equipment . Service rig. Run 7" casing at time of report. Lay down drill pipe 4940'-562', lay down BHA. Remove wear bushing and test bop. Install wear bushing. Trip into hole Depth md Total Losses from Midnight to Midnight - 0 bbls Current R.O.P. (ft/hr) Gas (units)0 0 0' 0' Run Casing and Cementing R. Keipzig,/ J. Habethur 0 trip Flow In (gpm) Current Pump & Flow Data: 3.5530 $266,235.20Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 10.1 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Cmt ml/30min Max:Ambient Air Pit Room 0.0 0 Gas (units) 76 0.0 42 09/06/2011-04:00 11430' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 10.20 10.20 32.89 Nabors 19AC $4,865.75 AK-AM-0006852352 9.5 1.035 8.0 Silt Siltst ClystCht FXG46Ds PDC 11430'33 Chromatograph (ppm) H2S Data Sample Line Avg: C2C1 Sh 25.00 Sd Depth Max 5.0 Lst 9098' 1100 C4 C5 Tuff Gas Breakdown Avg: Average Sst C3 API Filt 9.20 140 33 Colby Marks /Javian Ervin Ann Corr Cor Solids (lb/100ft2) 17,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 9.50'' Max: Hole Condition On Bot Hrs 11430'0 Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam 135bbls diesel into 7"X 9 5/8" annulus. Pressured test casing. Casing slips did not set. Service rig. Pressured test casing and rig down tesco. Installed test plug, an performed BOP test. Tripping into hole 4" Drill pipe. Currently tripping into hole. Run 7" casing to 8949". Sting into seal assembly. Circulated and test 9 5/8" X 11 3/4" annulus to 3500 psi. Circulated Depth md Total Losses from Midnight to Midnight - 0 bbls Current R.O.P. (ft/hr) Gas (units)0 0 0' 0' Tripping R. Keipzig,/ J. Habethur 0 trip Flow In (gpm) Current Pump & Flow Data: 3.5530 $271,100.95Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 10.1 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Cmt ml/30min Max:Ambient Air Pit Room 0.0 0 Gas (units) 73 0.0 43 09/07/2011-04:00 11430' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 10.20 10.20 32.89 Nabors 19AC $4,865.75 AK-AM-0006852352 9.5 1.035 8.0 Silt Siltst ClystCht FXG46Ds PDC 11430'30 Chromatograph (ppm) H2S Data Sample Line Avg: C2C1 Sh 25.00 Sd Depth Max 3.6 Lst 9098' 1100 C4 C5 Tuff Gas Breakdown Avg: Average Sst C3 API Filt 9.00 140 38 Colby Marks /Javian Ervin Ann Corr Cor Solids (lb/100ft2) 17,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks /Javian Ervin Ann Corr Cor Solids (lb/100ft2) 16,500 24 hr Max YP C3 18 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max 6.8 Lst 1300 C2C1 Sh H2S Data Sample Line Avg: Chromatograph (ppm) 6.0 Silt Siltst ClystCht FXG46Ds PDC 11454'1210.30 10.30 Nabors 19AC $6,336.97 AK-AM-0006852352 0 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 44 09/09/2011-04:00 11454' North Slope Daily Charges Avg 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 46 Cmt pH Chlorides GvlCoal Min Avg 10.2 mg/l AvgMin Max Max API Filt 11.90 3.5530 $283,774.89Total Charges: Flow In (spm) SPP (psi) Gallons/stroke tripping in hole R. Keipzig,/ J. Habethur 0 11454' Flow In (gpm) Current Pump & Flow Data: 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 0 0' Depth md Total Losses from Midnight to Midnight - 0 bbls tripping into the hole at the time of report. Total Losses from Midnight to 04:00- 0 bbls Drill cement to 11430". Circulate and condition bottoms up, with 10.2 ppg EMW. Tripped out hole. Madd Pass 350 'hr from 11428' to 10400', and 9400' to 9203'. Trip out hole an lay down BHA. Repair hydrylic leak on BOP stack. Pick up Bha # 14, and currently PWD Drilling All Circ Avg Diam % Trip into hole at 11137". Drill log cement an shoe track to 11416". Circulate and condition 10.2 ppg surface to surface. Max: Hole Condition On Bot Hrs 11454'0 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 6.13'' Max: Hole Condition On Bot Hrs 11653'15.5 Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam Displace 10.2 ppg LSND to 8.6 ppg, Quick drilling fluid. Drill to 11555', Perform pore pressure PSI test , with MPD. Record 9.21 ppg EMW pore psi. Rotary drill ahead to 1161'. Currently drilling ahead at time of report. Run into hole to 11400'. Slip and cut drill line. Install MPD RCD bearing. Pump 50bbls10.2 ppg high viscosity spacer. Depth md Total Losses from Midnight to Midnight - 0 bbls Current R.O.P. (ft/hr) Gas (units)20 50 11554' 199' Drilling Ahead R. Keipzig,/ J. Habethur 695 Flow In (gpm) Current Pump & Flow Data: 12.60 1269 3.5530 $290,111.86 183 183 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 10.38 0.4 mg/l 9.99 AvgMin Max Max9.81 pH Chlorides GvlCoal 9.74 Min 10.12 Avg Cmt ml/30min Max:Ambient Air Pit Room 1.1 75 Gas (units) 49 1.4 46 09/010/2011-04:00 11653' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 8.50 8.50 Nabors 19AC $6,336.97 AK-AM-0006852352 0 0.5 Silt Siltst ClystCht FXG46Ds PDC 11650'6 40 Chromatograph (ppm) H2S Data Sample Line Avg: C2C1 ShSd Depth Max 5.8 Lst 11454' 1300 40 C4 C5 Tuff Gas Breakdown Avg: 20 Average Sst C3 API Filt 9.5023 Colby Marks /Javian Ervin Ann Corr Cor Solids (lb/100ft2) 17,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 33556 385 6.13'' Max: Hole Condition On Bot Hrs 11790'15.5 Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam Time drilling an rotary drilling from 11650' to 11727'. Continued drilling siderite stringers. Currently drilling ahead. Depth md Total Losses from Midnight to Midnight - 0 bbls Current R.O.P. (ft/hr) Gas (units)82 50 11755' 137' Drilling Ahead R. Keipzig,/ J. Habethur 389 11770' Flow In (gpm) Current Pump & Flow Data: 10.34 1304 3.5530 $296,448.83 181 183 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 10.08 1.0 mg/l 9.85 AvgMin Max Max9.39 pH Chlorides GvlCoal 9.39 Min 9.86 Avg Cmt ml/30min Max:Ambient Air Pit Room 3.3 76 Gas (units) 47 1.1 47 09/11/2011-04:00 11790' North Slope 11702 11770 Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 8.50 8.50 Nabors 19AC $6,336.97 AK-AM-0006852352 0 2.5 Silt Siltst ClystCht FXG46Ds PDC 11725'7 60 15 32390 Chromatograph (ppm) H2S Data Sample Line Avg: 11770 389 200 2071 1018 C2C1 ShSd Depth Max 5.8 Lst 11454' 1300 25 130 C4 C5 CG156 181 CG Tuff Gas Breakdown 11702 Avg: 250 Average Sst 1315 202 C3 API Filt 8.9021 1778 David Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 13,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirDavid Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 15,000 24 hr Max YP C3 23 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max 5.2 Lst 11454' 1300 10 C2C1 Sh H2S Data Sample Line Avg: 75 Chromatograph (ppm) 2.5 Silt Siltst ClystCht 15 FXG46Ds PDC 11919'98.50 8.50 Nabors 19AC $6,336.97 AK-AM-0006852352 0 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 48 09/11/2011-04:00 11919' North Slope Daily Charges Avg 7.8 78 Gas (units) ml/30min Max:Ambient Air Pit Room 52 Cmt 7.83 pH Chlorides GvlCoal 7.83 Min 10.06 Avg 0.7 mg/l 9.95 AvgMin Max Max API Filt 9.50 3.5530 $302,785.80Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 129' Circulate and condition R. Keipzig,/ J. Habethur 114 11909' Flow In (gpm) Current Pump & Flow Data: 12.12 Max @ ft Current R.O.P. (ft/hr) Gas (units)29 40 11915' Depth md Total Losses from Midnight to Midnight - 0 bbls After Attempt to circulate, ECD increased. Circulating and conditioning the hole and trouble shooting gas chromatograph at time of report. Total Losses from Midnight to 04:00- 0 bbls Drilling to 11919'. ECD increasing 10.2 ppg to 12.0 ppg. Circulate and condition fluid. Bottoms up, flocculated an oil contaminated mud dumping over shakers. Flow out lubes at 7%. Shakers were cleaned, and continued run into hole. PWD Drilling All Circ Avg Diam % 10.99 Time drilling and rotary drilling to 11854'. Troubleshoot GeoPilot , unable to downlink. Switch GeoSpan modes. 6.13'' Max: Hole Condition On Bot Hrs 11790'35 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 6.13'' Max: Hole Condition On Bot Hrs 11935'64 Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam Circulated bottoms up. Hole unloading oil contaminated an flocculated mud. Attempt to treat mud to surface system with no positive results. Dump and diluted 100% of the active system. Circulated new 8.5 ppg Quick Dril N surface to surface. Stage pump Trip out the hole to 11400'. Stand pipe pressure increasing. Adjusted drilling parameters in attempt to lower psi. Depth md Total Losses from Midnight to Midnight - 0 bbls rate to 250 gpm. Confirm no losses to hole. Trip back to bottom holding 11.0 ppg EMW with MPD. Minor pack off at 11900' Circulated bottoms up two times at 11919'. Trip back into hole at 11796'. Perform pore psi test with MPD. Read 10.1 ppg EMW. Ream and wash to bottom holding 11.1 ppg EMW. Orient Geo Piolot. Currently drilling at report time. Current R.O.P. (ft/hr) Gas (units)35 14 11915' 32' Circulate and condition R. Keipzig,/ J. Habethur 1700 Circ Flow In (gpm) Current Pump & Flow Data: 11.30 1650 3.5530 $309,122.77 180 180 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 11.22 0.7 mg/l 11.09 AvgMin Max Max10.93 pH Chlorides GvlCoal 10.30 Min 11.07 Avg Cmt ml/30min Max:Ambient Air Pit Room 1.3 11923 Gas (units) 52 28.0 49 09/13/2011-04:00 11951' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 8.50 8.50 Nabors 19AC $6,336.97 AK-AM-0006852352 0 1.0 Silt Siltst ClystCht FXG46Ds PDC 11935'8 75 15 Chromatograph (ppm) H2S Data Sample Line Avg: C2C1 ShSd Depth Max 5.8 Lst 11454' 1300 10 C4 C5 Tuff Gas Breakdown Avg: Average Sst C3 API Filt 9.5025 David Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 14,500 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirDavid Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 15,000 24 hr Max 493 YP 3434 1703 C3 2381 23 Tuff Gas Breakdown 12345 Avg: 1100 Average Sst FG 525 C4 C5 FG1571 479 FG Sd Depth Max 5.6 Lst 11454' 1300 5 4063 2662 C2C1 Sh 2142 6866 CG 634 1106 78516 5106 CG1774 718 3541 12409 12497 12497 1120 1115 H2S Data Sample Line Avg: 95 992 67839 Chromatograph (ppm) 4403 5034 3125 3.5 Silt Siltst ClystCht FXG46Ds PDC 12832'78.50 8.60 Nabors 19AC $6,336.97 AK-AM-0006852352 0 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 50 09/14/2011-04:00 13056' North Slope 1121 12345 12409 Daily Charges Avg 61.0 81 67565 12903'12903' 1561 12847' 12943'112056 1111 1542 3116 Gas (units) ml/30min 1366 Max:Ambient Air Pit Room 48 Cmt 4477 619 CG1661 10.84 pH Chlorides GvlCoal 10.46 Min 11.21 Avg 0.6 mg/l 11.22 AvgMin Max Max API Filt 9.60 2039 3.5530 $315,409.74 218 218 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 1105' Circulate and condition R. Keipzig,/ J. Habethur 1561 12943' Flow In (gpm) Current Pump & Flow Data: 11.51 85.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)703 698 13045' Depth md Total Losses from Midnight to Midnight - 0 bbls Total Losses from Midnight to 04:00- 0 bbls 8.5 ppg in an 8.65 ppg out. Pumped a 20 bbls sweep at 12,500' with no increase in cuttings at the shakers. Pumped another 20 bbl sweep at 12,800' with no increase in volume. Drilling ahead at report time. PWD Drilling All Circ Avg Diam % 11.40 Rotary drilling and time drilling from 11935 to 12883". Holding 11.0-11.1 ppg EMW, with MPD @ shoe. Mud weight 25 bbls 6.39'' Max: Hole Condition On Bot Hrs 12832'64 12943' 12847' 1069 1022 44129 78278 1131 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirDavid Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 16,000 24 hr Max 698 YP 5736 821 C3 5911 17 Tuff Gas Breakdown 13296 Avg: 2504 Average Sst F 916 C4 C5 F2814 712 CG Sd Depth Max 5.6 Lst 11454' 1300 5 10204 6284 C2C1 Sh 13906 13933 13933 2605 2603 198686 2471 H2S Data Sample Line Avg: 95 195225 Chromatograph (ppm) 8661 9812 10476 1.5 Silt Siltst ClystCht FXG46Ds PDC 13939'78.50 8.60 Nabors 19AC $6,336.97 AK-AM-0006852352 0 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 51 09/15/2011-04:00 14130' North Slope 13296 13906 Daily Charges Avg 30.0 109 Gas (units) ml/30min 1923 4773 2379 Max:Ambient Air Pit Room 43 Cmt F 11.26 572 pH Chlorides GvlCoal 11.20 Min 11.49 Avg 0.3 mg/l 11.49 AvgMin Max Max API Filt 9.40 2120 3.5530 $321,796.71 218 218 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 1074' Circulate and condition R. Keipzig,/ J. Habethur 2934 13933' Flow In (gpm) Current Pump & Flow Data: 11.74 50.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)382 350 14104' Depth md Total Losses from Midnight to Midnight - 0 bbls Total Losses from Midnight to 04:00- 0 bbls and 8.6 ppg out. Steady fine oily sands returning on shakers while drilling. Pumping 20bbl High Viscosity 8.5 ppg sweeps every 300". Minimal increase with returns on sweeps. Currently drilling ahead at report time. PWD Drilling All Circ Avg Diam % 11.40 Rotary drilling and time drilling from 12863 to 13949. Holding 11.3 ppg EMW with MPD at shoe. Mud weight 8.5 ppg in 25 bbls 6.39'' Max: Hole Condition On Bot Hrs 12939'64 1394913949 1456 2934 2634 227165 200767 2506 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 6.39'' Max: Hole Condition On Bot Hrs 14513'109 Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam shoot. Unable to regain signal. TD called. Circulated 4x Bottoms up. Pump 40 bbl Hi vis sweep. Minimal change in returns at shakers. Trip out hole to inside casing shoe at 11356'. Circulate and condition drilling fluid. Trip back to bottom, Circulate and Rotary drilling an time drilling to 14513'. Holding 11.3 ppg EMW with MPD at shoe. Lost signal to GeoPilot. Trouble Depth md Total Losses from Midnight to Midnight - 0 bbls Condition. Current R.O.P. (ft/hr) Gas (units)50 300 14468' 383' Circulate and condition R. Keipzig,/ J. Habethur 558 14453' Flow In (gpm) Current Pump & Flow Data: 11.92 2220 3.5530 $328,133.68 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 11.92 0.6 mg/l 11.59 AvgMin Max Max11.19 pH Chlorides GvlCoal 11.19 Min 11.53 Avg Cmt ml/30min Max:Ambient Air Pit Room 8.5 54 Gas (units) 43 33.0 52 09/16/2011-04:00 14513' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 25 bbls 8.50 8.60 Nabors 19AC $6,336.97 AK-AM-0006852352 0 1.5 Silt Siltst ClystCht FXG46Ds PDC 14513'6 90 5 Chromatograph (ppm) H2S Data Sample Line Avg: C2C1 ShSd Depth Max 5.8 Lst 11454' 1300 5 C4 C5 Tuff Gas Breakdown Avg: Average Sst C3 API Filt 9.3022 David Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 17,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 6.39'' Max: Hole Condition On Bot Hrs 14513'109 Total Losses from Midnight to 04:00- 21 bbls PWD Drilling All Circ Avg Diam PSI test to 10.73 ppg EMW. Pump 50bbls High vis 8.6 ppg sweep. Displace open hole with new quick drill in with 5% NXS lube. Trip out hole to 11949'. Circulate and condition fluid. Continued tripping out of hole to 11400', while mixing Brine at RSC. Trip back Circulate and condition drilling fluid inside casing shoe. Trip into hole to 14513'. Circulate bottoms up. Perform Pore Depth md Total Losses from Midnight to Midnight - 0 bbls in to hole to sump, 11949'. Lay out 11.2 ppg High vis spacer 11949' to 11400'. Displace 8.6 ppg Quick Drill into 11.2 ppg NaCL/ NaBr vis brine. Observe weill static 15 minutes. Pull MPD RCD bearing. Pump Out Of Hole to 10000. Continue Pulling out hole at report time. Current R.O.P. (ft/hr) Gas (units) Tripping Out Hole J. Polya/J. Cortez Flow In (gpm) Current Pump & Flow Data: 3.5530 $334,470.65Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % -8.1 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Cmt ml/30min Max:Ambient Air Pit Room Gas (units) 42 53 09/17/2011-04:00 14513' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 25 bbls 11.20 11.20 Nabors 19AC $6,336.97 AK-AM-0006852352 0 Silt Siltst ClystCht FXG46Ds PDC 14513'9 Chromatograph (ppm) H2S Data Sample Line Avg: C2C1 ShSd Depth Max Lst 11454' 1300 C4 C5 Tuff Gas Breakdown Avg: Average Sst C3 API Filt 22 David Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 172,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirDavid Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 172,000 24 hr Max YP C3 22 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max Lst 11454' 1300 C2C1 Sh H2S Data Sample Line Avg: Chromatograph (ppm) Silt Siltst ClystCht FXG46Ds PDC 14513'911.20 11.20 Nabors 19AC $6,336.97 AK-AM-0006852352 0 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 54 09/18/2011-04:00 14513' North Slope Daily Charges Avg 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 42 Cmt pH Chlorides GvlCoal Min Avg -8.1 mg/l AvgMin Max Max API Filt 3.5530 $340,439.81Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Tripping Out Hole J. Polya/J. Cortez 0 0' Flow In (gpm) Current Pump & Flow Data: 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 0 0' Depth md Total Losses from Midnight to Midnight - 24bbls Total Losses from Midnight to 04:00- 0 bbls HWDP. Rig up to run 4.5' slotted linger. Make up liner per weatherford rep. Trip into hole with 77 joints of liner. Trip in hole with liner on 4" DP to 6350. PWD Drilling All Circ Avg Diam % Trip out hole to 420'. Monitor hole . Static condition. Lay down BHA. Download MWD. Pick up and flush additional 4" 25 bbls 6.39'' Max: Hole Condition On Bot Hrs 14513'109 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 6.39'' Max: Hole Condition On Bot Hrs 14513' Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam phenolic ball. No seat. Drop 1.75" aluminum ball. No seat. Jar string. No seat. Attempt emergency seat. Apply left hand turn to 4.5k torque x 3. No release. Try manual release with out positive results. Pump 20bbl high vis sweep to attempt assist ball seat. No seat. Trip into hole with liner on 4" DP to 14513'. Tagged bottom. Picked up to 14511'. Circulate and condition, pump 1.75" Depth md Total Losses from Midnight to Midnight - 0bbls Pump wiper ball to assist seat. PSI increase. Hanger set. Attempt release set tool. Liner moving. Work pipe. Tool released. Completed packer set per weatherford rep. Psi test shoe. Unable to hold 3500 psi. Bleed off. Circulated 2x bottoms up. Pulled out hole laying down 4" drillpipe at time of report. Current R.O.P. (ft/hr) Gas (units)0 5 0' Tripping Out Hole J. Polya/J. Cortez 53 Circ Flow In (gpm) Current Pump & Flow Data: 3.5530 $346,539.77Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % -8.3 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Cmt ml/30min Max:Ambient Air Pit Room 0.0 0 Gas (units) 42 0.0 55 09/19/2011-04:00 14513' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 25 bbls 11.15 11.15 Nabors 19AC $4,130.13 AK-AM-0006852352 Silt Siltst ClystCht N/A 14513'9 Chromatograph (ppm) H2S Data Sample Line Avg: C2C1 ShSd Depth Max Lst 1340 C4 C5 Tuff Gas Breakdown Avg: Average Sst C3 API Filt 23 David Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 171,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirDavid Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 172,000 24 hr Max YP C3 23 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max Lst 1340 C2C1 Sh H2S Data Sample Line Avg: Chromatograph (ppm) Silt Siltst ClystCht N/A 14513'1011.10 11.10 Nabors 19AC $4,130.13 AK-AM-0006852352 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 56 09/20/2011-04:00 14513' North Slope Daily Charges Avg 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 43 Cmt pH Chlorides GvlCoal Min Avg -8.1 mg/l AvgMin Max Max API Filt 3.5530 $350,669.90Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Tripping Out Hole J. Polya/J. Cortez 53 Circ Flow In (gpm) Current Pump & Flow Data: 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 5 0' Depth md Total Losses from Midnight to Midnight - 7 bbls up. Slight crude oil returns on bottom shaker screens during circulate. Cut an slip drill line. Currently pulling out of hole. Total Losses from Midnight to 04:00- 0 bbls into hole with Baker fishing Bha with bailer on 4" drill pipe to 11270'. Trip in hole to 11412'. Function hydro bailer. Stack 10,000 to open fill 2bbls. Repeat procedure 3x. Fill pipe. Circulate 2 bottoms up, No change in Mud weight in Mud weight out on 2x bottoms PWD Drilling All Circ Avg Diam % Pull out hole to BHA, Laying down 4" pipe. Monitor well 10 minutes, Static. Lay down weatherford BHA. Test BOP's. Trip 25 bbls 6.39'' Max: Hole Condition On Bot Hrs 14513' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirDavid Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 170,000 24 hr Max YP C3 20 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max Lst 1340 C2C1 Sh H2S Data Sample Line Avg: Chromatograph (ppm) Silt Siltst ClystCht N/A 14513'1011.10 11.10 Nabors 19AC $4,130.13 AK-AM-0006852352 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 57 09/21/2011-04:00 14513' North Slope Daily Charges Avg 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 42 Cmt pH Chlorides GvlCoal Min Avg -7.5 mg/l AvgMin Max Max API Filt 3.5530 $354,800.03Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Tripping Out Hole J. Polya/J. Cortez 0 Circ Flow In (gpm) Current Pump & Flow Data: 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 0 0' Depth md Total Losses from Midnight to Midnight - 8 bbls Total Losses from Midnight to 04:00- 0 bbls pull out of hole, laying down 4" drill pipe to hydro bailer BHA. Secure sheave in derrick due to high winds. Lay down bailer. No debris recovered. Rigged up ESP cable and currently running in the hole with ESP pump at time of report. PWD Drilling All Circ Avg Diam % Monitor well. Static. Cut an slip drill line. Pull out of hole laying down 4" drill pipe. Hang ESP cable sheave. Continue to 25 bbls 6.39'' Max: Hole Condition On Bot Hrs 14513' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirDavid Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 170,000 24 hr Max YP C3 23 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max Lst 1340 C2C1 Sh H2S Data Sample Line Avg: Chromatograph (ppm) Silt Siltst ClystCht N/A 14513'911.10 11.10 Nabors 19AC $4,130.13 AK-AM-0006852352 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 58 09/22/2011-04:00 14513' North Slope Daily Charges Avg 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 41 Cmt pH Chlorides GvlCoal Min Avg -8.0 mg/l AvgMin Max Max API Filt 3.5530 $358,930.16Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Tripping In Hole J. Polya/J. Cortez 0 Circ Flow In (gpm) Current Pump & Flow Data: 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 0 0' Depth md Total Losses from Midnight to Midnight - 0 bbls Total Losses from Midnight to 04:00- 0 bbls ESP to 902', stack out. Test ESP, cable shorted out. Trip out of the hole too 613', pull on Top drive to free 30,000 over. Pull out of the hole to surface., broken stabilizer above ESP and 20' of wire missing. Currently running into hole at report time. PWD Drilling All Circ Avg Diam % Pull ESP cable to rig floor and secure same. Splice ESP cable to motor. Make up pump assembly. Run into hole with 25 bbls 6.39'' Max: Hole Condition On Bot Hrs 14513' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 6.39'' Max: Hole Condition On Bot Hrs 14513' Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam scraper magnet and trip into hole to 1480', pump 120 bbls at 250 gpm. Trip into hole to 2735'. Trip out of hole recovered bolt head and metal shards. Rig up slick line and run into hole with magnet and brush to 4000'. Pull out hole, nothing recovered. Make up Lay down ESP, retrieve 20' of wire. Load pipe in pipe shed. Rig down tubing equipment. Service top drive. Make up Depth md Total Losses from Midnight to Midnight - 0 bbls gauge ring and junk basket and run into hole to 8973'. Pull out of hole with out fish. Rig down slick line. Currently running into hole with 4" drill pipe for a clean out run. Current R.O.P. (ft/hr) Gas (units)0 0 0' Tripping In Hole J. Polya/J. Cortez 0 Circ Flow In (gpm) Current Pump & Flow Data: 3.5530 $363,060.29Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % -8.0 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Cmt ml/30min Max:Ambient Air Pit Room 0.0 0 Gas (units) 41 0.0 59 09/23/2011-04:00 14513' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 25 bbls 11.10 11.10 Nabors 19AC $4,130.13 AK-AM-0006852352 Silt Siltst ClystCht N/A 14513'10 Chromatograph (ppm) H2S Data Sample Line Avg: C2C1 ShSd Depth Max Lst 1340 C4 C5 Tuff Gas Breakdown Avg: Average Sst C3 API Filt 20 David Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 170,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirDavid Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 170,000 24 hr Max YP C3 23 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max Lst 1340 C2C1 Sh H2S Data Sample Line Avg: Chromatograph (ppm) Silt Siltst ClystCht N/A 14513'911.10 11.10 Nabors 19AC $4,130.13 AK-AM-0006852352 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 60 09/24/2011-04:00 14513' North Slope Daily Charges Avg 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 44 Cmt pH Chlorides GvlCoal Min Avg -8.0 mg/l AvgMin Max Max API Filt 3.5530 $367,190.42Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Tripping In J. Polya/J. Cortez 0 Circ Flow In (gpm) Current Pump & Flow Data: 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 0 0' Depth md Total Losses from Midnight to Midnight - 0 bbls Pump 13bbls, and shut dwon to allow diesel to migrate up. Confirm returns at 11.1 ppg. Rig up to pump down outer annulus taking returns from inner annulus. Running into hole to set packer at time of report. Total Losses from Midnight to 04:00- 0 bbls casing. OA pressuring up. IA and OA are in communication. Rig up to circulate freeze protect diesel out of annulus to flow back tank Pump down IA, out OA, displace with viscosifed 11.1 brine at 2.5 gpm. Pump 60bbls and shut down to allow diesel to migrate up. PWD Drilling All Circ Avg Diam % Make up magnet scraper and mule shoe and run in hole picking up 4" drill pipe to 10174'. Set packer. Pressure test 25 bbls 6.39'' Max: Hole Condition On Bot Hrs 14513' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 6.39'' Max: Hole Condition On Bot Hrs 14513' Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam hole to 10190'. Trip into the hole on 4" drill pipe 10190'-11148'. Set packer. Trip out of hole to surface. Change rams and test. Pull 7" pack off and pull 7" casing laying down 20 joints. Service rig. Wait on orders. Test BOPE. Trip into hole to retrieve packer, and Circulate out freeze protect at 1 bpm and ensure. 11.1 ppg. Trip out of hole. Pick up storm, valve and twin and trip into Depth md Total Losses from Midnight to Midnight - 0 bbls storm valve. Service top drive. Currently pulling out of at report time. Current R.O.P. (ft/hr) Gas (units)0 0 0' Tripping In J. Polya/J. Cortez 0 Circ Flow In (gpm) Current Pump & Flow Data: 3.5530 $371,320.55Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % -8.0 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Cmt ml/30min Max:Ambient Air Pit Room 0.0 0 Gas (units) 43 0.0 61 09/25/2011-04:00 14513' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 25 bbls 11.10 11.10 Nabors 19AC $4,130.13 AK-AM-0006852352 Silt Siltst ClystCht N/A 14513'10 Chromatograph (ppm) H2S Data Sample Line Avg: C2C1 ShSd Depth Max Lst 1340 C4 C5 Tuff Gas Breakdown Avg: Average Sst C3 API Filt 7.4023 David Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 170,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 6.39'' Max: Hole Condition On Bot Hrs 14513' Total Losses from Midnight to 04:00- 0 bbls PWD Drilling All Circ Avg Diam with returns. Monitor well, static. Service the rig. Trip out of the hole to surface. Lay down BHA with magnet and scraper, no significant metal on magnet. Service rig and wwait on 3rd party tools. Pick up BHA and Run in hole to 9160'. Drop 1/2" ball, pump Trip into holemaking up retrieval tool. Tag up on fish at 2993'. Turn pipe 14x to the right and pull to 2992', pump 1bbl Depth md Total Losses from Midnight to Midnight - 0 bbls 3 bpm. Currently pulling out of hole at report time. Current R.O.P. (ft/hr) Gas (units)0 0 0' Tripping In J. Polya/J. Cortez 0 Circ Flow In (gpm) Current Pump & Flow Data: 3.5530 $375,450.68Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % -8.0 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Cmt ml/30min Max:Ambient Air Pit Room 0.0 0 Gas (units) 43 0.0 61 09/26/2011-04:00 14513' North Slope Daily Charges Avg (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk Max @ ft 25 bbls 11.10 11.10 Nabors 19AC $4,130.13 AK-AM-0006852352 Silt Siltst ClystCht N/A 14513'10 Chromatograph (ppm) H2S Data Sample Line Avg: C2C1 ShSd Depth Max Lst 1340 C4 C5 Tuff Gas Breakdown Avg: Average Sst C3 API Filt 7.4023 David Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 170,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirDavid Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 170,000 24 hr Max YP C3 19 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max Lst 1340 C2C1 Sh H2S Data Sample Line Avg: Chromatograph (ppm) Silt Siltst ClystCht N/A 14513'1111.10 11.10 Nabors 19AC $4,130.13 AK-AM-0006852352 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 63 09/27/2011-04:00 14513' North Slope Daily Charges Avg 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 42 Cmt pH Chlorides GvlCoal Min Avg -8.0 mg/l AvgMin Max Max API Filt 7.10 3.5530 $379,580.81Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Tripping In J. Polya/J.Habethur 0 Circ Flow In (gpm) Current Pump & Flow Data: 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 0 0' Depth md Total Losses from Midnight to Midnight - 0 bbls packer retrieval tool and Trip into hole, taking weight at 900'. Trip out of hole and inspect BHA, good. Trip in hole to 1616' and stack out, damage/change out saver-sub. Continue to Trip into hole to 9130'. Set packer and test, good. Trip out of hole. Currently tripping in hole at time of report. Total Losses from Midnight to 04:00- 0 bbls taking weight. Ball did not seat. Drop 1 1/4" Teflon ball, pump 914 strokes., shear not observed. Pull out of hole 9160'-9133' and test packer, bleed off, test failed. Run in hole and tagged plug at 9160', re-test. Trip out of hole to surface. Test BOPE. Pick up Baker PWD Drilling All Circ Avg Diam % Circulate at 9160, pump 2nd aluminum ball 3 bpm, 250 psi. Attempt rotate, recip, pump surge at 406 bbls. Slack off, 25 bbls 6.39'' Max: Hole Condition On Bot Hrs 14513' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirDavid Mckechnie/Javian Ervin Ann Corr Cor Solids (lb/100ft2) 17,000 24 hr Max YP C3 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max Lst 1340 C2C1 Sh H2S Data Sample Line Avg: Chromatograph (ppm) Silt Siltst ClystCht N/A 14513'8.60 8.60 Nabors 19AC $5,035.50 AK-AM-0006852352 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 64 09/28/2011-04:00 14513' North Slope Daily Charges Avg 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room Cmt pH Chlorides GvlCoal Min Avg -0.8 mg/l AvgMin Max Max API Filt 3.5530 $385,521.68Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Tripping Out J. Polya/J.Habethur 67 Circ Flow In (gpm) Current Pump & Flow Data: 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 0 0' Depth md Total Losses from Midnight to Midnight - 0 bbls tag sand, no go. Work pipe 9115'-9125'. Sand not on bottom. Displace well with straight seawater, monitor well and dump 16 sacks of sand down drill pipe. Circulate 5 bpm. Currently pulling out of hole at time of report. Total Losses from Midnight to 04:00- 0 bbls new packer, to 9178'. Set packer at 9180' and test to 1000 psi, good. Reverse circulate 405 bbls9.0 viscosified seawater. Monitor well, static. Pump 20 bbls 11.1 ppg brine and 2850 lbs of sand in drill pipe. Waited on sand to fall. Trip into hole to 9110'. Attempt to PWD Drilling All Circ Avg Diam % Trip out of hole to surface, monitor well, static. Lay down BHA. Make up G-model bridge plug and trip into hole, with 25 bbls 6.39'' Max: Hole Condition On Bot Hrs 14513' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: 7" Logging Engineer:*10000 units = 100% Gas In AirDavid Mckechnie/Javian Ervin/Degi Olofinboba Ann Corr Cor Solids (lb/100ft2) 17,000 24 hr Max YP C3 22 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max Lst 1340 C2C1 Sh H2S Data Sample Line Avg: Chromatograph (ppm) Silt Siltst ClystCht N/A 14513'78.60 8.60 Nabors 19AC $5,035.50 AK-AM-0006852352 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 65 09/29/2011-04:00 14513' North Slope Daily Charges Avg 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 41 Cmt pH Chlorides GvlCoal Min Avg 2.5 mg/l AvgMin Max Max API Filt 7.50 3.5530 $390,557.18Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Rig Service J. Polya/J.Habethur 88 Circ Flow In (gpm) Current Pump & Flow Data: 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 0 0' Depth md Total Losses from Midnight to Midnight - 0 bbls Engage fish and pull free with 215k. Line up on gas buster and displace 10.2 ppg LSND from inactive annulus behind 7" casing. Pull casing from 8962" to 8072'. Release spear. Service top drive. Still servicing top drive at report time. Total Losses from Midnight to 04:00- 0 bbls Displace Well. Reverse circulate 465 bbls 9.0 ppg viscosified seawater, 320 gpm, 2074 psi.Trip out of hole to surface. Install 7" test joint, change out pipe rams to 7". Test BOPE. Pick up 7" casing spear BHA and trip in hole with same tagging fish at 890'. PWD Drilling All Circ Avg Diam % Circulate and condition mud while working pipe 9064 - 9156'. Tag sand at 9156', rotate and circulate tag sand 9130'. 25 bbls 6.39'' Max: Hole Condition On Bot Hrs 14513' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… 24 hr Recap: 7" Logging Engineer:*10000 units = 100% Gas In AirDavid Mckechnie/Javian Ervin/Degi Olofinboba Ann Corr Cor Solids (lb/100ft2) 18,000 24 hr Max YP C3 21 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max Lst 1340 C2C1 Sh H2S Data Sample Line Avg: Chromatograph (ppm) Silt Siltst ClystCht N/A 14513'89.00 9.00 Nabors 19AC $5,035.50 AK-AM-0006852352 (ppb Eq)cP PV Size MBT Pioneer ODSK-13 Oooguruk 66 09/30/2011-04:00 14513' North Slope Daily Charges Avg 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 41 Cmt pH Chlorides GvlCoal Min Avg 2.0 mg/l AvgMin Max Max API Filt 8.00 3.5530 $395,592.68Total Charges: Flow In (spm) SPP (psi) Gallons/stroke RIH w/ fishing tool J. Polya/J.Habethur 0 Circ Flow In (gpm) Current Pump & Flow Data: 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 0 0' Depth md Total Losses from Midnight to Midnight - 0 bbls Total Losses from Midnight to 04:00- 0 bbls surface. Service rig, change rams. Test BOPE. Pull and lay casing to surface without the mule shoe. Service rig, rig up fishing tool and trip back in hole to retrieve mule shoe.. Tripping in hole at report time. PWD Drilling All Circ Avg Diam % Install upper IBOP and test same. Failed. Downtime, IBOP. Re-test same. Test BOPE. Pull and lay down 7" casing to 25 bbls 6.39'' Max: Hole Condition On Bot Hrs 14513' WELL NAME:ODSK-13LOCATION:OoogurukOPERATOR:Pioneer Natural ResourcesAREA:North SlopeMUD CO:BaroidSTATE:AlaskaRIG:Nabors 19ACSPUD:13-May-11SPERRY JOB:AK-AM-6852352TD:11-Jul-11BIT RECORDBHA # Bit # Bit Type Bit SizeDepth InDepth OutFootage Bit HoursTFA AVG ROPWOB (max)RPM (max)SPP(max)FLOW GPM (max)Bit Grade Remarks2 2 Baker GT-C1 10.63 3525 3545 20 0.50 0.9419 51 5.964 720 695 POOH to pick up GEO Pilot3 3 HDBS FXG65s 10.63 3545 9224 5679 69.18 1.2701 82 15146 3683 844 0-0-ER-C-X-I-NO-TDTD 10 5/8" section4 BN Bull Nose - - - - - ---- - - - -5 3RR1 HDBS FXG65s 10.63 3512 3529 17' 0.58 1.2701 35 15 70 3152 800 0-0-ER-C-X-I-NO-HPPOOH after getting stuck on Casing6 4 Baker GT-C1 10.63 3529 4241 714' 12.32 0.8560 58 25 1002900 850 1-1-NO-A-E-I-NO-BHAPOOH for GEO Pilot7 3RR2 HDBS FXG65s 10.63 4241 9100 4859' 66.20 1.2701 73 30 1404050 850 1-1-ER-C-X-I-NO-TDTD 10 5/8" by 11.75" section84RR3Ti10 509100910000002 356000124259785523ERCE1WTBHACl t RODSK-13 PB18 4RR3Tricone10.50 9100 9100 0 0.00 2.35600 01242597 855 2-3-ER-C-E1-WT-BHACleanout Run9 5RR1 Tricone 8.50 9100 9120 20 0.62 0.8560 32 15 802300 700 1-1-NO-A-E-I-NO-BHADrill Cement/FIT test10 6 HDBS FXG46Ds 8.50 9120 11187 2067 32.87 1.0354 63 33 1504300 700 0-1-CT-S-X-I-ER-TD TD Pilot hole11 6RR1 HDBS FXG46Ds 8.50 9098 11430 2332 39.86 1.0354 59 34 1404450 740 1-4-BT-S-X-I-CT-TD TD 8.5" by9.5" hole Section12 - Weatherford Polish Mill 8.40 - - - - - ---- - - Polished and Confirmed top of Liner13 7 Halliburton QH1R 6.13 11430 11454 24' 6.30 0.9204 18 22 1401750 250 3-2-CD-A-E-I-ER-BHADrilled 20', FIT, POOH for RSS BHA14 8 HDBS FXG64 6.13 11454 14513 3,059' 155.62 0.3889 28 30 1202350 250 1-2-ER-N-X-I-CT-TD Drilled Production Hole, MWD FailureODSK-13 PB2 WELL NAME:ODSK-13LOCATION:OoogurukOPERATOR:Pioneer Natural ResourcesAREA:North SlopeMUD CO:BaroidSTATE:AlaskaRIG:Nabors 19ACSPUD:31-Dec-09SPERRY JOB:AK-AM-6852352TD:16-Sep-11 Water- and Oil-Based Mud RecordDate Depth Wt Vis PV YP Gels FiltR600/R300/R200/R100/R6/R3Cake SolidsOil/WaterSd Pm pH MBT Pf/Mf Chlor Hard Remarksft - MD ppg sec cP lb/100 lb/100ft2 m/30m Rheometer 32nds % % % ppb Eqv mg/l Ca++26-Jul 3525 8.60 47 9 16 8/10/13 8.0 34/25/20/15/7/8 1/- 1.0 2/96 0.00 0.10 10.0 1.5 0.05/0.00 18,500 80 Pipe Management27-Jul 3525 8.60 45 7 16 8/11/12 8.0 30/23/19/15/7/6 1/- 11.0 2.5/85.5 0.00 - 9.0 1.0 0.06/0.40 19,000 100 Tripping28-Jul 3525 8.60 45 9 14 8/10/13 8.0 32/23/19/16/9/6 1/- 1.5 4.0/93.5 0.05 - 10.1 1.0 0.15/0.55 18,000 100 Reaming29-Jul 3825 8.60 49 8 26 9/13/17 5.8 42/34/29/23/10/8 2/0 1.6 4.0/93.5 0.05 - 10.0 2.0 0.10/0.65 16,000 120 Drilling30-Jul 5578 9.30 45 13 31 15/26/34 6.0 57/44/36/27/13/11 2/0 6.6 4.0/88.5 0.05 - 9.7 12.0 0.10/0.70 17,000 200 Drilling31-Jul 6507 9.35 54 11 28 15/27/38 5.5 50/39/34/28/16/15 2/0 6.7 4.0/89.0 0.05 - 10.0 15.0 0.15/0.90 18,000 200 Condition/Circulate1-Aug 6750 9.20 48 10 23 12/25/32 5.8 43/33/27/23/10/8 2/0 5.5 4.0/89.5 0.05 - 9.8 14.0 .010/0.75 18,000 280 Drilling Ahead2-Aug 8083 9.35 49 11 20 10/17/24 5.8 42/31/26/20/9/8 2/0 7.0 4.0/88.0 0.05 - 9.4 12.0 0.05/0.70 19,000 280 Drilling Ahead3-Aug 9224 9.24 49 10 27 11/17/24 5.8 47/37/31/24/11/10 2/0 7.0 4.0/88.0 0.10 - 9.9 11.0 0.05/0.85 20,000 280 Drilling Ahead4-Aug 9224 9.35 50 12 25 10/13/15 4.0 49/37/33/24/11/9 2/0 7.0 4.0/88.0 0.10 - 9.5 11.0 .05/0.55 19,000 320 Tripping5-Aug 9224 9.45 47 12 22 10/19/27 5.8 46/34/23/18/10/8 2/0 6.6 4.0/88.5 0.05 - 9.8 12.0 0.05/0.65 18,000 320 Reaming6-Aug 9224 9.60 54 11 41 24/32/45 6.0 63/52/45/37/20/19 2/0 8.0 3.5/87.5 0.05 - 9.5 14.0 0.08/0.40 19,000 320 Condition/Circulate7-Aug 9224 9.55 48 9 24 15/27/39 6.0 42/33/27/21/10/8 2/0 8.1 3.0/88.0 0.10 0.60 9.5 15.0 0.05/0.85 18,000 360 Condition/Circulate8-Aug 9224 9.60 51 10 22 16/29/39 6.0 42/32/27/21/10/8 2/0 8.6 2.0/88.5 0.10 0.45 9.4 15.0 0.05/0.70 18,000 320 Test BOP9-Aug 9224 10.70 55 14 26 17/32/35 10.5 54/40/35/28/14/13 2/0 16.7 1.5/81.0 0.10 - 10.2 19.0 0.05/2.50 17,000 1800 TrippingEnd ODSK-13 PB 110-Aug 3529 10.70 55 14 26 10/14/15 7.4 58/45/37/29/12/10 2/0 10.6 1.0/87.5 0.01 0.60 10.3 2.5 0.12/0.60 18,000 520 Tripping11-Aug 3750 11.00 55 17 42 16/19/21 4.4 76/59/51/41/18/15 2/0 11.6 4.5/83.0 0.10 0.90 9.7 4.5 0.15/1.10 18,000 480 Running in hole12-Aug 4,241 10.90 60 16 46 14/19/21 5.2 78/62/52/41/19/16 2/0 11.6 3.5/84.0 0.05 0.70 9.5 11.0 .10/0.40 18,500 400 Laying Down BHA13-Aug 5036 11.00 65 31 54 21/26/31 4.0 116/85/77/60/26/21 2/0 11.1 5.0/83.0 0.01 0.70 9.4 13.0 0.10/1.70 19,000 220 Drilling Ahead14-Aug 6501 11.00 60 30 48 11/12/13 2.2 108/78/63/46/14/11 2/0 11.1 5.0/83.0 0.01 0.40 9.5 16.0 0.05/0.85 19,000 88 Drilling Ahead15-Aug 7112 11.00 64 27 40 10/11/13 2.1 94/67/53/39/12/9 2/0 11.1 4.5/83.5 0.01 0.50 10.0 18.0 0.25/0.55 17,000 180 Drilling Ahead16-Aug 8275 11.00 67 37 52 21/24/0 2.2 126/89/74/55/24/21 2/0 11.1 5.0/83.0 0.01 0.80 10.0 16.0 0.30/1.20 18,000 120 Drilling Ahead17-Aug 9100 11.00 60 21 49 24/26/28 2.2 91/70/60/49/25/23 2/0 11.4 4.3/83.4 0.01 0.80 10.2 14.0 0.35/1.00 18,500 88 Tripping18-Aug 9100 11.00 80 18 49 16/19/22 3.2 85/67/54/41/18/15 2/0 11.1 4.0/84.0 0.01 0.60 10.0 20.0 0.30/1.20 18,500 100 Backreaming19-Aug 9100 11.00 65 29 41 13/15/18 2.7 99/70/60/44/15/13 2/0 11.0 4.0/84.0 0.01 0.40 10.0 20.0 0.35/1.70 20,000 100 Tripping20-Aug 9100 10.00 50 12 15 4/6/9 4.5 39/27/21/15/5/3 2/0 0.0 2.5/0.0 0.01 0.30 10.0 12.0 0.20/1.10 20,000 80 Run Casing and Cement21 A910010 004813156/9/174841/28/22/16/6/42/08525/8801003010 012 50 20/1 8020 000100T i i B id Pl BHA21-Aug9100 10.00 48 13 15 6/9/174.8 41/28/22/16/6/42/08.5 2.5/880.100.3010.0 12.5 0.20/1.8020,000100 Tripping Bridge Plug BHA22-Aug 9100 10.00 49 14 27 8/12/20 5.0 55/41/34/23/8/6 2/0 8.6 2.5/88 0.10 0.40 10.0 10.0 0.30/1.90 18,000 160 Tripping Bridge Plug Assembly23-Aug 9120 9.80 45 7 16 6/8/11 4.6 30/23/20/15/7/6 2/0 9.0 3.0/87.0 0.00 0.70 10.1 1.5 0.10/0.90 19,000 160 Tripping 24-Aug 9746 9.80 53 16 21 6/7/10 4.0 53/37/30/22/8/5 2/0 10.1 3.5/85.5 0.10 - 10.3 2.5 0.10/1.10 18,000 120 Drilling Ahead25-Aug 10575 10.20 55 24 30 6/8/9 4.0 78/54/44/31/8/6 2/0 9.3 4.5/85.3 0.10 - 10.0 8.5 0.10/1.65 17,000 240 Drilling Ahead26-Aug 11187 13.00 55 24 34 10/13/17 4.0 82/58/47/35/12/10 2/0 9.4 4.0/85.7 0.10 - 10.0 8.0 0.15/1.95 18,000 240 Condition/Circulate27-Aug 11187 13.00 62 35 47 15/19/25 4.0 117/82/65/50/18/15 2/0 20.2 3.0/76.0 0.10 - 9.5 7.5 0.10/1.80 17,000 200 Condition/Circulate28-Aug 8812 9.90 50 13 21 8/10/12 5.0 47/34/29/21/9/7 2/0 8.1 1.0/90.0 0.10 - 9.7 4.5 0.10/0.65 17,000 240 Service rig29-Aug 9406 9.80 47 16 21 5/7/10 3.8 53/37/30/23/6/4/3.8 2/0 8.2 6.0/85 0.10 - 11.0 0.05/2.40 15,500 600 Drilling Ahead30-Aug 10452 9.90 54 23 30 8/20/0 3.8 76/5343/30/9/7 2/0 8.2 5.5/85.5 0.10 - 10.4 5.0 0.10/2.60 16,000 680 Drilling Ahead31-Aug 11118 9.90 52 33 37 11/19/29 4.0 103/70/57/39/10/9.0 2/0 8.2 5.0/86.0 0.10 - 10.3 11.0 0.15/2.40 16,000 480 Repair rig1-Sep 11430 10.20 75 28 45 14/25/31 3.6 101/73/61/45/16/13 2/0 10.2 6.0/83.0 0.05 0.35 9.8 14.0 0.10/1.45 17,000 240 Circ/Condition2-Sep 11430 13.00 78 44 61 23/39/45 3.8 149/105/87/65/25/21 2/0 19.2 5.0/75.0 0.05 0.15 9.2 9.0 0.10/1.20 17,000 400 Test BOP3-Sep 11430 10.20 75 29 42 12/22/29 4.8 100/71/58/41/14/12 2/0 10.1 4.0/85.0 0.01 0.25 9.5 6.0 0.10/1.25 17,000 240 Run Liner and Cement4-Sep 11430 10.20 76 31 38 11/20/28 4.8 100/69/56/40/14/13 2/0 10.1 4.0/85.0 0.01 0.30 9.5 8.0 0.10/1.20 17,000 280 Tripping 5-Sep 11430 10.20 76 33 33 11/19/28 5.0 99/66/55/38/14/12 2/0 10.1 4.0/85.0 0.05 0.25 9.2 8.0 0.05/1.00 17,000 280 Casing 6-Sep 11430 10.20 73 30 38 13/20/26 3.6 98/68/55/39/13/12 2/0 10.1 4.0/85.0 0.01 0.30 9.0 8.0 0.05/1.10 17,000 300 Tripping7-Sep 11430 10.20 73 30 38 13/20/26 3.6 98/68/55/39/13/12 2/0 10.1 4.0/85.0 0.01 0.30 9.0 8.0 0.05/1.10 17,000 300 Testing B.O.P.8-Sep 11430 10.20 60 13 26 9/12/17 4.1 52/39/31/26/10/8 2/0 10.1 4.0/85.0 0.01 0.23 9.0 8.0 0.05/1.05 17,000 260 Condition/Circulate9-Sep 11454 10.30 46 12 18 5/9/14 6.8 42/30/24/18/5/4 2/0 10.2 4.0/85.0 0.01 5.80 11.9 6.0 0.70/1.25 16,500 640 Tripping10-Sep 11650 8.50 49 6 23 9/11/13 5.8 35/29/26/21/9/8 1/0 0.4 3.0/95.6 0.01 0.50 9.5 0.5 0.10/0.60 17,000 280 Drilling Ahead11-Sep 11725 8.50 47 7 21 8/11/13 5.8 35/28/25/20/9/8 1/0 1.0 6.0/92.3 0.01 - 8.9 2.5 0.05/0.45 13,000 560 Drilling Ahead12-Sep 11919 8.50 52 9 23 9/12/14 5.2 41/32/28/23/10/8 1/0 0.7 5.0/93.4 0.01 0.50 9.5 2.5 0.10/0.55 15,000 360 Circ/Condition13-Sep 11935 8.50 52 8 25 9/12/14 5.8 41/33/29/24/11/91/1 0.7 4.5/93.9 0.010.259.5 1.0 0.05/0.4014,500 880 Drilling Ahead14-Sep 12832 8.50 48 7 23 9/13/2016 5.637/30/28/22/9/8 1/0 0.6 4.0/94.50.010.69.6 3.5 0.15/0.8515,000 480 Drilling Ahead15-Sep 13939 8.50 43 7 17 7/9/12 5.6 31/24/22/17/8/6 1/0 0.3 1.5/97.3 0.10 0.50 9.4 1.5 0.15/0.90 16,000 240 Drilling Ahead16-Sep 14513 8.50 43 6 22 8/10/14 5.8 34/28/24/19/11/7 1/0 0.6 2.0/96.4 0.10 0.40 9.3 1.5 0.20/1.20 17,000 200 Tripping 17-Sep 14513 11.20 42 - - - - - - - 0.0/97.0 - - - - - 178,000 - Tripping18-Sep 14513 11.20 42 9 22 10/11/13 40/31/26/21/10/9 - -8.1 0.0/97.0 - - 7.5 - - 172,000 - Run Liner and Cement19-Sep 14513 11.15 42 9 23 10/11/13 41/32/27/21/10/9 - -8.3 0.0/97.2 - - 7.5 - - 171,000 - Tripping 20-Sep 14513 11.10 43 10 23 10/12/13 43/33/28/22/11/9 - -8.1 0.0/97.0 - - 7.5 - - 172,000 - Tripping21-Sep 11513 11.10 42 10 20 9/10/12 40/30/26/21/10/8 - -7.5 0.0/96.6 - - 7.3 - - 170,000 - -Casing Record16" Conductor @ 15811.75" Intermediate @ 3512'9.625" Intermediate @ 11,6587' 7" Intermediate @ 14,082'End of ODSK-13 Marker MD INC AZ TVD TVDSS Surface Hole Base Permafrost 1716.0 25.60 308.10 1668.20 1612.00 Top West Sak 2442.0 35.50 340.70 2305.50 2249.30 Tuffaceous Shale 3377.0 64.30 1.20 2889.50 2833.30 SCP 3512.6 63.50 2.40 2949.10 2892.90 ODSK-13 PB1 Hue 1 Marker 3826.0 62.50 12.70 3094.70 3038.50 Hue 2 Marker 4111.0 63.70 21.20 3224.60 3168.40 Brook 2B 6703.0 65.30 38.70 4328.00 4271.80 Torok Top 8455.0 58.90 14.50 5154.10 5097.90 Torok Base 8951.0 56.60 1.40 5417.00 5360.80 Torok SH_1 9188.0 56.50 357.90 5549.40 5493.20 ODSK-13 Intermediate 1 Brookian 2B 6739.0 67.40 51.40 4322.60 4266.40 Torok Top 8582.0 58.20 15.00 5150.00 5093.80 Torok Base 9076.0 57.70 365.50 5411.40 5355.20 ICP 9098.0 57.50 356.70 5423.20 5367.00 ODSK-13 Pilot Hole PB2 Torok Shale 9324.0 56.90 357.60 5546.00 5489.80 Top HRZ 9988.0 56.50 345.20 5902.70 5846.50 Base HRZ 10218.0 58.00 339.20 6027.30 5971.10 Kalubik Marker 10362.0 57.30 335.50 6104.60 6048.40 Kup C 10478.0 57.20 331.80 6167.30 6111.10 Base Kup C(LCU)10504.0 56.70 330.60 6181.40 6125.20 ODSK-13 Interpolated Tops BCU 10756.0 54.00 324.90 6325.10 6268.90 Nuiqsut 10849.0 53.00 326.00 6380.50 6324.30 Base Nuiqsut 10986.0 51.50 326.60 6463.90 6407.70 Nechelik 10993.0 51.30 326.60 6468.30 6412.10 Base Nechelik 11082.0 49.40 326.80 6525.20 6469.00 Pilot TD 11187.0 48.20 372.20 6594.70 6538.50 OSK-13 Interpolated Tops Torok Shale 1 9329.0 58.70 354.10 5547.00 5490.80 Top HRZ 10104.0 65.20 343.10 5906.80 5850.60 Base HRZ 10467.0 73.10 334.90 6032.80 5976.60 Kalubic Mkr 10782.0 78.60 327.20 6111.30 6055.10 Kuparuk C 11426.0 87.30 320.60 6182.00 6125.80 7" ICP2 Shoe 11428.0 87.40 320.70 6182.10 6125.90 Kuparuk C ::LCU D1 11790.0 85.40 319.20 6200.90 6144.70 LCU::Kuparuk C U1 11949.0 91.60 319.20 6203.10 6146.90 Total Depth Lateral 14513.0 87.60 325.30 6251.20 6195.00 22 September, 2011 Oooguruk Development Oooguruk Drill Site ODSK-13PB1 Permit to Drill: 209-1460 API: 50-703-20607-00 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSK-13 ODSK-13PB1 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSK-13PB1 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSK-13 - Slot ODS-13 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Oooguruk Development Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: ft +E/-W +N/-S Position Uncertainty ft ft ftGround Level: ODSK-13 - Slot ODS-13 ft ft 0.00 0.00 6,031,076.06 469,845.81 13.50Wellhead Elevation:ft0.00 70° 29' 45.498 N 150° 14' 47.653 W Wellbore Declination (?) Field Strength (nT) Sample Date Dip Angle (?) ODSK-13PB1 Model NameMagnetics IGRF200510 12/29/2009 21.99 80.81 57,759 Phase:Version: Audit Notes: Design ODSK-13PB1 1.0 ACTUAL Vertical Section: Depth From (TVD) (ft) +N/-S (ft) Direction (?) +E/-W (ft) Tie On Depth:42.70 9.730.000.0042.70 From (ft) Survey Program DescriptionTool NameSurvey (Wellbore) To (ft) Date 9/19/2011 Survey Start Date SR-Gyro-SS Fixed:v2:surface readout gyro single shot100.00 532.00 ODSK-13 Gyro (ODSK-13PB1)01/04/2010 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag573.71 3,468.28 ODSK-13 MWD (ODSK-13PB1)01/04/2010 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag3,555.82 9,192.55 ODSK-13 MWD Run 300 (ODSK-13PB1 08/01/2011 MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 42.70 0.00 0.00 42.70 0.00 0.00-13.50 6,031,076.06 469,845.81 0.00 0.00 UNDEFINED 100.00 0.34 221.19 100.00 -0.13 -0.1143.80 6,031,075.93 469,845.70 0.59 -0.15 SR-Gyro-SS (1) 168.00 0.16 130.95 168.00 -0.34 -0.17111.80 6,031,075.72 469,845.63 0.55 -0.37 SR-Gyro-SS (1) 259.00 0.70 164.84 259.00 -0.96 0.07202.80 6,031,075.10 469,845.87 0.63 -0.94 SR-Gyro-SS (1) 350.00 0.37 253.30 349.99 -1.58 -0.07293.79 6,031,074.48 469,845.73 0.86 -1.57 SR-Gyro-SS (1) 441.00 1.19 307.31 440.99 -1.09 -1.10384.79 6,031,074.97 469,844.70 1.12 -1.26 SR-Gyro-SS (1) 532.00 1.95 322.83 531.95 0.71 -2.79475.75 6,031,076.78 469,843.02 0.95 0.23 SR-Gyro-SS (1) 573.71 1.85 317.80 573.64 1.78 -3.67517.44 6,031,077.85 469,842.15 0.47 1.13 MWD+IFR2+MS+sag (2) 626.58 3.17 315.66 626.46 3.45 -5.26570.26 6,031,079.54 469,840.56 2.50 2.51 MWD+IFR2+MS+sag (2) 671.26 4.30 316.56 671.04 5.55 -7.28614.84 6,031,081.64 469,838.55 2.53 4.24 MWD+IFR2+MS+sag (2) 763.81 6.86 316.45 763.14 12.08 -13.47706.94 6,031,088.19 469,832.39 2.77 9.63 MWD+IFR2+MS+sag (2) 813.54 8.01 316.35 812.46 16.74 -17.91756.26 6,031,092.87 469,827.97 2.31 13.47 MWD+IFR2+MS+sag (2) 9/22/2011 1:52:47PM COMPASS 2003.16 Build 42 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSK-13 ODSK-13PB1 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSK-13PB1 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSK-13 - Slot ODS-13 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 860.24 8.60 315.98 858.67 21.61 -22.59802.47 6,031,097.76 469,823.31 1.27 17.48 MWD+IFR2+MS+sag (2) 909.76 9.51 313.90 907.57 27.11 -28.11851.37 6,031,103.28 469,817.82 1.95 21.96 MWD+IFR2+MS+sag (2) 956.78 9.35 312.67 953.95 32.39 -33.71897.75 6,031,108.58 469,812.23 0.55 26.22 MWD+IFR2+MS+sag (2) 1,005.95 9.18 310.28 1,002.48 37.63 -39.64946.28 6,031,113.85 469,806.32 0.86 30.39 MWD+IFR2+MS+sag (2) 1,049.84 11.17 311.64 1,045.68 42.72 -45.49989.48 6,031,118.96 469,800.50 4.57 34.42 MWD+IFR2+MS+sag (2) 1,096.33 13.93 309.80 1,091.05 49.29 -53.161,034.85 6,031,125.56 469,792.86 6.00 39.60 MWD+IFR2+MS+sag (2) 1,145.56 15.24 312.60 1,138.70 57.47 -62.471,082.50 6,031,133.77 469,783.58 3.02 46.08 MWD+IFR2+MS+sag (2) 1,194.22 15.31 310.88 1,185.64 66.00 -72.041,129.44 6,031,142.35 469,774.05 0.94 52.88 MWD+IFR2+MS+sag (2) 1,240.56 16.78 310.92 1,230.17 74.39 -81.721,173.97 6,031,150.77 469,764.40 3.17 59.51 MWD+IFR2+MS+sag (2) 1,289.96 18.95 309.46 1,277.19 84.16 -93.301,220.99 6,031,160.59 469,752.86 4.48 67.18 MWD+IFR2+MS+sag (2) 1,336.79 20.72 308.92 1,321.24 94.19 -105.621,265.04 6,031,170.67 469,740.59 3.80 74.99 MWD+IFR2+MS+sag (2) 1,384.42 22.51 306.84 1,365.52 104.96 -119.471,309.32 6,031,181.49 469,726.78 4.09 83.25 MWD+IFR2+MS+sag (2) 1,430.42 23.07 305.99 1,407.93 115.53 -133.811,351.73 6,031,192.12 469,712.48 1.41 91.25 MWD+IFR2+MS+sag (2) 1,479.83 23.39 304.58 1,453.33 126.79 -149.721,397.13 6,031,203.44 469,696.62 1.30 99.66 MWD+IFR2+MS+sag (2) 1,525.32 23.94 305.15 1,494.99 137.23 -164.701,438.79 6,031,213.94 469,681.68 1.31 107.42 MWD+IFR2+MS+sag (2) 1,576.16 24.01 305.92 1,541.45 149.23 -181.511,485.25 6,031,226.01 469,664.92 0.63 116.41 MWD+IFR2+MS+sag (2) 1,621.34 24.33 306.96 1,582.67 160.22 -196.391,526.47 6,031,237.06 469,650.09 1.18 124.72 MWD+IFR2+MS+sag (2) 1,671.07 25.79 307.41 1,627.72 172.95 -213.171,571.52 6,031,249.86 469,633.36 2.96 134.44 MWD+IFR2+MS+sag (2) 1,705.60 25.58 308.15 1,658.83 182.12 -225.001,602.63 6,031,259.07 469,621.57 1.11 141.47 MWD+IFR2+MS+sag (2) 1,766.84 25.73 308.07 1,714.04 198.48 -245.861,657.84 6,031,275.52 469,600.78 0.25 154.08 MWD+IFR2+MS+sag (2) 1,811.68 25.57 310.02 1,754.46 210.71 -260.931,698.26 6,031,287.80 469,585.76 1.92 163.58 MWD+IFR2+MS+sag (2) 1,862.23 25.52 312.44 1,800.07 225.07 -277.331,743.87 6,031,302.23 469,569.43 2.07 174.96 MWD+IFR2+MS+sag (2) 1,907.09 25.51 313.53 1,840.55 238.25 -291.461,784.35 6,031,315.46 469,555.35 1.05 185.56 MWD+IFR2+MS+sag (2) 1,958.99 26.92 315.00 1,887.11 254.25 -307.871,830.91 6,031,331.53 469,539.00 2.99 198.56 MWD+IFR2+MS+sag (2) 2,001.97 27.61 317.15 1,925.32 268.43 -321.531,869.12 6,031,345.77 469,525.41 2.80 210.23 MWD+IFR2+MS+sag (2) 2,097.12 28.74 323.48 2,009.21 302.99 -350.141,953.01 6,031,380.44 469,496.94 3.36 239.46 MWD+IFR2+MS+sag (2) 2,192.69 29.36 331.16 2,092.79 341.99 -375.132,036.59 6,031,419.54 469,472.11 3.95 273.68 MWD+IFR2+MS+sag (2) 2,241.25 29.14 334.14 2,135.16 363.06 -386.022,078.96 6,031,440.65 469,461.30 3.03 292.60 MWD+IFR2+MS+sag (2) 2,287.81 29.36 334.80 2,175.78 383.59 -395.832,119.58 6,031,461.22 469,451.58 0.84 311.18 MWD+IFR2+MS+sag (2) 2,383.06 33.63 338.04 2,256.99 429.21 -415.652,200.79 6,031,506.91 469,431.95 4.82 352.79 MWD+IFR2+MS+sag (2) 2,477.86 36.61 342.39 2,334.53 480.52 -434.022,278.33 6,031,558.28 469,413.78 4.10 400.25 MWD+IFR2+MS+sag (2) 2,530.79 38.32 345.12 2,376.55 511.42 -443.012,320.35 6,031,589.22 469,404.92 4.50 429.19 MWD+IFR2+MS+sag (2) 2,572.80 40.97 347.17 2,408.89 537.44 -449.422,352.69 6,031,615.27 469,398.62 7.03 453.76 MWD+IFR2+MS+sag (2) 2,619.68 42.07 349.45 2,444.00 567.87 -455.702,387.80 6,031,645.72 469,392.46 3.99 482.69 MWD+IFR2+MS+sag (2) 2,668.18 44.23 350.62 2,479.38 600.54 -461.442,423.18 6,031,678.41 469,386.86 4.75 513.91 MWD+IFR2+MS+sag (2) 2,763.56 46.77 352.08 2,546.23 667.79 -471.652,490.03 6,031,745.69 469,376.92 2.88 578.47 MWD+IFR2+MS+sag (2) 2,857.18 49.32 354.88 2,608.82 736.95 -479.522,552.62 6,031,814.87 469,369.33 3.52 645.30 MWD+IFR2+MS+sag (2) 2,953.56 52.79 357.15 2,669.40 811.71 -484.692,613.20 6,031,889.64 469,364.47 4.04 718.11 MWD+IFR2+MS+sag (2) 3,048.04 54.50 358.46 2,725.40 887.74 -487.592,669.20 6,031,965.68 469,361.87 2.13 792.56 MWD+IFR2+MS+sag (2) 3,143.06 57.30 358.73 2,778.67 966.39 -489.522,722.47 6,032,044.33 469,360.26 2.96 869.75 MWD+IFR2+MS+sag (2) 9/22/2011 1:52:47PM COMPASS 2003.16 Build 42 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSK-13 ODSK-13PB1 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSK-13PB1 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSK-13 - Slot ODS-13 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 3,239.01 61.30 359.87 2,827.65 1,048.87 -490.512,771.45 6,032,126.80 469,359.61 4.29 950.88 MWD+IFR2+MS+sag (2) 3,332.55 64.45 1.07 2,870.29 1,132.10 -489.822,814.09 6,032,210.02 469,360.64 3.56 1,033.03 MWD+IFR2+MS+sag (2) 3,429.23 64.20 1.45 2,912.18 1,219.21 -487.902,855.98 6,032,297.12 469,362.91 0.44 1,119.22 MWD+IFR2+MS+sag (2) 3,468.28 63.59 2.08 2,929.36 1,254.26 -486.822,873.16 6,032,332.16 469,364.13 2.13 1,153.95 MWD+IFR2+MS+sag (2) 3,555.82 63.39 2.74 2,968.43 1,332.53 -483.532,912.23 6,032,410.41 469,367.74 0.71 1,231.64 MWD+IFR2+MS+sag (3) 3,578.71 62.75 2.28 2,978.80 1,352.92 -482.632,922.60 6,032,430.79 469,368.72 3.32 1,251.89 MWD+IFR2+MS+sag (3) 3,677.09 61.59 5.97 3,024.74 1,439.67 -476.392,968.54 6,032,517.51 469,375.31 3.52 1,338.45 MWD+IFR2+MS+sag (3) 3,770.79 62.04 10.47 3,069.02 1,521.38 -464.583,012.82 6,032,599.16 469,387.45 4.26 1,420.98 MWD+IFR2+MS+sag (3) 3,866.65 62.81 14.30 3,113.40 1,604.35 -446.353,057.20 6,032,682.05 469,406.01 3.63 1,505.83 MWD+IFR2+MS+sag (3) 3,960.85 62.51 16.53 3,156.67 1,685.01 -424.113,100.47 6,032,762.61 469,428.58 2.13 1,589.09 MWD+IFR2+MS+sag (3) 4,055.97 63.27 19.06 3,200.02 1,765.62 -398.243,143.82 6,032,843.10 469,454.78 2.50 1,672.91 MWD+IFR2+MS+sag (3) 4,151.57 63.95 22.84 3,242.53 1,845.57 -367.623,186.33 6,032,922.92 469,485.72 3.61 1,756.89 MWD+IFR2+MS+sag (3) 4,246.13 64.78 26.99 3,283.45 1,922.86 -331.703,227.25 6,033,000.06 469,521.94 4.05 1,839.14 MWD+IFR2+MS+sag (3) 4,341.23 64.57 30.27 3,324.14 1,998.30 -290.523,267.94 6,033,075.32 469,563.42 3.13 1,920.45 MWD+IFR2+MS+sag (3) 4,435.82 64.23 32.53 3,365.01 2,071.10 -246.093,308.81 6,033,147.94 469,608.15 2.18 1,999.72 MWD+IFR2+MS+sag (3) 4,531.81 63.49 34.47 3,407.31 2,142.96 -198.533,351.11 6,033,219.59 469,655.99 1.97 2,078.58 MWD+IFR2+MS+sag (3) 4,626.75 63.88 36.82 3,449.40 2,212.11 -148.943,393.20 6,033,288.53 469,705.86 2.26 2,155.11 MWD+IFR2+MS+sag (3) 4,721.33 64.39 38.83 3,490.66 2,279.32 -96.753,434.46 6,033,355.53 469,758.32 1.99 2,230.18 MWD+IFR2+MS+sag (3) 4,817.23 64.79 41.08 3,531.82 2,345.72 -41.133,475.62 6,033,421.69 469,814.20 2.16 2,305.02 MWD+IFR2+MS+sag (3) 4,912.03 64.23 40.84 3,572.61 2,410.34 14.973,516.41 6,033,486.07 469,870.56 0.63 2,378.19 MWD+IFR2+MS+sag (3) 5,006.90 64.64 41.25 3,613.55 2,474.88 71.173,557.35 6,033,550.38 469,927.01 0.58 2,451.31 MWD+IFR2+MS+sag (3) 5,101.42 64.93 39.96 3,653.82 2,539.80 126.823,597.62 6,033,615.07 469,982.92 1.27 2,524.70 MWD+IFR2+MS+sag (3) 5,196.84 65.06 40.99 3,694.16 2,605.58 182.953,637.96 6,033,680.62 470,039.31 0.99 2,599.02 MWD+IFR2+MS+sag (3) 5,291.68 64.77 40.39 3,734.37 2,670.71 238.953,678.17 6,033,745.51 470,095.57 0.65 2,672.68 MWD+IFR2+MS+sag (3) 5,386.51 64.54 41.16 3,774.96 2,735.61 294.923,718.76 6,033,810.18 470,151.80 0.77 2,746.10 MWD+IFR2+MS+sag (3) 5,481.66 64.68 41.22 3,815.76 2,800.30 351.533,759.56 6,033,874.63 470,208.66 0.16 2,819.43 MWD+IFR2+MS+sag (3) 5,576.70 64.71 41.47 3,856.38 2,864.80 408.293,800.18 6,033,938.90 470,265.68 0.24 2,892.60 MWD+IFR2+MS+sag (3) 5,670.97 64.95 40.30 3,896.48 2,929.31 464.133,840.28 6,034,003.16 470,321.78 1.15 2,965.61 MWD+IFR2+MS+sag (3) 5,766.10 65.25 38.59 3,936.53 2,995.94 518.953,880.33 6,034,069.57 470,376.86 1.66 3,040.55 MWD+IFR2+MS+sag (3) 5,861.55 65.54 38.12 3,976.27 3,063.99 572.803,920.07 6,034,137.39 470,430.98 0.54 3,116.72 MWD+IFR2+MS+sag (3) 5,956.37 65.14 39.26 4,015.84 3,131.25 626.673,959.64 6,034,204.43 470,485.11 1.17 3,192.12 MWD+IFR2+MS+sag (3) 6,051.38 65.29 38.93 4,055.67 3,198.20 681.063,999.47 6,034,271.14 470,539.77 0.35 3,267.29 MWD+IFR2+MS+sag (3) 6,145.92 65.05 38.54 4,095.37 3,265.12 734.754,039.17 6,034,337.85 470,593.72 0.45 3,342.33 MWD+IFR2+MS+sag (3) 6,241.44 64.90 39.62 4,135.77 3,332.31 789.314,079.57 6,034,404.81 470,648.55 1.04 3,417.77 MWD+IFR2+MS+sag (3) 6,337.01 64.85 40.68 4,176.35 3,398.45 845.104,120.15 6,034,470.71 470,704.61 1.01 3,492.39 MWD+IFR2+MS+sag (3) 6,432.40 64.93 40.88 4,216.83 3,463.85 901.524,160.63 6,034,535.88 470,761.28 0.21 3,566.39 MWD+IFR2+MS+sag (3) 6,526.91 66.06 40.29 4,256.03 3,529.16 957.464,199.83 6,034,600.95 470,817.48 1.32 3,640.21 MWD+IFR2+MS+sag (3) 6,621.96 66.00 40.37 4,294.65 3,595.37 1,013.674,238.45 6,034,666.93 470,873.96 0.10 3,714.97 MWD+IFR2+MS+sag (3) 6,717.88 65.21 38.37 4,334.27 3,662.90 1,069.094,278.07 6,034,734.22 470,929.64 2.07 3,790.89 MWD+IFR2+MS+sag (3) 6,812.62 64.24 37.19 4,374.72 3,730.60 1,121.574,318.52 6,034,801.71 470,982.39 1.52 3,866.49 MWD+IFR2+MS+sag (3) 9/22/2011 1:52:47PM COMPASS 2003.16 Build 42 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSK-13 ODSK-13PB1 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSK-13PB1 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSK-13 - Slot ODS-13 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 6,907.44 64.22 37.11 4,415.94 3,798.67 1,173.144,359.74 6,034,869.55 471,034.23 0.08 3,942.29 MWD+IFR2+MS+sag (3) 7,002.96 63.92 38.41 4,457.71 3,866.58 1,225.744,401.51 6,034,937.24 471,087.10 1.26 4,018.11 MWD+IFR2+MS+sag (3) 7,097.97 64.36 39.31 4,499.15 3,933.15 1,279.384,442.95 6,035,003.59 471,141.01 0.97 4,092.79 MWD+IFR2+MS+sag (3) 7,193.33 62.83 38.02 4,541.56 3,999.83 1,332.754,485.36 6,035,070.05 471,194.63 2.01 4,167.54 MWD+IFR2+MS+sag (3) 7,288.50 62.64 36.54 4,585.16 4,067.14 1,383.994,528.96 6,035,137.14 471,246.14 1.40 4,242.54 MWD+IFR2+MS+sag (3) 7,383.33 62.35 35.16 4,628.96 4,135.31 1,433.254,572.76 6,035,205.11 471,295.67 1.33 4,318.05 MWD+IFR2+MS+sag (3) 7,479.51 61.83 33.70 4,673.98 4,205.41 1,481.304,617.78 6,035,275.01 471,344.01 1.45 4,395.27 MWD+IFR2+MS+sag (3) 7,574.86 61.54 31.91 4,719.21 4,275.96 1,526.784,663.01 6,035,345.36 471,389.76 1.68 4,472.49 MWD+IFR2+MS+sag (3) 7,670.10 61.18 31.24 4,764.86 4,347.17 1,570.544,708.66 6,035,416.39 471,433.82 0.72 4,550.07 MWD+IFR2+MS+sag (3) 7,765.07 60.83 29.78 4,810.90 4,418.74 1,612.724,754.70 6,035,487.77 471,476.27 1.39 4,627.73 MWD+IFR2+MS+sag (3) 7,859.90 60.68 27.85 4,857.23 4,491.23 1,652.604,801.03 6,035,560.09 471,516.44 1.78 4,705.92 MWD+IFR2+MS+sag (3) 7,955.59 61.13 26.66 4,903.76 4,565.56 1,690.884,847.56 6,035,634.26 471,555.03 1.18 4,785.65 MWD+IFR2+MS+sag (3) 8,050.02 60.50 24.71 4,949.81 4,639.85 1,726.624,893.61 6,035,708.40 471,591.06 1.92 4,864.91 MWD+IFR2+MS+sag (3) 8,145.69 60.06 22.42 4,997.24 4,716.00 1,759.834,941.04 6,035,784.40 471,624.58 2.13 4,945.58 MWD+IFR2+MS+sag (3) 8,240.52 59.99 20.69 5,044.63 4,792.39 1,790.014,988.43 6,035,860.67 471,655.07 1.58 5,025.97 MWD+IFR2+MS+sag (3) 8,335.23 59.30 17.78 5,092.50 4,869.54 1,816.945,036.30 6,035,937.70 471,682.30 2.75 5,106.56 MWD+IFR2+MS+sag (3) 8,432.15 58.84 15.07 5,142.32 4,949.27 1,840.455,086.12 6,036,017.33 471,706.13 2.44 5,189.12 MWD+IFR2+MS+sag (3) 8,526.58 58.97 12.58 5,191.09 5,027.78 1,859.775,134.89 6,036,095.75 471,725.77 2.26 5,269.77 MWD+IFR2+MS+sag (3) 8,621.41 58.41 8.92 5,240.39 5,107.36 1,874.885,184.19 6,036,175.25 471,741.21 3.35 5,350.75 MWD+IFR2+MS+sag (3) 8,716.41 57.63 7.17 5,290.70 5,187.14 1,886.175,234.50 6,036,254.98 471,752.81 1.77 5,431.30 MWD+IFR2+MS+sag (3) 8,812.24 57.64 5.02 5,342.01 5,267.62 1,894.765,285.81 6,036,335.42 471,761.73 1.90 5,512.07 MWD+IFR2+MS+sag (3) 8,907.18 57.23 2.25 5,393.11 5,347.46 1,899.845,336.91 6,036,415.23 471,767.13 2.50 5,591.62 MWD+IFR2+MS+sag (3) 9,001.87 55.89 0.36 5,445.30 5,426.45 1,901.645,389.10 6,036,494.20 471,769.26 2.19 5,669.77 MWD+IFR2+MS+sag (3) 9,097.31 55.81 359.30 5,498.87 5,505.43 1,901.415,442.67 6,036,573.17 471,769.34 0.92 5,747.58 MWD+IFR2+MS+sag (3) 9,192.55 56.55 357.79 5,551.88 5,584.52 1,899.405,495.68 6,036,652.27 471,767.65 1.53 5,825.20 MWD+IFR2+MS+sag (3) 9,224.00 56.55 357.79 5,569.22 5,610.74 1,898.395,513.02 6,036,678.49 471,766.75 0.00 5,850.87 PROJECTED to TD 9/22/2011 1:52:47PM COMPASS 2003.16 Build 42 Page 5 22 September, 2011 Oooguruk Development Oooguruk Drill Site ODSK-13PB2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSK-13 ODSK-13PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSK-13PB2 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSK-13 - Slot ODS-13 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Oooguruk Development Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: ft +E/-W +N/-S Position Uncertainty ft ft ftGround Level: ODSK-13 - Slot ODS-13 ft ft 0.00 0.00 6,031,076.06 469,845.81 13.50Wellhead Elevation:ft0.00 70° 29' 45.498 N 150° 14' 47.653 W Wellbore Declination (?) Field Strength (nT) Sample Date Dip Angle (?) ODSK-13PB2 Model NameMagnetics User Defined 7/27/2011 20.82 80.97 57,639 Phase:Version: Audit Notes: Design ODSK-13PB2 1.0 ACTUAL Vertical Section: Depth From (TVD) (ft) +N/-S (ft) Direction (?) +E/-W (ft) Tie On Depth:3,468.28 9.730.000.0042.70 From (ft) Survey Program DescriptionTool NameSurvey (Wellbore) To (ft) Date 9/22/2011 Survey Start Date SR-Gyro-SS Fixed:v2:surface readout gyro single shot100.00 532.00 ODSK-13 Gyro (ODSK-13PB1)01/04/2010 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag573.71 3,468.28 ODSK-13 MWD (ODSK-13PB1)01/04/2010 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag3,512.00 4,188.14 ODSK-13PB2 MWD Run 600 (ODSK-13 08/11/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag4,249.10 9,067.50 ODSK-13PB2 MWD Run 700 (ODSK-13 08/25/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag9,140.14 11,140.31 ODSK-13PB2 MWD Run 1000 (ODSK-1 09/22/2011 MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 42.70 0.00 0.00 42.70 0.00 0.00-13.50 6,031,076.06 469,845.81 0.00 0.00 UNDEFINED 100.00 0.34 221.19 100.00 -0.13 -0.1143.80 6,031,075.93 469,845.70 0.59 -0.15 SR-Gyro-SS (1) 168.00 0.16 130.95 168.00 -0.34 -0.17111.80 6,031,075.72 469,845.63 0.55 -0.37 SR-Gyro-SS (1) 259.00 0.70 164.84 259.00 -0.96 0.07202.80 6,031,075.10 469,845.87 0.63 -0.94 SR-Gyro-SS (1) 350.00 0.37 253.30 349.99 -1.58 -0.07293.79 6,031,074.48 469,845.73 0.86 -1.57 SR-Gyro-SS (1) 441.00 1.19 307.31 440.99 -1.09 -1.10384.79 6,031,074.97 469,844.70 1.12 -1.26 SR-Gyro-SS (1) 532.00 1.95 322.83 531.95 0.71 -2.79475.75 6,031,076.78 469,843.02 0.95 0.23 SR-Gyro-SS (1) 573.71 1.85 317.80 573.64 1.78 -3.67517.44 6,031,077.85 469,842.15 0.47 1.13 MWD+IFR2+MS+sag (2) 626.58 3.17 315.66 626.46 3.45 -5.26570.26 6,031,079.54 469,840.56 2.50 2.51 MWD+IFR2+MS+sag (2) 671.26 4.30 316.56 671.04 5.55 -7.28614.84 6,031,081.64 469,838.55 2.53 4.24 MWD+IFR2+MS+sag (2) 9/22/2011 2:38:48PM COMPASS 2003.16 Build 42 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSK-13 ODSK-13PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSK-13PB2 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSK-13 - Slot ODS-13 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 763.81 6.86 316.45 763.14 12.08 -13.47706.94 6,031,088.19 469,832.39 2.77 9.63 MWD+IFR2+MS+sag (2) 813.54 8.01 316.35 812.46 16.74 -17.91756.26 6,031,092.87 469,827.97 2.31 13.47 MWD+IFR2+MS+sag (2) 860.24 8.60 315.98 858.67 21.61 -22.59802.47 6,031,097.76 469,823.31 1.27 17.48 MWD+IFR2+MS+sag (2) 909.76 9.51 313.90 907.57 27.11 -28.11851.37 6,031,103.28 469,817.82 1.95 21.96 MWD+IFR2+MS+sag (2) 956.78 9.35 312.67 953.95 32.39 -33.71897.75 6,031,108.58 469,812.23 0.55 26.22 MWD+IFR2+MS+sag (2) 1,005.95 9.18 310.28 1,002.48 37.63 -39.64946.28 6,031,113.85 469,806.32 0.86 30.39 MWD+IFR2+MS+sag (2) 1,049.84 11.17 311.64 1,045.68 42.72 -45.49989.48 6,031,118.96 469,800.50 4.57 34.42 MWD+IFR2+MS+sag (2) 1,096.33 13.93 309.80 1,091.05 49.29 -53.161,034.85 6,031,125.56 469,792.86 6.00 39.60 MWD+IFR2+MS+sag (2) 1,145.56 15.24 312.60 1,138.70 57.47 -62.471,082.50 6,031,133.77 469,783.58 3.02 46.08 MWD+IFR2+MS+sag (2) 1,194.22 15.31 310.88 1,185.64 66.00 -72.041,129.44 6,031,142.35 469,774.05 0.94 52.88 MWD+IFR2+MS+sag (2) 1,240.56 16.78 310.92 1,230.17 74.39 -81.721,173.97 6,031,150.77 469,764.40 3.17 59.51 MWD+IFR2+MS+sag (2) 1,289.96 18.95 309.46 1,277.19 84.16 -93.301,220.99 6,031,160.59 469,752.86 4.48 67.18 MWD+IFR2+MS+sag (2) 1,336.79 20.72 308.92 1,321.24 94.19 -105.621,265.04 6,031,170.67 469,740.59 3.80 74.99 MWD+IFR2+MS+sag (2) 1,384.42 22.51 306.84 1,365.52 104.96 -119.471,309.32 6,031,181.49 469,726.78 4.09 83.25 MWD+IFR2+MS+sag (2) 1,430.42 23.07 305.99 1,407.93 115.53 -133.811,351.73 6,031,192.12 469,712.48 1.41 91.25 MWD+IFR2+MS+sag (2) 1,479.83 23.39 304.58 1,453.33 126.79 -149.721,397.13 6,031,203.44 469,696.62 1.30 99.66 MWD+IFR2+MS+sag (2) 1,525.32 23.94 305.15 1,494.99 137.23 -164.701,438.79 6,031,213.94 469,681.68 1.31 107.42 MWD+IFR2+MS+sag (2) 1,576.16 24.01 305.92 1,541.45 149.23 -181.511,485.25 6,031,226.01 469,664.92 0.63 116.41 MWD+IFR2+MS+sag (2) 1,621.34 24.33 306.96 1,582.67 160.22 -196.391,526.47 6,031,237.06 469,650.09 1.18 124.72 MWD+IFR2+MS+sag (2) 1,671.07 25.79 307.41 1,627.72 172.95 -213.171,571.52 6,031,249.86 469,633.36 2.96 134.44 MWD+IFR2+MS+sag (2) 1,705.60 25.58 308.15 1,658.83 182.12 -225.001,602.63 6,031,259.07 469,621.57 1.11 141.47 MWD+IFR2+MS+sag (2) 1,766.84 25.73 308.07 1,714.04 198.48 -245.861,657.84 6,031,275.52 469,600.78 0.25 154.08 MWD+IFR2+MS+sag (2) 1,811.68 25.57 310.02 1,754.46 210.71 -260.931,698.26 6,031,287.80 469,585.76 1.92 163.58 MWD+IFR2+MS+sag (2) 1,862.23 25.52 312.44 1,800.07 225.07 -277.331,743.87 6,031,302.23 469,569.43 2.07 174.96 MWD+IFR2+MS+sag (2) 1,907.09 25.51 313.53 1,840.55 238.25 -291.461,784.35 6,031,315.46 469,555.35 1.05 185.56 MWD+IFR2+MS+sag (2) 1,958.99 26.92 315.00 1,887.11 254.25 -307.871,830.91 6,031,331.53 469,539.00 2.99 198.56 MWD+IFR2+MS+sag (2) 2,001.97 27.61 317.15 1,925.32 268.43 -321.531,869.12 6,031,345.77 469,525.41 2.80 210.23 MWD+IFR2+MS+sag (2) 2,097.12 28.74 323.48 2,009.21 302.99 -350.141,953.01 6,031,380.44 469,496.94 3.36 239.46 MWD+IFR2+MS+sag (2) 2,192.69 29.36 331.16 2,092.79 341.99 -375.132,036.59 6,031,419.54 469,472.11 3.95 273.68 MWD+IFR2+MS+sag (2) 2,241.25 29.14 334.14 2,135.16 363.06 -386.022,078.96 6,031,440.65 469,461.30 3.03 292.60 MWD+IFR2+MS+sag (2) 2,287.81 29.36 334.80 2,175.78 383.59 -395.832,119.58 6,031,461.22 469,451.58 0.84 311.18 MWD+IFR2+MS+sag (2) 2,383.06 33.63 338.04 2,256.99 429.21 -415.652,200.79 6,031,506.91 469,431.95 4.82 352.79 MWD+IFR2+MS+sag (2) 2,477.86 36.61 342.39 2,334.53 480.52 -434.022,278.33 6,031,558.28 469,413.78 4.10 400.25 MWD+IFR2+MS+sag (2) 2,530.79 38.32 345.12 2,376.55 511.42 -443.012,320.35 6,031,589.22 469,404.92 4.50 429.19 MWD+IFR2+MS+sag (2) 2,572.80 40.97 347.17 2,408.89 537.44 -449.422,352.69 6,031,615.27 469,398.62 7.03 453.76 MWD+IFR2+MS+sag (2) 2,619.68 42.07 349.45 2,444.00 567.87 -455.702,387.80 6,031,645.72 469,392.46 3.99 482.69 MWD+IFR2+MS+sag (2) 2,668.18 44.23 350.62 2,479.38 600.54 -461.442,423.18 6,031,678.41 469,386.86 4.75 513.91 MWD+IFR2+MS+sag (2) 2,763.56 46.77 352.08 2,546.23 667.79 -471.652,490.03 6,031,745.69 469,376.92 2.88 578.47 MWD+IFR2+MS+sag (2) 2,857.18 49.32 354.88 2,608.82 736.95 -479.522,552.62 6,031,814.87 469,369.33 3.52 645.30 MWD+IFR2+MS+sag (2) 2,953.56 52.79 357.15 2,669.40 811.71 -484.692,613.20 6,031,889.64 469,364.47 4.04 718.11 MWD+IFR2+MS+sag (2) 9/22/2011 2:38:48PM COMPASS 2003.16 Build 42 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSK-13 ODSK-13PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSK-13PB2 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSK-13 - Slot ODS-13 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 3,048.04 54.50 358.46 2,725.40 887.74 -487.592,669.20 6,031,965.68 469,361.87 2.13 792.56 MWD+IFR2+MS+sag (2) 3,143.06 57.30 358.73 2,778.67 966.39 -489.522,722.47 6,032,044.33 469,360.26 2.96 869.75 MWD+IFR2+MS+sag (2) 3,239.01 61.30 359.87 2,827.65 1,048.87 -490.512,771.45 6,032,126.80 469,359.61 4.29 950.88 MWD+IFR2+MS+sag (2) 3,332.55 64.45 1.07 2,870.29 1,132.10 -489.822,814.09 6,032,210.02 469,360.64 3.56 1,033.03 MWD+IFR2+MS+sag (2) 3,429.23 64.20 1.45 2,912.18 1,219.21 -487.902,855.98 6,032,297.12 469,362.91 0.44 1,119.22 MWD+IFR2+MS+sag (2) 3,468.28 63.59 2.08 2,929.36 1,254.26 -486.822,873.16 6,032,332.16 469,364.13 2.13 1,153.95 MWD+IFR2+MS+sag (2) 3,512.00 63.49 2.41 2,948.84 1,293.37 -485.292,892.64 6,032,371.26 469,365.82 0.71 1,192.75 MWD+IFR2+MS+sag (3) 3,555.33 62.03 1.18 2,968.67 1,331.88 -484.082,912.47 6,032,409.76 469,367.19 4.21 1,230.91 MWD+IFR2+MS+sag (3) 3,616.51 64.15 2.52 2,996.36 1,386.40 -482.312,940.16 6,032,464.26 469,369.17 3.98 1,284.94 MWD+IFR2+MS+sag (3) 3,665.79 64.07 1.46 3,017.88 1,430.71 -480.772,961.68 6,032,508.56 469,370.89 1.94 1,328.87 MWD+IFR2+MS+sag (3) 3,712.23 63.29 1.97 3,038.47 1,472.31 -479.532,982.27 6,032,550.16 469,372.31 1.95 1,370.09 MWD+IFR2+MS+sag (3) 3,807.59 63.18 1.37 3,081.42 1,557.42 -477.053,025.22 6,032,635.24 469,375.13 0.57 1,454.39 MWD+IFR2+MS+sag (3) 3,902.42 63.18 1.51 3,124.20 1,642.02 -474.923,068.00 6,032,719.83 469,377.60 0.13 1,538.14 MWD+IFR2+MS+sag (3) 3,997.88 62.71 0.22 3,167.62 1,727.02 -473.633,111.42 6,032,804.81 469,379.23 1.30 1,622.13 MWD+IFR2+MS+sag (3) 4,093.20 62.04 359.94 3,211.82 1,811.48 -473.513,155.62 6,032,889.26 469,379.69 0.75 1,705.39 MWD+IFR2+MS+sag (3) 4,188.14 63.53 0.20 3,255.24 1,895.90 -473.413,199.04 6,032,973.68 469,380.14 1.59 1,788.62 MWD+IFR2+MS+sag (3) 4,249.10 63.12 0.16 3,282.61 1,950.37 -473.243,226.41 6,033,028.14 469,380.53 0.68 1,842.34 MWD+IFR2+MS+sag (4) 4,342.75 62.39 1.86 3,325.48 2,033.62 -471.783,269.28 6,033,111.37 469,382.33 1.79 1,924.63 MWD+IFR2+MS+sag (4) 4,439.42 63.41 7.57 3,369.55 2,119.33 -464.693,313.35 6,033,197.04 469,389.77 5.36 2,010.31 MWD+IFR2+MS+sag (4) 4,534.56 63.63 10.80 3,411.98 2,203.38 -451.093,355.78 6,033,281.03 469,403.70 3.05 2,095.45 MWD+IFR2+MS+sag (4) 4,629.62 63.38 14.09 3,454.39 2,286.44 -432.773,398.19 6,033,364.01 469,422.37 3.11 2,180.41 MWD+IFR2+MS+sag (4) 4,721.64 63.48 17.57 3,495.56 2,365.60 -410.323,439.36 6,033,443.07 469,445.13 3.38 2,262.23 MWD+IFR2+MS+sag (4) 4,818.91 63.26 20.75 3,539.17 2,447.73 -381.793,482.97 6,033,525.07 469,473.99 2.93 2,347.99 MWD+IFR2+MS+sag (4) 4,911.96 63.66 24.62 3,580.76 2,524.51 -349.693,524.56 6,033,601.71 469,506.40 3.75 2,429.09 MWD+IFR2+MS+sag (4) 5,007.94 63.69 27.95 3,623.33 2,601.62 -311.603,567.13 6,033,678.66 469,544.80 3.11 2,511.54 MWD+IFR2+MS+sag (4) 5,103.05 63.87 30.03 3,665.36 2,676.25 -270.253,609.16 6,033,753.11 469,586.45 1.97 2,592.08 MWD+IFR2+MS+sag (4) 5,198.48 63.74 31.88 3,707.49 2,749.68 -226.213,651.29 6,033,826.36 469,630.78 1.74 2,671.89 MWD+IFR2+MS+sag (4) 5,293.95 64.38 34.93 3,749.26 2,821.33 -178.943,693.06 6,033,897.81 469,678.33 2.95 2,750.51 MWD+IFR2+MS+sag (4) 5,388.05 64.77 37.53 3,789.66 2,889.88 -128.723,733.46 6,033,966.14 469,728.83 2.53 2,826.55 MWD+IFR2+MS+sag (4) 5,483.36 65.50 39.43 3,829.74 2,957.56 -74.913,773.54 6,034,033.61 469,782.90 1.96 2,902.36 MWD+IFR2+MS+sag (4) 5,579.29 66.01 42.51 3,869.14 3,023.59 -17.573,812.94 6,034,099.40 469,840.51 2.98 2,977.13 MWD+IFR2+MS+sag (4) 5,673.51 65.72 44.70 3,907.67 3,085.85 41.733,851.47 6,034,161.41 469,900.05 2.14 3,048.51 MWD+IFR2+MS+sag (4) 5,768.88 65.19 47.30 3,947.29 3,146.11 104.123,891.09 6,034,221.41 469,962.68 2.54 3,118.45 MWD+IFR2+MS+sag (4) 5,863.95 66.34 49.90 3,986.32 3,203.43 169.153,930.12 6,034,278.45 470,027.93 2.77 3,185.93 MWD+IFR2+MS+sag (4) 5,959.06 67.46 51.77 4,023.64 3,258.67 236.983,967.44 6,034,333.41 470,095.98 2.16 3,251.84 MWD+IFR2+MS+sag (4) 6,054.68 67.35 52.31 4,060.38 3,312.97 306.584,004.18 6,034,387.43 470,165.79 0.53 3,317.13 MWD+IFR2+MS+sag (4) 6,149.01 67.62 52.84 4,096.50 3,365.93 375.784,040.30 6,034,440.10 470,235.20 0.59 3,381.02 MWD+IFR2+MS+sag (4) 6,244.58 67.61 52.94 4,132.90 3,419.24 446.254,076.70 6,034,493.12 470,305.88 0.10 3,445.48 MWD+IFR2+MS+sag (4) 6,339.78 67.33 52.56 4,169.37 3,472.47 516.254,113.17 6,034,546.06 470,376.09 0.47 3,509.77 MWD+IFR2+MS+sag (4) 6,433.33 67.79 51.93 4,205.08 3,525.41 584.614,148.88 6,034,598.72 470,444.66 0.79 3,573.50 MWD+IFR2+MS+sag (4) 9/22/2011 2:38:48PM COMPASS 2003.16 Build 42 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSK-13 ODSK-13PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSK-13PB2 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSK-13 - Slot ODS-13 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 6,499.89 68.02 51.58 4,230.12 3,563.59 633.054,173.92 6,034,636.69 470,493.24 0.60 3,619.32 MWD+IFR2+MS+sag (4) 6,529.96 67.69 51.89 4,241.46 3,580.84 654.914,185.26 6,034,653.85 470,515.18 1.45 3,640.01 MWD+IFR2+MS+sag (4) 6,625.13 66.73 51.49 4,278.32 3,635.23 723.764,222.12 6,034,707.96 470,584.24 1.08 3,705.25 MWD+IFR2+MS+sag (4) 6,720.41 67.39 51.27 4,315.46 3,689.99 792.324,259.26 6,034,762.44 470,653.01 0.72 3,770.82 MWD+IFR2+MS+sag (4) 6,813.96 67.62 51.79 4,351.25 3,743.76 859.994,295.05 6,034,815.93 470,720.89 0.57 3,835.25 MWD+IFR2+MS+sag (4) 6,910.56 67.95 51.12 4,387.77 3,799.49 929.934,331.57 6,034,871.36 470,791.05 0.73 3,902.00 MWD+IFR2+MS+sag (4) 7,005.87 67.72 50.71 4,423.73 3,855.14 998.444,367.53 6,034,926.73 470,859.78 0.47 3,968.42 MWD+IFR2+MS+sag (4) 7,099.81 67.81 50.30 4,459.28 3,910.44 1,065.544,403.08 6,034,981.75 470,927.10 0.42 4,034.27 MWD+IFR2+MS+sag (4) 7,194.84 67.46 49.70 4,495.44 3,966.93 1,132.874,439.24 6,035,037.96 470,994.64 0.69 4,101.33 MWD+IFR2+MS+sag (4) 7,290.27 66.41 47.24 4,532.83 4,025.13 1,198.594,476.63 6,035,095.89 471,060.60 2.61 4,169.80 MWD+IFR2+MS+sag (4) 7,385.79 65.53 45.76 4,571.73 4,085.18 1,261.874,515.53 6,035,155.68 471,124.12 1.69 4,239.68 MWD+IFR2+MS+sag (4) 7,480.76 64.78 43.46 4,611.64 4,146.52 1,322.394,555.44 6,035,216.77 471,184.88 2.34 4,310.37 MWD+IFR2+MS+sag (4) 7,577.09 64.17 41.66 4,653.15 4,210.54 1,381.194,596.95 6,035,280.54 471,243.93 1.80 4,383.40 MWD+IFR2+MS+sag (4) 7,671.10 62.47 40.38 4,695.36 4,273.91 1,436.324,639.16 6,035,343.68 471,299.31 2.18 4,455.18 MWD+IFR2+MS+sag (4) 7,766.33 61.94 38.93 4,739.77 4,338.77 1,490.084,683.57 6,035,408.31 471,353.33 1.46 4,528.19 MWD+IFR2+MS+sag (4) 7,862.27 61.80 36.99 4,785.00 4,405.47 1,542.124,728.80 6,035,474.79 471,405.63 1.79 4,602.72 MWD+IFR2+MS+sag (4) 7,957.08 61.46 34.26 4,830.06 4,473.27 1,590.714,773.86 6,035,542.39 471,454.49 2.56 4,677.76 MWD+IFR2+MS+sag (4) 8,052.55 59.95 31.28 4,876.78 4,543.26 1,635.784,820.58 6,035,612.18 471,499.84 3.15 4,754.36 MWD+IFR2+MS+sag (4) 8,148.21 59.28 28.61 4,925.17 4,614.75 1,676.974,868.97 6,035,683.50 471,541.32 2.51 4,831.78 MWD+IFR2+MS+sag (4) 8,241.73 59.42 26.12 4,972.85 4,686.19 1,713.954,916.65 6,035,754.79 471,578.58 2.30 4,908.45 MWD+IFR2+MS+sag (4) 8,336.89 58.89 23.40 5,021.65 4,760.37 1,748.174,965.45 6,035,828.82 471,613.09 2.52 4,987.34 MWD+IFR2+MS+sag (4) 8,432.34 58.45 20.01 5,071.29 4,836.10 1,778.325,015.09 6,035,904.42 471,643.55 3.07 5,067.08 MWD+IFR2+MS+sag (4) 8,527.43 58.16 16.73 5,121.26 4,912.87 1,803.815,065.06 6,035,981.07 471,669.35 2.95 5,147.05 MWD+IFR2+MS+sag (4) 8,622.99 58.31 13.78 5,171.58 4,991.24 1,825.195,115.38 6,036,059.35 471,691.04 2.63 5,227.90 MWD+IFR2+MS+sag (4) 8,718.51 58.61 9.62 5,221.56 5,070.93 1,841.685,165.36 6,036,138.96 471,707.86 3.72 5,309.24 MWD+IFR2+MS+sag (4) 8,812.82 57.91 5.46 5,271.19 5,150.41 1,852.225,214.99 6,036,218.40 471,718.71 3.82 5,389.36 MWD+IFR2+MS+sag (4) 8,908.88 57.88 1.43 5,322.25 5,231.61 1,857.105,266.05 6,036,299.56 471,723.93 3.55 5,470.21 MWD+IFR2+MS+sag (4) 9,003.97 57.75 357.12 5,372.92 5,312.05 1,856.095,316.72 6,036,380.00 471,723.24 3.84 5,549.33 MWD+IFR2+MS+sag (4) 9,067.50 57.73 356.42 5,406.83 5,365.69 1,853.065,350.63 6,036,433.65 471,720.43 0.93 5,601.68 MWD+IFR2+MS+sag (4) 9,140.14 57.10 357.11 5,445.95 5,426.79 1,849.615,389.75 6,036,494.76 471,717.23 1.18 5,661.32 MWD+IFR2+MS+sag (5) 9,238.01 57.06 357.02 5,499.14 5,508.84 1,845.405,442.94 6,036,576.82 471,713.35 0.09 5,741.48 MWD+IFR2+MS+sag (5) 9,332.85 56.89 357.65 5,550.83 5,588.27 1,841.705,494.63 6,036,656.25 471,709.98 0.59 5,819.14 MWD+IFR2+MS+sag (5) 9,427.64 57.43 358.35 5,602.23 5,667.86 1,838.925,546.03 6,036,735.85 471,707.52 0.84 5,897.12 MWD+IFR2+MS+sag (5) 9,522.32 57.95 357.95 5,652.84 5,747.84 1,836.345,596.64 6,036,815.83 471,705.26 0.66 5,975.51 MWD+IFR2+MS+sag (5) 9,617.97 58.03 355.52 5,703.55 5,828.81 1,831.725,647.35 6,036,896.80 471,700.97 2.16 6,054.53 MWD+IFR2+MS+sag (5) 9,713.40 58.94 353.21 5,753.43 5,909.76 1,823.725,697.23 6,036,977.78 471,693.31 2.27 6,132.97 MWD+IFR2+MS+sag (5) 9,808.56 57.66 350.42 5,803.44 5,989.89 1,812.215,747.24 6,037,057.94 471,682.12 2.83 6,210.00 MWD+IFR2+MS+sag (5) 9,903.97 55.71 347.52 5,855.85 6,068.13 1,796.985,799.65 6,037,136.24 471,667.21 3.26 6,284.54 MWD+IFR2+MS+sag (5) 9,998.95 56.56 344.86 5,908.79 6,144.70 1,778.155,852.59 6,037,212.88 471,648.69 2.49 6,356.83 MWD+IFR2+MS+sag (5) 10,094.87 56.93 342.38 5,961.39 6,221.65 1,755.535,905.19 6,037,289.91 471,626.39 2.20 6,428.85 MWD+IFR2+MS+sag (5) 9/22/2011 2:38:48PM COMPASS 2003.16 Build 42 Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSK-13 ODSK-13PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSK-13PB2 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSK-13 - Slot ODS-13 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 10,190.51 58.17 339.71 6,012.71 6,297.96 1,729.315,956.51 6,037,366.32 471,600.48 2.69 6,499.63 MWD+IFR2+MS+sag (5) 10,285.77 57.44 337.82 6,063.47 6,373.10 1,700.126,007.27 6,037,441.57 471,571.59 1.85 6,568.75 MWD+IFR2+MS+sag (5) 10,380.99 57.29 334.94 6,114.83 6,446.56 1,668.006,058.63 6,037,515.15 471,539.77 2.55 6,635.72 MWD+IFR2+MS+sag (5) 10,474.77 57.27 331.94 6,165.53 6,517.12 1,632.726,109.33 6,037,585.84 471,504.79 2.69 6,699.31 MWD+IFR2+MS+sag (5) 10,569.76 55.53 327.60 6,218.11 6,585.46 1,592.936,161.91 6,037,654.34 471,465.28 4.22 6,759.95 MWD+IFR2+MS+sag (5) 10,665.10 55.14 325.51 6,272.34 6,650.89 1,549.726,216.14 6,037,719.94 471,422.34 1.85 6,817.13 MWD+IFR2+MS+sag (5) 10,759.82 53.90 324.84 6,327.32 6,714.21 1,505.686,271.12 6,037,783.43 471,378.56 1.43 6,872.09 MWD+IFR2+MS+sag (5) 10,855.66 52.88 326.07 6,384.48 6,777.57 1,462.056,328.28 6,037,846.96 471,335.19 1.48 6,927.17 MWD+IFR2+MS+sag (5) 10,950.39 52.36 326.67 6,441.99 6,840.24 1,420.366,385.79 6,037,909.80 471,293.76 0.74 6,981.90 MWD+IFR2+MS+sag (5) 11,045.38 50.08 326.61 6,501.48 6,902.09 1,379.646,445.28 6,037,971.80 471,253.30 2.40 7,035.97 MWD+IFR2+MS+sag (5) 11,140.31 48.21 327.22 6,563.57 6,962.24 1,340.456,507.37 6,038,032.11 471,214.35 2.03 7,088.63 MWD+IFR2+MS+sag (5) 11,187.00 48.21 327.22 6,594.69 6,991.51 1,321.606,538.49 6,038,061.45 471,195.62 0.00 7,114.30 PROJECTED to TD 9/22/2011 2:38:48PM COMPASS 2003.16 Build 42 Page 6 22 September, 2011 Oooguruk Development Oooguruk Drill Site ODSK-13 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSK-13 ODSK-13 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSK-13 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSK-13 - Slot ODS-13 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Oooguruk Development Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: ft +E/-W +N/-S Position Uncertainty ft ft ftGround Level: ODSK-13 - Slot ODS-13 ft ft 0.00 0.00 6,031,076.06 469,845.81 13.50Wellhead Elevation:ft0.00 70° 29' 45.498 N 150° 14' 47.653 W Wellbore Declination (?) Field Strength (nT) Sample Date Dip Angle (?) ODSK-13 Model NameMagnetics User Defined 7/27/2011 20.82 80.97 57,639 Phase:Version: Audit Notes: Design ODSK-13 1.0 ACTUAL Vertical Section: Depth From (TVD) (ft) +N/-S (ft) Direction (?) +E/-W (ft) Tie On Depth:9,067.50 349.420.000.0042.70 From (ft) Survey Program DescriptionTool NameSurvey (Wellbore) To (ft) Date 9/22/2011 Survey Start Date SR-Gyro-SS Fixed:v2:surface readout gyro single shot100.00 532.00 ODSK-13 Gyro (ODSK-13PB1)01/04/2010 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag573.71 3,468.28 ODSK-13 MWD (ODSK-13PB1)01/04/2010 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag3,512.00 4,188.14 ODSK-13PB2 MWD Run 600 (ODSK-13 08/11/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag4,249.10 9,067.50 ODSK-13PB2 MWD Run 700 (ODSK-13 08/25/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag9,098.00 11,397.45 ODSK-13 MWD Run 1100 (ODSK-13)08/30/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag11,459.07 14,447.61 ODSK-13 MWD Run 1300 (ODSK-13)09/22/2011 MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 42.70 0.00 0.00 42.70 0.00 0.00-13.50 6,031,076.06 469,845.81 0.00 0.00 UNDEFINED 100.00 0.34 221.19 100.00 -0.13 -0.1143.80 6,031,075.93 469,845.70 0.59 -0.11 SR-Gyro-SS (1) 168.00 0.16 130.95 168.00 -0.34 -0.17111.80 6,031,075.72 469,845.63 0.55 -0.30 SR-Gyro-SS (1) 259.00 0.70 164.84 259.00 -0.96 0.07202.80 6,031,075.10 469,845.87 0.63 -0.96 SR-Gyro-SS (1) 350.00 0.37 253.30 349.99 -1.58 -0.07293.79 6,031,074.48 469,845.73 0.86 -1.54 SR-Gyro-SS (1) 441.00 1.19 307.31 440.99 -1.09 -1.10384.79 6,031,074.97 469,844.70 1.12 -0.87 SR-Gyro-SS (1) 532.00 1.95 322.83 531.95 0.71 -2.79475.75 6,031,076.78 469,843.02 0.95 1.21 SR-Gyro-SS (1) 573.71 1.85 317.80 573.64 1.78 -3.67517.44 6,031,077.85 469,842.15 0.47 2.42 MWD+IFR2+MS+sag (2) 626.58 3.17 315.66 626.46 3.45 -5.26570.26 6,031,079.54 469,840.56 2.50 4.36 MWD+IFR2+MS+sag (2) 671.26 4.30 316.56 671.04 5.55 -7.28614.84 6,031,081.64 469,838.55 2.53 6.80 MWD+IFR2+MS+sag (2) 9/22/2011 2:59:36PM COMPASS 2003.16 Build 42 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSK-13 ODSK-13 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSK-13 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSK-13 - Slot ODS-13 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 763.81 6.86 316.45 763.14 12.08 -13.47706.94 6,031,088.19 469,832.39 2.77 14.35 MWD+IFR2+MS+sag (2) 813.54 8.01 316.35 812.46 16.74 -17.91756.26 6,031,092.87 469,827.97 2.31 19.74 MWD+IFR2+MS+sag (2) 860.24 8.60 315.98 858.67 21.61 -22.59802.47 6,031,097.76 469,823.31 1.27 25.38 MWD+IFR2+MS+sag (2) 909.76 9.51 313.90 907.57 27.11 -28.11851.37 6,031,103.28 469,817.82 1.95 31.80 MWD+IFR2+MS+sag (2) 956.78 9.35 312.67 953.95 32.39 -33.71897.75 6,031,108.58 469,812.23 0.55 38.03 MWD+IFR2+MS+sag (2) 1,005.95 9.18 310.28 1,002.48 37.63 -39.64946.28 6,031,113.85 469,806.32 0.86 44.27 MWD+IFR2+MS+sag (2) 1,049.84 11.17 311.64 1,045.68 42.72 -45.49989.48 6,031,118.96 469,800.50 4.57 50.34 MWD+IFR2+MS+sag (2) 1,096.33 13.93 309.80 1,091.05 49.29 -53.161,034.85 6,031,125.56 469,792.86 6.00 58.22 MWD+IFR2+MS+sag (2) 1,145.56 15.24 312.60 1,138.70 57.47 -62.471,082.50 6,031,133.77 469,783.58 3.02 67.96 MWD+IFR2+MS+sag (2) 1,194.22 15.31 310.88 1,185.64 66.00 -72.041,129.44 6,031,142.35 469,774.05 0.94 78.10 MWD+IFR2+MS+sag (2) 1,240.56 16.78 310.92 1,230.17 74.39 -81.721,173.97 6,031,150.77 469,764.40 3.17 88.13 MWD+IFR2+MS+sag (2) 1,289.96 18.95 309.46 1,277.19 84.16 -93.301,220.99 6,031,160.59 469,752.86 4.48 99.86 MWD+IFR2+MS+sag (2) 1,336.79 20.72 308.92 1,321.24 94.19 -105.621,265.04 6,031,170.67 469,740.59 3.80 111.98 MWD+IFR2+MS+sag (2) 1,384.42 22.51 306.84 1,365.52 104.96 -119.471,309.32 6,031,181.49 469,726.78 4.09 125.11 MWD+IFR2+MS+sag (2) 1,430.42 23.07 305.99 1,407.93 115.53 -133.811,351.73 6,031,192.12 469,712.48 1.41 138.14 MWD+IFR2+MS+sag (2) 1,479.83 23.39 304.58 1,453.33 126.79 -149.721,397.13 6,031,203.44 469,696.62 1.30 152.12 MWD+IFR2+MS+sag (2) 1,525.32 23.94 305.15 1,494.99 137.23 -164.701,438.79 6,031,213.94 469,681.68 1.31 165.13 MWD+IFR2+MS+sag (2) 1,576.16 24.01 305.92 1,541.45 149.23 -181.511,485.25 6,031,226.01 469,664.92 0.63 180.02 MWD+IFR2+MS+sag (2) 1,621.34 24.33 306.96 1,582.67 160.22 -196.391,526.47 6,031,237.06 469,650.09 1.18 193.55 MWD+IFR2+MS+sag (2) 1,671.07 25.79 307.41 1,627.72 172.95 -213.171,571.52 6,031,249.86 469,633.36 2.96 209.15 MWD+IFR2+MS+sag (2) 1,705.60 25.58 308.15 1,658.83 182.12 -225.001,602.63 6,031,259.07 469,621.57 1.11 220.34 MWD+IFR2+MS+sag (2) 1,766.84 25.73 308.07 1,714.04 198.48 -245.861,657.84 6,031,275.52 469,600.78 0.25 240.25 MWD+IFR2+MS+sag (2) 1,811.68 25.57 310.02 1,754.46 210.71 -260.931,698.26 6,031,287.80 469,585.76 1.92 255.04 MWD+IFR2+MS+sag (2) 1,862.23 25.52 312.44 1,800.07 225.07 -277.331,743.87 6,031,302.23 469,569.43 2.07 272.16 MWD+IFR2+MS+sag (2) 1,907.09 25.51 313.53 1,840.55 238.25 -291.461,784.35 6,031,315.46 469,555.35 1.05 287.71 MWD+IFR2+MS+sag (2) 1,958.99 26.92 315.00 1,887.11 254.25 -307.871,830.91 6,031,331.53 469,539.00 2.99 306.46 MWD+IFR2+MS+sag (2) 2,001.97 27.61 317.15 1,925.32 268.43 -321.531,869.12 6,031,345.77 469,525.41 2.80 322.90 MWD+IFR2+MS+sag (2) 2,097.12 28.74 323.48 2,009.21 302.99 -350.141,953.01 6,031,380.44 469,496.94 3.36 362.13 MWD+IFR2+MS+sag (2) 2,192.69 29.36 331.16 2,092.79 341.99 -375.132,036.59 6,031,419.54 469,472.11 3.95 405.06 MWD+IFR2+MS+sag (2) 2,241.25 29.14 334.14 2,135.16 363.06 -386.022,078.96 6,031,440.65 469,461.30 3.03 427.77 MWD+IFR2+MS+sag (2) 2,287.81 29.36 334.80 2,175.78 383.59 -395.832,119.58 6,031,461.22 469,451.58 0.84 449.75 MWD+IFR2+MS+sag (2) 2,383.06 33.63 338.04 2,256.99 429.21 -415.652,200.79 6,031,506.91 469,431.95 4.82 498.22 MWD+IFR2+MS+sag (2) 2,477.86 36.61 342.39 2,334.53 480.52 -434.022,278.33 6,031,558.28 469,413.78 4.10 552.04 MWD+IFR2+MS+sag (2) 2,530.79 38.32 345.12 2,376.55 511.42 -443.012,320.35 6,031,589.22 469,404.92 4.50 584.07 MWD+IFR2+MS+sag (2) 2,572.80 40.97 347.17 2,408.89 537.44 -449.422,352.69 6,031,615.27 469,398.62 7.03 610.82 MWD+IFR2+MS+sag (2) 2,619.68 42.07 349.45 2,444.00 567.87 -455.702,387.80 6,031,645.72 469,392.46 3.99 641.89 MWD+IFR2+MS+sag (2) 2,668.18 44.23 350.62 2,479.38 600.54 -461.442,423.18 6,031,678.41 469,386.86 4.75 675.05 MWD+IFR2+MS+sag (2) 2,763.56 46.77 352.08 2,546.23 667.79 -471.652,490.03 6,031,745.69 469,376.92 2.88 743.03 MWD+IFR2+MS+sag (2) 2,857.18 49.32 354.88 2,608.82 736.95 -479.522,552.62 6,031,814.87 469,369.33 3.52 812.46 MWD+IFR2+MS+sag (2) 2,953.56 52.79 357.15 2,669.40 811.71 -484.692,613.20 6,031,889.64 469,364.47 4.04 886.90 MWD+IFR2+MS+sag (2) 9/22/2011 2:59:36PM COMPASS 2003.16 Build 42 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSK-13 ODSK-13 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSK-13 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSK-13 - Slot ODS-13 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 3,048.04 54.50 358.46 2,725.40 887.74 -487.592,669.20 6,031,965.68 469,361.87 2.13 962.17 MWD+IFR2+MS+sag (2) 3,143.06 57.30 358.73 2,778.67 966.39 -489.522,722.47 6,032,044.33 469,360.26 2.96 1,039.84 MWD+IFR2+MS+sag (2) 3,239.01 61.30 359.87 2,827.65 1,048.87 -490.512,771.45 6,032,126.80 469,359.61 4.29 1,121.10 MWD+IFR2+MS+sag (2) 3,332.55 64.45 1.07 2,870.29 1,132.10 -489.822,814.09 6,032,210.02 469,360.64 3.56 1,202.79 MWD+IFR2+MS+sag (2) 3,429.23 64.20 1.45 2,912.18 1,219.21 -487.902,855.98 6,032,297.12 469,362.91 0.44 1,288.07 MWD+IFR2+MS+sag (2) 3,468.28 63.59 2.08 2,929.36 1,254.26 -486.822,873.16 6,032,332.16 469,364.13 2.13 1,322.32 MWD+IFR2+MS+sag (2) 3,512.00 63.49 2.41 2,948.84 1,293.37 -485.292,892.64 6,032,371.26 469,365.82 0.71 1,360.49 MWD+IFR2+MS+sag (3) 3,555.33 62.03 1.18 2,968.67 1,331.88 -484.082,912.47 6,032,409.76 469,367.19 4.21 1,398.11 MWD+IFR2+MS+sag (3) 3,616.51 64.15 2.52 2,996.36 1,386.40 -482.312,940.16 6,032,464.26 469,369.17 3.98 1,451.39 MWD+IFR2+MS+sag (3) 3,665.79 64.07 1.46 3,017.88 1,430.71 -480.772,961.68 6,032,508.56 469,370.89 1.94 1,494.66 MWD+IFR2+MS+sag (3) 3,712.23 63.29 1.97 3,038.47 1,472.31 -479.532,982.27 6,032,550.16 469,372.31 1.95 1,535.33 MWD+IFR2+MS+sag (3) 3,807.59 63.18 1.37 3,081.42 1,557.42 -477.053,025.22 6,032,635.24 469,375.13 0.57 1,618.53 MWD+IFR2+MS+sag (3) 3,902.42 63.18 1.51 3,124.20 1,642.02 -474.923,068.00 6,032,719.83 469,377.60 0.13 1,701.30 MWD+IFR2+MS+sag (3) 3,997.88 62.71 0.22 3,167.62 1,727.02 -473.633,111.42 6,032,804.81 469,379.23 1.30 1,784.62 MWD+IFR2+MS+sag (3) 4,093.20 62.04 359.94 3,211.82 1,811.48 -473.513,155.62 6,032,889.26 469,379.69 0.75 1,867.62 MWD+IFR2+MS+sag (3) 4,188.14 63.53 0.20 3,255.24 1,895.90 -473.413,199.04 6,032,973.68 469,380.14 1.59 1,950.59 MWD+IFR2+MS+sag (3) 4,249.10 63.12 0.16 3,282.61 1,950.37 -473.243,226.41 6,033,028.14 469,380.53 0.68 2,004.11 MWD+IFR2+MS+sag (4) 4,342.75 62.39 1.86 3,325.48 2,033.62 -471.783,269.28 6,033,111.37 469,382.33 1.79 2,085.67 MWD+IFR2+MS+sag (4) 4,439.42 63.41 7.57 3,369.55 2,119.33 -464.693,313.35 6,033,197.04 469,389.77 5.36 2,168.62 MWD+IFR2+MS+sag (4) 4,534.56 63.63 10.80 3,411.98 2,203.38 -451.093,355.78 6,033,281.03 469,403.70 3.05 2,248.75 MWD+IFR2+MS+sag (4) 4,629.62 63.38 14.09 3,454.39 2,286.44 -432.773,398.19 6,033,364.01 469,422.37 3.11 2,327.03 MWD+IFR2+MS+sag (4) 4,721.64 63.48 17.57 3,495.56 2,365.60 -410.323,439.36 6,033,443.07 469,445.13 3.38 2,400.73 MWD+IFR2+MS+sag (4) 4,818.91 63.26 20.75 3,539.17 2,447.73 -381.793,482.97 6,033,525.07 469,473.99 2.93 2,476.21 MWD+IFR2+MS+sag (4) 4,911.96 63.66 24.62 3,580.76 2,524.51 -349.693,524.56 6,033,601.71 469,506.40 3.75 2,545.79 MWD+IFR2+MS+sag (4) 5,007.94 63.69 27.95 3,623.33 2,601.62 -311.603,567.13 6,033,678.66 469,544.80 3.11 2,614.61 MWD+IFR2+MS+sag (4) 5,103.05 63.87 30.03 3,665.36 2,676.25 -270.253,609.16 6,033,753.11 469,586.45 1.97 2,680.37 MWD+IFR2+MS+sag (4) 5,198.48 63.74 31.88 3,707.49 2,749.68 -226.213,651.29 6,033,826.36 469,630.78 1.74 2,744.47 MWD+IFR2+MS+sag (4) 5,293.95 64.38 34.93 3,749.26 2,821.33 -178.943,693.06 6,033,897.81 469,678.33 2.95 2,806.22 MWD+IFR2+MS+sag (4) 5,388.05 64.77 37.53 3,789.66 2,889.88 -128.723,733.46 6,033,966.14 469,728.83 2.53 2,864.38 MWD+IFR2+MS+sag (4) 5,483.36 65.50 39.43 3,829.74 2,957.56 -74.913,773.54 6,034,033.61 469,782.90 1.96 2,921.04 MWD+IFR2+MS+sag (4) 5,579.29 66.01 42.51 3,869.14 3,023.59 -17.573,812.94 6,034,099.40 469,840.51 2.98 2,975.42 MWD+IFR2+MS+sag (4) 5,673.51 65.72 44.70 3,907.67 3,085.85 41.733,851.47 6,034,161.41 469,900.05 2.14 3,025.73 MWD+IFR2+MS+sag (4) 5,768.88 65.19 47.30 3,947.29 3,146.11 104.123,891.09 6,034,221.41 469,962.68 2.54 3,073.51 MWD+IFR2+MS+sag (4) 5,863.95 66.34 49.90 3,986.32 3,203.43 169.153,930.12 6,034,278.45 470,027.93 2.77 3,117.91 MWD+IFR2+MS+sag (4) 5,959.06 67.46 51.77 4,023.64 3,258.67 236.983,967.44 6,034,333.41 470,095.98 2.16 3,159.76 MWD+IFR2+MS+sag (4) 6,054.68 67.35 52.31 4,060.38 3,312.97 306.584,004.18 6,034,387.43 470,165.79 0.53 3,200.36 MWD+IFR2+MS+sag (4) 6,149.01 67.62 52.84 4,096.50 3,365.93 375.784,040.30 6,034,440.10 470,235.20 0.59 3,239.71 MWD+IFR2+MS+sag (4) 6,244.58 67.61 52.94 4,132.90 3,419.24 446.254,076.70 6,034,493.12 470,305.88 0.10 3,279.18 MWD+IFR2+MS+sag (4) 6,339.78 67.33 52.56 4,169.37 3,472.47 516.254,113.17 6,034,546.06 470,376.09 0.47 3,318.65 MWD+IFR2+MS+sag (4) 6,433.33 67.79 51.93 4,205.08 3,525.41 584.614,148.88 6,034,598.72 470,444.66 0.79 3,358.14 MWD+IFR2+MS+sag (4) 9/22/2011 2:59:36PM COMPASS 2003.16 Build 42 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSK-13 ODSK-13 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSK-13 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSK-13 - Slot ODS-13 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 6,499.89 68.02 51.58 4,230.12 3,563.59 633.054,173.92 6,034,636.69 470,493.24 0.60 3,386.77 MWD+IFR2+MS+sag (4) 6,529.96 67.69 51.89 4,241.46 3,580.84 654.914,185.26 6,034,653.85 470,515.18 1.45 3,399.71 MWD+IFR2+MS+sag (4) 6,625.13 66.73 51.49 4,278.32 3,635.23 723.764,222.12 6,034,707.96 470,584.24 1.08 3,440.54 MWD+IFR2+MS+sag (4) 6,720.41 67.39 51.27 4,315.46 3,689.99 792.324,259.26 6,034,762.44 470,653.01 0.72 3,481.79 MWD+IFR2+MS+sag (4) 6,813.96 67.62 51.79 4,351.25 3,743.76 859.994,295.05 6,034,815.93 470,720.89 0.57 3,522.22 MWD+IFR2+MS+sag (4) 6,910.56 67.95 51.12 4,387.77 3,799.49 929.934,331.57 6,034,871.36 470,791.05 0.73 3,564.15 MWD+IFR2+MS+sag (4) 7,005.87 67.72 50.71 4,423.73 3,855.14 998.444,367.53 6,034,926.73 470,859.78 0.47 3,606.28 MWD+IFR2+MS+sag (4) 7,099.81 67.81 50.30 4,459.28 3,910.44 1,065.544,403.08 6,034,981.75 470,927.10 0.42 3,648.32 MWD+IFR2+MS+sag (4) 7,194.84 67.46 49.70 4,495.44 3,966.93 1,132.874,439.24 6,035,037.96 470,994.64 0.69 3,691.49 MWD+IFR2+MS+sag (4) 7,290.27 66.41 47.24 4,532.83 4,025.13 1,198.594,476.63 6,035,095.89 471,060.60 2.61 3,736.63 MWD+IFR2+MS+sag (4) 7,385.79 65.53 45.76 4,571.73 4,085.18 1,261.874,515.53 6,035,155.68 471,124.12 1.69 3,784.04 MWD+IFR2+MS+sag (4) 7,480.76 64.78 43.46 4,611.64 4,146.52 1,322.394,555.44 6,035,216.77 471,184.88 2.34 3,833.23 MWD+IFR2+MS+sag (4) 7,577.09 64.17 41.66 4,653.15 4,210.54 1,381.194,596.95 6,035,280.54 471,243.93 1.80 3,885.36 MWD+IFR2+MS+sag (4) 7,671.10 62.47 40.38 4,695.36 4,273.91 1,436.324,639.16 6,035,343.68 471,299.31 2.18 3,937.53 MWD+IFR2+MS+sag (4) 7,766.33 61.94 38.93 4,739.77 4,338.77 1,490.084,683.57 6,035,408.31 471,353.33 1.46 3,991.41 MWD+IFR2+MS+sag (4) 7,862.27 61.80 36.99 4,785.00 4,405.47 1,542.124,728.80 6,035,474.79 471,405.63 1.79 4,047.43 MWD+IFR2+MS+sag (4) 7,957.08 61.46 34.26 4,830.06 4,473.27 1,590.714,773.86 6,035,542.39 471,454.49 2.56 4,105.15 MWD+IFR2+MS+sag (4) 8,052.55 59.95 31.28 4,876.78 4,543.26 1,635.784,820.58 6,035,612.18 471,499.84 3.15 4,165.67 MWD+IFR2+MS+sag (4) 8,148.21 59.28 28.61 4,925.17 4,614.75 1,676.974,868.97 6,035,683.50 471,541.32 2.51 4,228.39 MWD+IFR2+MS+sag (4) 8,241.73 59.42 26.12 4,972.85 4,686.19 1,713.954,916.65 6,035,754.79 471,578.58 2.30 4,291.83 MWD+IFR2+MS+sag (4) 8,336.89 58.89 23.40 5,021.65 4,760.37 1,748.174,965.45 6,035,828.82 471,613.09 2.52 4,358.46 MWD+IFR2+MS+sag (4) 8,432.34 58.45 20.01 5,071.29 4,836.10 1,778.325,015.09 6,035,904.42 471,643.55 3.07 4,427.37 MWD+IFR2+MS+sag (4) 8,527.43 58.16 16.73 5,121.26 4,912.87 1,803.815,065.06 6,035,981.07 471,669.35 2.95 4,498.15 MWD+IFR2+MS+sag (4) 8,622.99 58.31 13.78 5,171.58 4,991.24 1,825.195,115.38 6,036,059.35 471,691.04 2.63 4,571.26 MWD+IFR2+MS+sag (4) 8,718.51 58.61 9.62 5,221.56 5,070.93 1,841.685,165.36 6,036,138.96 471,707.86 3.72 4,646.57 MWD+IFR2+MS+sag (4) 8,812.82 57.91 5.46 5,271.19 5,150.41 1,852.225,214.99 6,036,218.40 471,718.71 3.82 4,722.77 MWD+IFR2+MS+sag (4) 8,908.88 57.88 1.43 5,322.25 5,231.61 1,857.105,266.05 6,036,299.56 471,723.93 3.55 4,801.69 MWD+IFR2+MS+sag (4) 9,003.97 57.75 357.12 5,372.92 5,312.05 1,856.095,316.72 6,036,380.00 471,723.24 3.84 4,880.95 MWD+IFR2+MS+sag (4) 9,067.50 57.73 356.42 5,406.83 5,365.69 1,853.065,350.63 6,036,433.65 471,720.43 0.93 4,934.23 MWD+IFR2+MS+sag (4) 9,098.00 57.47 356.71 5,423.17 5,391.39 1,851.525,366.97 6,036,459.35 471,718.99 1.17 4,959.78 MWD+IFR2+MS+sag (5) 9,183.61 56.59 355.97 5,469.76 5,463.07 1,846.945,413.56 6,036,531.04 471,714.70 1.26 5,031.08 MWD+IFR2+MS+sag (5) 9,278.09 58.50 353.68 5,520.47 5,542.45 1,839.735,464.27 6,036,610.45 471,707.82 2.88 5,110.44 MWD+IFR2+MS+sag (5) 9,372.49 58.87 354.44 5,569.53 5,622.67 1,831.385,513.33 6,036,690.68 471,699.80 0.79 5,190.82 MWD+IFR2+MS+sag (5) 9,467.98 59.84 354.47 5,618.20 5,704.44 1,823.455,562.00 6,036,772.48 471,692.20 1.02 5,272.66 MWD+IFR2+MS+sag (5) 9,563.17 61.25 352.27 5,665.02 5,786.76 1,813.875,608.82 6,036,854.83 471,682.95 2.50 5,355.34 MWD+IFR2+MS+sag (5) 9,658.60 62.02 349.54 5,710.36 5,869.66 1,800.595,654.16 6,036,937.78 471,670.01 2.64 5,439.27 MWD+IFR2+MS+sag (5) 9,754.27 63.48 348.02 5,754.17 5,953.08 1,784.035,697.97 6,037,021.25 471,653.79 2.08 5,524.31 MWD+IFR2+MS+sag (5) 9,849.34 64.04 346.62 5,796.20 6,036.27 1,765.315,740.00 6,037,104.51 471,635.41 1.45 5,609.52 MWD+IFR2+MS+sag (5) 9,945.34 64.02 345.67 5,838.24 6,120.06 1,744.655,782.04 6,037,188.38 471,615.09 0.89 5,695.69 MWD+IFR2+MS+sag (5) 10,040.82 64.35 344.89 5,879.82 6,203.19 1,722.805,823.62 6,037,271.59 471,593.59 0.81 5,781.41 MWD+IFR2+MS+sag (5) 9/22/2011 2:59:36PM COMPASS 2003.16 Build 42 Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSK-13 ODSK-13 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSK-13 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSK-13 - Slot ODS-13 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 10,135.81 65.57 342.15 5,920.03 6,285.70 1,698.385,863.83 6,037,354.19 471,569.51 2.91 5,867.01 MWD+IFR2+MS+sag (5) 10,230.64 68.36 340.50 5,957.13 6,368.36 1,670.435,900.93 6,037,436.95 471,541.89 3.35 5,953.39 MWD+IFR2+MS+sag (5) 10,324.60 71.31 338.73 5,989.52 6,451.02 1,639.705,933.32 6,037,519.73 471,511.50 3.60 6,040.29 MWD+IFR2+MS+sag (5) 10,419.20 72.66 336.09 6,018.78 6,534.07 1,605.145,962.58 6,037,602.90 471,477.28 3.01 6,128.27 MWD+IFR2+MS+sag (5) 10,515.14 73.63 333.73 6,046.60 6,617.21 1,566.215,990.40 6,037,686.20 471,438.69 2.56 6,217.15 MWD+IFR2+MS+sag (5) 10,609.34 75.12 331.32 6,071.98 6,697.69 1,524.356,015.78 6,037,766.83 471,397.16 2.93 6,303.94 MWD+IFR2+MS+sag (5) 10,704.81 76.95 328.62 6,095.02 6,777.88 1,477.986,038.82 6,037,847.21 471,351.13 3.35 6,391.28 MWD+IFR2+MS+sag (5) 10,799.78 79.03 326.84 6,114.78 6,856.42 1,428.396,058.58 6,037,925.93 471,301.85 2.86 6,477.59 MWD+IFR2+MS+sag (5) 10,895.18 80.98 326.67 6,131.34 6,934.99 1,376.886,075.14 6,038,004.70 471,250.67 2.05 6,564.28 MWD+IFR2+MS+sag (5) 10,990.23 82.48 325.46 6,145.01 7,013.02 1,324.386,088.81 6,038,082.94 471,198.49 2.02 6,650.63 MWD+IFR2+MS+sag (5) 11,085.22 83.48 324.04 6,156.62 7,090.01 1,269.966,100.42 6,038,160.14 471,144.39 1.82 6,736.30 MWD+IFR2+MS+sag (5) 11,180.95 85.15 322.75 6,166.11 7,166.48 1,213.166,109.91 6,038,236.83 471,087.91 2.20 6,821.89 MWD+IFR2+MS+sag (5) 11,276.55 86.28 321.63 6,173.25 7,241.79 1,154.726,117.05 6,038,312.38 471,029.78 1.66 6,906.66 MWD+IFR2+MS+sag (5) 11,371.57 86.75 320.51 6,179.02 7,315.57 1,095.136,122.82 6,038,386.39 470,970.49 1.28 6,990.13 MWD+IFR2+MS+sag (5) 11,397.45 86.74 320.18 6,180.49 7,335.46 1,078.646,124.29 6,038,406.35 470,954.08 1.27 7,012.71 MWD+IFR2+MS+sag (5) 11,459.07 88.05 321.19 6,183.29 7,383.08 1,039.646,127.09 6,038,454.12 470,915.28 2.68 7,066.68 MWD+IFR2+MS+sag (6) 11,555.52 88.53 318.39 6,186.17 7,456.70 977.406,129.97 6,038,527.98 470,853.35 2.94 7,150.47 MWD+IFR2+MS+sag (6) 11,653.88 87.41 320.61 6,189.66 7,531.44 913.576,133.46 6,038,602.97 470,789.83 2.53 7,235.66 MWD+IFR2+MS+sag (6) 11,704.81 85.05 320.52 6,193.01 7,570.69 881.296,136.81 6,038,642.35 470,757.71 4.64 7,280.17 MWD+IFR2+MS+sag (6) 11,749.40 84.19 318.81 6,197.19 7,604.53 852.566,140.99 6,038,676.30 470,729.12 4.28 7,318.71 MWD+IFR2+MS+sag (6) 11,803.91 85.76 319.40 6,201.96 7,645.57 817.016,145.76 6,038,717.48 470,693.74 3.08 7,365.58 MWD+IFR2+MS+sag (6) 11,847.04 88.45 319.69 6,204.14 7,678.35 789.066,147.94 6,038,750.37 470,665.93 6.27 7,402.93 MWD+IFR2+MS+sag (6) 11,902.39 91.21 320.85 6,204.30 7,720.91 753.696,148.10 6,038,793.07 470,630.74 5.41 7,451.27 MWD+IFR2+MS+sag (6) 11,941.91 91.74 319.19 6,203.29 7,751.18 728.316,147.09 6,038,823.44 470,605.48 4.41 7,485.68 MWD+IFR2+MS+sag (6) 12,038.76 89.19 319.95 6,202.50 7,824.89 665.516,146.30 6,038,897.40 470,542.98 2.75 7,569.67 MWD+IFR2+MS+sag (6) 12,135.28 89.83 319.17 6,203.33 7,898.35 602.906,147.13 6,038,971.10 470,480.68 1.05 7,653.38 MWD+IFR2+MS+sag (6) 12,188.82 91.51 319.22 6,202.70 7,938.87 567.926,146.50 6,039,011.76 470,445.87 3.14 7,699.63 MWD+IFR2+MS+sag (6) 12,232.48 89.30 319.87 6,202.39 7,972.09 539.596,146.19 6,039,045.09 470,417.68 5.28 7,737.49 MWD+IFR2+MS+sag (6) 12,328.76 88.65 318.49 6,204.11 8,044.94 476.676,147.91 6,039,118.19 470,355.06 1.58 7,820.65 MWD+IFR2+MS+sag (6) 12,426.43 89.33 317.85 6,205.84 8,117.70 411.546,149.64 6,039,191.21 470,290.23 0.96 7,904.14 MWD+IFR2+MS+sag (6) 12,521.69 91.13 314.26 6,205.45 8,186.28 345.456,149.25 6,039,260.04 470,224.42 4.22 7,983.68 MWD+IFR2+MS+sag (6) 12,618.14 88.70 313.25 6,205.60 8,252.97 275.796,149.40 6,039,327.01 470,155.04 2.73 8,062.03 MWD+IFR2+MS+sag (6) 12,714.90 88.65 314.32 6,207.83 8,319.91 205.956,151.63 6,039,394.22 470,085.48 1.11 8,140.65 MWD+IFR2+MS+sag (6) 12,810.14 86.91 315.11 6,211.52 8,386.86 138.326,155.32 6,039,461.45 470,018.14 2.01 8,218.88 MWD+IFR2+MS+sag (6) 12,907.07 89.72 322.00 6,214.38 8,459.44 74.246,158.18 6,039,534.28 469,954.36 7.67 8,301.99 MWD+IFR2+MS+sag (6) 13,002.93 87.72 323.95 6,216.52 8,535.95 16.546,160.32 6,039,611.01 469,896.97 2.91 8,387.79 MWD+IFR2+MS+sag (6) 13,099.29 89.46 327.09 6,218.89 8,615.34 -37.996,162.69 6,039,690.62 469,842.77 3.72 8,475.85 MWD+IFR2+MS+sag (6) 13,195.32 88.90 325.08 6,220.26 8,695.02 -91.566,164.06 6,039,770.50 469,789.53 2.17 8,564.01 MWD+IFR2+MS+sag (6) 13,291.24 88.96 322.68 6,222.06 8,772.49 -148.096,165.86 6,039,848.19 469,733.32 2.50 8,650.54 MWD+IFR2+MS+sag (6) 13,366.77 87.96 323.30 6,224.08 8,832.78 -193.546,167.88 6,039,908.66 469,688.12 1.56 8,718.15 MWD+IFR2+MS+sag (6) 9/22/2011 2:59:36PM COMPASS 2003.16 Build 42 Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSK-13 ODSK-13 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSK-13 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSK-13 - Slot ODS-13 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 13,387.15 90.29 327.60 6,224.40 8,849.55 -205.096,168.20 6,039,925.48 469,676.64 23.99 8,736.76 MWD+IFR2+MS+sag (6) 13,485.01 88.64 328.61 6,225.31 8,932.63 -256.796,169.11 6,040,008.76 469,625.28 1.98 8,827.92 MWD+IFR2+MS+sag (6) 13,581.69 88.84 330.09 6,227.44 9,015.78 -306.066,171.24 6,040,092.10 469,576.35 1.54 8,918.70 MWD+IFR2+MS+sag (6) 13,637.48 89.90 329.81 6,228.05 9,064.07 -334.006,171.85 6,040,140.49 469,548.61 1.97 8,971.30 MWD+IFR2+MS+sag (6) 13,678.25 87.70 327.90 6,228.90 9,098.95 -355.086,172.70 6,040,175.46 469,527.68 7.15 9,009.46 MWD+IFR2+MS+sag (6) 13,772.94 88.78 323.63 6,231.81 9,177.18 -408.316,175.61 6,040,253.89 469,474.77 4.65 9,096.13 MWD+IFR2+MS+sag (6) 13,869.94 88.84 322.77 6,233.83 9,254.83 -466.406,177.63 6,040,331.77 469,417.00 0.89 9,183.13 MWD+IFR2+MS+sag (6) 13,965.50 87.22 321.01 6,237.11 9,329.97 -525.346,180.91 6,040,407.14 469,358.37 2.50 9,267.81 MWD+IFR2+MS+sag (6) 14,060.37 89.03 325.91 6,240.22 9,406.13 -581.776,184.02 6,040,483.52 469,302.25 5.50 9,353.04 MWD+IFR2+MS+sag (6) 14,156.63 87.84 324.06 6,242.85 9,484.93 -636.986,186.65 6,040,562.54 469,247.37 2.28 9,440.64 MWD+IFR2+MS+sag (6) 14,165.65 88.52 324.25 6,243.13 9,492.24 -642.266,186.93 6,040,569.87 469,242.12 7.83 9,448.79 MWD+IFR2+MS+sag (6) 14,194.37 91.54 325.53 6,243.12 9,515.73 -658.786,186.92 6,040,593.42 469,225.70 11.42 9,474.91 MWD+IFR2+MS+sag (6) 14,253.09 87.57 323.94 6,243.57 9,563.66 -692.676,187.37 6,040,641.49 469,192.01 7.28 9,528.26 MWD+IFR2+MS+sag (6) 14,350.77 89.53 324.29 6,246.05 9,642.77 -749.916,189.85 6,040,720.82 469,135.10 2.04 9,616.53 MWD+IFR2+MS+sag (6) 14,447.61 87.60 325.32 6,248.47 9,721.88 -805.706,192.27 6,040,800.15 469,079.63 2.26 9,704.54 MWD+IFR2+MS+sag (6) 14,513.00 87.60 325.32 6,251.21 9,775.61 -842.876,195.01 6,040,854.02 469,042.68 0.00 9,764.17 PROJECTED to TD 9/22/2011 2:59:36PM COMPASS 2003.16 Build 42 Page 7 3000 4000 5000 6000 7000 8000 9000 10000 11000Depth Oooguruk ODSK-13i Begin Sidetrack outside of casing for re-drill of 11.75" Intermediate TD 1st Intermediate at 9224' MD, 5569' TVD,20:22 08/03/2011 TD Intermediate 2 on 9/1/2011 @ 15:46 TD 1st Intermediate at 9100' MD, 5424' TVD, @ 16:54 8/17/2011 Set 9 5/8" Liner TOL 3,282', 2847' TVD BOL 9098' MD, 5423' TVD Begin Drill Intermediate 2 8.5" by 9.5" hole. Begin 11.75" Intemediate at 5810' MD, 3179' TVD On Bot: 07:08 05/23/2011 Set 7" Liner TOL 8949'MD 5343'TVD11000 12000 13000 14000 15000 16000 17000 18000 19000 20000 21000 0 10203040506070Measured DRig Days Hole Unstable, Abandon PB1, Sidetrack outside of Casing Set 4 1/2" Liner Lost Communication with Geo Pilot- T.D. 14513' MD 6251.24 TVD TD Intermediate 2(Pilot Hole) PB2 on 8/26/2011 @ 12:00, Will set plug and Kick off outside shoe TOL 8949 MD, 5343 TVD BOL 11438' MD, 6182' TVD Surface Data Logging After Action Review Employee Name: Colby Marks Date: 8/3/2011 Well: ODSK-13 Hole Section: Intermediate What went as, or better than, planned: Working in tandum with the mud engineers, we were able to keep accurate accounts of all sweeps pumped giving us good indicators of how well the hole is being cleaned as well as average hole Difficulties experienced: .The CVE stalled out completely and the degasser quit rotating, due to a build up of mud and clay in the motor housing. Took degasser apart and cleaned out mud, increased the amount of oil going to the motor and increased the speed at the same time. Doing all this fixed the problem. I kept the oil at a higher drip rate and lowered the speed back to it's normal setting. There are still some fluctuations with the rotary speed of the degasser, possibly due to residual mud inside, which will be cleaned at casing break Recommendations: Between every run, take apart degasser and make sure that it is cleaned thoroughly and well oiled, you should be having to fill the oiler once a tour. Innovations and/or cost savings: Surface Data Logging After Action Review Employee Name: David Mckechnie Date: 17-Sep-2011 Well: ODSK-13 Hole Section: Production-Kuparuk What went as, or better than, planned: CVE continues to work well as long as preventative maintenance is kept up. Difficulties experienced: Chromatograph occasionally times out due to Iris switching to power saving mode. Recommendations: Install new Iris machine and switch Chromatograph from USB port to R2S32. Innovations and/or cost savings:
