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210-142
New Plugback Esets 6/21/2024 Well Name API Number PTD Number ESet Number Date Kaladachabuna 2 PB1 50-283-20169-70-00 212-157 T38946 5-3-2013 Kaladachabuna 2 PB2 50-283-20169-71-00 212-157 T38947 5-3-2013 Kaladachabuna 2 PB3 50-283-20169-72-00 212-157 T38948 5-3-2013 Kaladachabuna 2 PB4 50-283-20169-73-00 212-157 T38949 5-3-2013 ODSN-18 PB1 50-703-20624-70-00 210-142 T38950 2-18-2011 ODSN-18 PB2 50-703-20624-71-00 210-142 T38951 2-18-2011 ODSN-18 PB3 50-703-20624-72-00 210-142 T38952 2-18-2011 ODSN-18 PB4 50-703-20624-73-00 210-142 T38953 2-18-2011 ODSN-18 PB5 50-703-20624-74-00 210-142 T38954 2-18-2011 ODSN-24 PB1 50-703-20662-70-00 212-178 T38955 6-13-2013 ODSN-24 PB2 50-703-20662-71-00 212-178 T38956 6-13-2013 PBU 18-27E PB2 50-029-22321-72-00 212-131 T38957 2-12-2013 PBU 18-27E PH 50-029-22321-71-00 212-131 T38958 2-12-2013 Redoubt Unit 7 PB1 50-733-20526-70-00 203-150 T38959 10-22-2003 SP18-N05 PB1 50-629-23453-70-00 211-101 T38960 7-11-2016 3K-103 PB1 50-029-23392-70-00 208-115 T38961 2-3-2009 3K-103 PB2 50-029-23392-71-00 208-115 T38962 2-3-2009 3K-103 PB3 50-029-23392-72-00 208-115 T38963 2-3-2009 3K-103 PB4 50-029-23392-73-00 208-115 T38964 2-3-2009 3K-103 PB5 50-029-23392-74-00 208-115 T38965 2-3-2009 ODSN-25 PB1 50-703-20656-70-00 212-030 T38966 8-11-2012 ODSN-25 PB2 50-703-20656-71-00 212-030 T38967 8-11-2012 ODSN-25 PB3 50-703-20656-72-00 212-030 T38968 8-11-2012 ODSN-25 PB4 50-703-20656-73-00 212-030 T38969 8-11-2012 ODSN-18 PB1 50-703-20624-70-00 210-142 T38950 2-18-2011 ODSN-18 PB2 50-703-20624-71-00 210-142 T38951 2-18-2011 ODSN-18 PB3 50-703-20624-72-00 210-142 T38952 2-18-2011 ODSN-18 PB4 50-703-20624-73-00 210-142 T38953 2-18-2011 ODSN-18 PB5 50-703-20624-74-00 210-142 T38954 2-18-2011 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. L Q - 114.a Well History File Identifier Organizing (done) ❑ Two-sided III 111111 111111111 ❑ Rescan Needed III 11111111 1111111 RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Ma's: reyscale Items: ❑ Other, No/Type: m ether Items Scannable by a Large Scanner LOGS ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: cc�� 6/i' ❑ Other:: BY: Maria Date: 3 OL /s/ 1(410 Project Proofing II 111111II III 11 111 BY: AIM Date: 3 c), /s/ 1114P Scanning Preparation f 0, x 30 = 3 too + 02 TOTAL PAGES 3 Sq. ( ount does not include cover sheet) BY: dle. Date: .41%7// /s/ Production Scanning 1111111111011H Stage 1 Page Count from Scanned File: 3 3-5—(Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO BY: IMO Date: 3A7/4/Lt /s/ 61,10 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 1111111111111111111 ReScanned 11111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked III 1111111111111111 OF �Ai T 4,^ I'///- 4^� , E STATE1 �. �' e i 6 s t -- ---- 332 West Seventh F 'cr,ue GOVERNOR C L N r, RN, Anchorage Alaska 9950' 35/2 "lc n 997 Alex Vaughan © f F Sr. Drilling Engineer Pioneer Natural Resources Alaska, LLC 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field,Nuiqsut Oil Pool, ODSN-18 Sundry Number: 314-242 SCANNED MAY 0 7 2011 Dear Mr. Vaughan: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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. oerster Chair DATED this G4 day of April, 2014. Encl. ` STATE OF ALASKA t ail 1 , Li 14 ALASKA OIL AND GAS CONSERVATION COMMISSION nTS 4-Rat 14, APPLICATION FOR SUNDRY APPROVALS •` 20 AAC 25.280 1.Type of Request: Abandon 0 Plug for Redrill 0 Perforate New Pod 0 Repair Well 0 Change Approved Program 0 Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 % Time Extension 0 Operations Shutdown 0 Re-enter Susp.Well 0 Stimulate 0 Alter Casing 0 Other Run Clean-out String Q • 2.Operator Name: 4.Current Well Class: ermit to Drill Number. Pioneer Natural Resources Alaska LLC Exploratory 0 Development 9• 210-142 3.Address: 700 G Street,Suite 600 Stratigraphic 0 Service ❑ 6.API Number. Anchorage,AK 99501 50-703-20624-00-00 - 7.If perforating: 8.Well Name end Number. What Regulation or Conservation Order governs well spacing in this pool? WA ODSN-18 " Will planned perforations require a spacing exception? Yes 0 No 19 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036 /ADL 355037 •• Oooguruk-Nuiqsut 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): 16,689' 6229' 16,399' 6232' N/A N/A Casing Length Size MD TVD Burst Collapse ! Conductor 110' 16" 158' 158' N/A N/A Surface 3557' 11-3/4" 3600' 3309' 5830 psi 3180 psi Drilling Liner 5504' 9-5/8" 3320'-8824' 3124'-5329' 5750 psi 3090 psi Tie-Back 8270' 7" 8308' 5149' 7240 psi 5410 psi Intermediate 2 3801' 7" 8289'-12,090' 5143'-6175' 7240 psi 5410 psi Liner 4485' 4-1/2" 11,915'-16,400' 6144'-6232' N/A N/A Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment,pg.2 1 See Attachment, pg.2 2-7/8",6.5# L-80, IBT-M 10,986' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): See Attachment, pg.3 See Attachment, pg.3 12.Attachments: Description Summary of Proposal 0 1 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development❑,, • Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/25/2014 Oil r • Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned 0 Commission Representative: GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alex Vaughan,343-2186 Email alex.vauahanc pxd.com Printed Name Alex Vaughan Title Sr. Drilling Engineer Signature Phone Date '- ,_ 343-2186 4/11/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3` -L.- 2-x{.2. Plug Integrity 0 BOP Test Mechanical Integrity Test 0 Location Clearance 0 Other: 7E- LI 5 D v i S Eo P W;S I-- ABDMS�a► AY A ? 2017 • Spacing Exception Required? Yes 0 No Subsequent Form Required: / 10 - I-1 011 Ciet7 APPROVED BY Approved by: 7 COMMISSIONER /THE COMMISSION Date: 4-u— J `f. 77/4/ -tv<6 Lcl4proval. Form 10-403(Revised 10/ 12) App a ptians d months frmhe daAttachments in Duplicate � R117 �C de' Il r RECEIVED PIONEER APR 142014 NATURAL RESOURCES ALASKA AOGCC Pioneer Natural Resources Alaska LLC 700 G Street,Suite 600 Anchorage,Alaska 99501 Tel: (907)277-2700 Fax: (907)343-2190 April 11th, 2014 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite#100 Anchorage, AK 99501 RE: ODSN-18 Sundry Application to Pull Tubing and Replace with Clean-out String REF: Permit To Drill # 210-142 Pioneer Natural Resources Alaska (PNRA) hereby submits an Application For Sundry to pull the existing ESP Completion String and replace with a new 2-7/8" completion to facilitate a coil clean out of the production liner on ODSN-18. See the proposed plan attachment and supporting documentation. Sincerely, Alex Vaughan Sr. Drilling Engineer Attachments: Form 10-403 Supporting information cc: ODSN-18 Well File Pioneer Natural Resources Alaska LLC ODSN-18 Page 2 AOGCC Form 10-403, Application for Sundry Approval Present Well Condition - Box #11 Perforation Depth (MD/TVD) - Attachment 4-W, 12.6#, L-80 Hyd 521 Uncemented Liner Perforated Pups w/ 6-1/2" Holes @ depths listed: MD TVD 12,302' - 12,306' 6201' - 6202' 12,506' - 12,511' 6222' - 6222' 12,628' - 12,632' 6225' - 6225' 13,005' - 13,009' 6211' - 6211' 13,168' - 13,173' 6207' - 6207' 13,535' - 13,540' 6217' - 6217' 13,734' - 13,739' 6230' - 6230' 13,934' - 13,939' 6233' - 6233' 14,138' - 14,143' 6235' - 6235' 14,300' - 14,304' 6239' - 6239' 14,463' - 14,468' 6242' - 6242' 14,840' - 14,844' 6238' - 6238' 15,043' - 15,048' 6244' - 6244' 15,247' - 15,252' 6242' - 6242' 15,448' - 15,453' 6249' - 6249' 15,648' - 15,653' 6251' - 6251' 15,867' - 15,872' 6239' - 6239' 16,029' - 16,034' 6232' - 6231' 16,234' - 16,239' 6230' - 6230' Pioneer Natural Resources Alaska LLC ODSN-18 Page 3 AOGCC Form 10-403, Application for Sundry Approval Present Well Condition Summary, Box #11 Packers and SSSV (type, measured and true vertical depth) SSSV TRMAXXX-5E SSSV (Locked Open) 2068' MD /2043' TVD Packers ESP Hydro II Packer w/ Gas Vent Valve 2570' MD / 2523' TVD 11-3/4" x 9-5/8" Liner Hanger Packer 3320' MD / 3123' TVD 7" x 9-5/8" Liner Top Packer 8308' MD / 5150' TVD . FSV Arrow Pak Retrievable Packer 11,873' MD / 6136' TVD 4-1/2" x 7" Liner Top Packer 11,930' MD / 6147' TVD PIONEER NATURAL RESOURCES ODSN-18 RWO Program Pull ESP & FSV and Install Gas Lift Completion ESP Completion: 10,986' MD / 5,998' TVD FSV Completion: 11 ,920' MD / 6,145' TVD Planned 2-7/8" Gas Lift String: 11 ,940' MD / 6,149' TVD AFE# 030547, API # 50-703-20624-0000 AOGCC Sundry # TBA Prepared: Date: Alex Vaughan: Operations Drilling Engineer Reviewed: Date: Rami Jasser: Sr. Staff Completions Engineer Reviewed: Date: Jack Kralick: Wells Superintendent Reviewed: Date: Gary Ross: Operations Superintendent Reviewed: Date: Rob Tirpack: Drilling Manager Approved: Date: Vern Johnson: Alaska Drilling Manager ODSN-18 2014 RWO ESP Replacement Program Version 1.0 1 April 11th, 2014 Pre-Riq Work to be completed prior to MIRU of Nabors 19AC: (The following workscope is to be completed as outlined in ODSN-18 Well Work Procedure Pre RWO document as coordinated by Jack Kralick) • All seawater based fluids injected into the well should be built with the following properties a. Filtered Treated Seawater filtered to sub 20 NTU's prior to the addition of additives. b. 0.5 gallons/ 100bbl NPS2263 scale inhibiter c. 0.5% by volume NoBlok C d. Maintain post additives NTU readings below 180 • Diesel should be used for freeze protection • • The TRSV has failed and has been locked out. " • All 3 GLV have DGLV's installed. 2/9/13 Wellview Rpt#5 • 2-7/8" x 7" annulus above ESP has been freeze protected with diesel and tested to 1000 psi for 5 min. Wellview Report: 2/9/14. The PVV in the ESP packer is failed in the closed position. • Tubing has been punched below the ESP packer from 2583.6' MD to 2588.6' MD @ 2 spf. Wellview Report: 2/9/2014 • Tubing has been punched above the ADV at 10657' MD 5' ©2 spf. Wellview Report: 3/15/2014 • • Annular fluid above lower holes has been displaced to 10.1 ppg Brine with the following additives. . Wellview Report: 3/21-22/2014 a. 0.5 gallons/ 100bbI NPS2263 scale inhibiter b. 0.5% by volume NoBlok C • XX plug has been set in X-Nipple at 2516' MD (slickline depth 2489') and tested to 1000 psi for 15 . min. Wellview Report 3/23/2014 • 2-7/8" x 7" annulus above ESP was re-pressure tested to 2500 psi for 15 min. Wellview Report: • 3/23/14 • A BPV is set in the tubing hanger • • The tree and tubing hanger pack-off void in well head have been pressure tested to 5,000 psi • • ODSN-18 is suspended with the following well control barriers: • a. 2-7/8" Tubing: i. XX plug in X-Nipple at 2516' MD, tested to 1000 psi for 15 min. ii. BPV b. 2-7/8" x 7" Annulus: i. Pressure tested 2-7/8" x 7" annulus above ESP Packer to 2500 psi for 15 min. y ii. Pressure tested Tubing hanger packoff c. Additional: i. 10.1 Brine is unlikely to be uniform in annulus and therefore not considered a well control barrier. V ii. FSV is currently operational and able to hold pressure from above. However, it is a check valve and will allow pressure from below through. ODSN-18 2014 RWO ESP Replacement Program Version 1.0 2 April 11th, 2014 ODSN-18 Nuiqsut Production Well Completion- Current JIIiii J O ScSSSV has failed Casingand is locked out Item# Item MD(ft) TVD(ft) ~~ A 16' Conductor 158 158 O J B 11-3/4"60#L-80 Hydril 521,10.772"ID 3,600 3309 '- XX plug in X-Nipple C 9-5/8"40#L-80 Hydril 521,8.835"ID' 8,824 5607 ...sr 2516'MD D 7"26#L-80 BTC-M,6.276"ID,Tieback 8,309 5150 I le liliii E 7"26#L-80 Hydril 511,6.276"ID** 12,090 6175 ■E Tubing punched F 4-1/2"12.6#Hydril 521 3.958"ID 16,400 6232 2583.6'MD) G 2-7/8"6.5#L-80 IBT-M 10,986 5948 iiiiiii': 5'@2 spf Upper Completion 2 O IA Fluid above ESP packer. Item# Item MDrkb(ft) TVDrkb(ft) Inhibited Kill weight Brine 1 VetcoGray Tubing Hanger 34 34 with 2000'TVD diesel cap 2 2-7/8"Wellstar Tubing Retreivable ScSSSV 2,068 2,043 3 GLM#1-2-7/8"x 1-1/2"(min.3 jts above top X nipple) 2,454 2,415 •- IA fluid below ESP packer: 2-7/8"X Nipple 2.313"I.D.(min.2 jts above Gas Vent . 10.1 Brine with NoBlok C and 4 Vale Packer) 2,518_ 2,475 q J o scale inhibiter 5 WFT 7"x 2-7/8"Gas Vent Vahe Packer(max.ND 2500') 2,550 2,504 l r r X 6 GLM#2-2-7/8"x 1-1/2"(min.2 jts above X nipple) 8,400 5,182 ii - Tubing fluid: 2-7/8"X Nipple,2.313"ID(max.incl.70 deg)w/RHC-M I 10.1 Brine with NoBlok C and 7 Plug Body 8,464 5,204 8 Automatic Divert Valve(ADV) 10,904 5,926 �, Tubing punched 9 ESP(Pump,Motor,and Jewelry) 10,914 5,929 ® oo 10657'MD ) End of Assembly 10,986 5,948 - 5'@ 2 spf Upper Completion 1 Item# Item MDrkb(ft) TVDrkb(ft)j 0 10 WFT 7"x 3-1/2"Retrievable Packer 11,850 6,133 _ 11 WFT 3-1/2"PressureActiveted Sleeve 11,875 6,137 12 WFT 3-1/2"Formation Saver Valve 11,900 6,142 13 1 jt 3.5"TC-II and WLEG 11,910 6,143 0tE C End of Assembly 11,945 6,150 Lower Completion 001 Item# Item MD(ft) TVD(ft) _�0 13 WFT PBR Tie Back Sleeve 15fl 11,915 6,144 14 WFT"NTH"Liner Top Pkr 11,930 6,147 15 WFT"PHR"Rotating Hyd Set Liner Hanger 11,934 6,148 16 Resman Tracer Pup(heel location) 12,975 6,211 4-1/2"12.60#L-80 Hydril Pupjt 4fl(Ported w/6 1/2 holes), See separate attachrrent 18 spaced every 200'. 0\11: _19 Resman Tracer Pup(midlateral location) 14,708 6,237 6 20 Resman Tracer Pup(toe location) 15,814 6,243 21 Liner Shoe(PLUGGED)w/4-1/2"Hydril 521 16,398 6,233 15 End of Assembly 16,400 6,233 n ®,�, ____ 18 0 s 20 _ �i./��� ..O 0 0 0 0 0 0 0 0 0 o 00 . 0 , e 0 0 ............)0 21 4-1/:"12.6#/ft L-80 Hydril 521 Liner w/ 6-1/8"Hole TD at Pre-Perforated pups at 16689'MD/6229' (6 holes-0.50"Diamenter) TVD spaced @ 200 ft apart ODSN-18 2014 RWO ESP Replacement Program Version 1.0 3 April 11th, 2014 Zi` ODSN-18 2014 RWO Planned Completion, 4-9-2014 Fia'frl./.- iiiii ODSN-18 JMD(ft) TVD(ft) Baker Hughes ;•::::•••.:".„:: IIIii 11-3/4"60#,L-80 Hyd 521,10.772"ID 3,600 3,309 A. 9-5/T40#L-80 Hyd 521,8.835"ID,Bottom 8,824 5,329 V11aed1Nl6rd 7'26#L-80 BTC-M 6.276"ID Tie Back 8,308 5,150 J 7'26#L-80 BTC-M,6.276"ID 12,090 6,175 Fs n 4-1/2"12.6#L-80 Hyd 521,3.958"ID,Top 11,915 6,144 Set Depth 1 940 1 I 4-1/2"12.6#L-80 Hyd 521,3.958"ID,Bottom 16,400 6,232 Tool Description Cumulative. D� Joints Length Length Inc(*) TVD Nett) (°It00usft) RKB 34.09 34.1 1.5 36 7.4 43 0.0 43 0.26 3.5"9.2#L-80 IBT-M Joints 2 62.0 105 0.16 105 0.26 0.9 106 0.2 106 0.26 2.875"6.5#L-80 IBT-M space out pups tba 31.0 137 0.25 137 0.26 - 2.875"6.5#L-80 IBT-M Joint • 61 1,868 2,005.3 15.8 1982 0.63 J - ' • - • -':Joint 12.00 2,017.3 15.8 1994 1.27 "'$ g "l8"NE TRSV 6.70 2,024.0 15.7 2000 1.27 114 -nt ill 12.00 2,036.0 15.6 2012 1.27 11 En 'i• 2.875"654 L-80 IBT-M Joint 1 31.00 2,067.0 15.2 2041 1.27 11111 1 1 1111:: 2.875"6.5#L-80 IBT-M Pup Joint 12.00 2,079.0 15.0 2053 1.27 1111' ""' 2.875"x 1"GLM EUE box pin,w/DCR-1 7.00 2,086.0 14.9 2060 1.27 k 2.875"6.5#L-80 IBT-M Pup Joint 12.00 2,098.0 14.8 2071 1.27 2.875"6.5#L-80 IBT-M Joint ' 1 31.00 2,129.0 14.4 2101 1.37 2.875"6.5#L-80 IBT-M Pup Joint " 12.00 2,141.0 14.3 2113 1.37 2.875"x 2.313"X-profile nipple 1.50 2,142.5 14.3 2115 1.37 2.875"6.5#LI301BT.M Pup Joint ,, 12.00 2,154.5 14.1 2126 1.37 2 875"6.5#L-80 IBT-M Joint 193 I 5,970 8,124.0 69.2 5085 0.76 2.875 6.5#L-80 IBT-M box XEUE pin Xo 12.00 8,136.0 69.2 5089 0.76 2.875"x 1"GLM EUE,w/DGLV 7.00 8,143.0 69.2 5092 0.76 2.875"6.5#L-80 EUE box X IBT-M pin XO 12.00 8,155.0 69.2 5096 0.76 2 875"6.5#L-80 IBT-M Joint ' 1 31.00 8,186.0 69.2 5107 0.76 2.875"6.5#L-80 IBT-M Pup Joint 12.00 8,198.0 69.2 5111 0.76 7"-2.875"FH Packer 10.00 8,208.0 69.2 5115 1.36 2.875"6.54 L-80 IBT-M Pup Joint 12.00 8,220.0 693 5119 1.36 2.875"6.5#L-80 IBT-M Joint 1 31.00 8,251.0 69.5 5130 1.36 2.875"6.5#L-80 IBT-M box XEUE pin XO 12.00 8,263.0 69.6 5134 1.36 2.875"sliding sleaee EUE pin x pin 8.65 8,271.7 69.7 5137 1.36 2.875"6.5#L-80 EUE box X IBT-M pin XO 12.00 8,283.7 69.8 5141 1.36 2.875"6.5#L-80 IBT-M Joint r 1 31.00 8,314.7 69.8 5152 0.5 12.00 8,326.7 69.8 5156 0.5 2.875"x 2.313")94 pndlle nippb 8.65 8,335.3 69.7 5159 0.5 . 2.875"6.5#L-80 IBT-M Pup Joint • 12.00 8,347.3 69.7 5163 0.5 111 /(�� 2 875"5 5#LA0 IBT-M Joint 116 I 3,568 11,915.0 79.6 6144 1.98 4� is • 2.875"Pup Joint20.00 11,935.0 79.6 6148 1.38 .. .• 4.5"UN2B pin X2.875"IBT-M box XO,30"be 1.50 11,936.5 79.6 6148 1.38 4 r\ Self-Align Mt .4111.1111111p,4.1"ID 3.50 11,940.0 79.7 6149 1.38 ir- . 0 0 0 0 0 0 e0 a e e o e o o I 1 4-V."12.64/([L-80 Hydril 521 Liner w/ 6-1/8"Hole TD at Pre-Perforated pups at 16689'MD/6229' (6 holes-0.50"Diamenter) TVD spaced @ 200 ft apart ODSN-18 2014 RWO ESP Replacement Program Version 1.0 4 April 11th, 2014 Pre-Rig Regulatory: 1. Provide 48 hour notice for the testing of the BOPE. 2. AOGCC mandates 1 week BOPE testing periods during RWO's. 3. Post ODSN-18 Approved Sundry#TBA(see program attachments). 4. Read Approved Sundry and ensure that operations are in accordance. Rig Activity: Kill ODSN-18 1. Hold pre job meeting a. Confirm Pre-Rig Workover Checklist has been filled out, reviewed, signed, and received from Operations b. Ensure proper handover of well from Operations c. Ensure adequate Seawater and fluid additives product is on location d. Discuss potential well control issues and ensure they are appropriately communicated to rig crew. e. RWO BOPE test cycle is 7 days as per AOGCC regulations. 2. All fluids injected into the well should be built with the following properties: a. Seawater filtered to sub 20 NTU's prior to the addition of additives. b. 0.02 ppb Aldacide G c. 0.5 gallons/ 100bbI NPS2263 scale inhibiter d. 0.5% by volume NoBlok C e. 0.25 ppb BARASCAV D oxygen scavenger i. Do not add ALDACIDE G and BARASCAV D at the same time, doing so will inhibit effectiveness. f. Maintain post additives NTU readings below 180 g. No Baracor corrosion inhibitor will be used until completion is in ground and packer fluid placed. 3. MIRU Nabors 19AC over ODSN-18 4. Lubricate and bleed the 2-7/8"x 7" IA as required. 5. ND production tree with the following well control barriers in place a. 2-7/8"Tubing: i. XX plug in X-Nipple at 2516' MD, tested to 1000 psi for 15 min. BPV. b. 2-7/8"x 7"Annulus: i. Pressure tested 2-7/8"x 7" annulus above ESP Packer to 2500 psi for 15 min. ii. Pressure tested tubing hanger packoff. 6. Install test dart, NU BOPE &Test 250 psi low/4500 psi high according to the test pressures outlined in the AOGCC Permit to Drill. a. Install 2-7/8" rams in lower BOPE ram body. b. Notify the AOGCC Field Representative 48 hours prior to the BOPE Test. ODSN-18 2014 RWO ESP Replacement Program Version 1.0 5 April 11th, 2014 7. Retrieve the test dart and BPV. 8. RU slickline with SLBOPE and test. 9. Pull DGLV from upper GLM at 2464' MD. 10. RU up tubing annulus valve to flowback tank and pump 10.1 ppg Brine down tubing to displace 94 bbl of diesel freeze protection from IA. 11. Pull XX Plug from X-Nipple at 2516' MD and RD Slickline. 12. Pick up 12,000' of 4" DP in mouse hole. a. It is recommended to pick up drill pipe at this point so as to be able to RIH with DP directly after pulling the ESP. This provides a reduced time we would be unable to circulate as compared to picking up drill pipe following pulling out of hole with the ESP completion. Additionally, it allows us to monitor the well the entire time we are picking up drill pipe. 13. Monitor well to ensure well is dead or on vacuum. Lubricate and bleed the IA as required. a. Tubing and annular fluid should be primarily 10.1 ppg Brine. It is unlikely to be uniform in annulus and therefore not considered a well control barrier. b. FSV is currently operational and able to hold pressure from above. However, it is a check valve and will allow pressure from below through if a hydrostatic pressure greater than reservoir pressure is not maintained. c. Bottom hole pressure model indicates an expected 8.8 ppg EMW. See model below. 4000 o 100 3500 200 3000 300 2500 400 II'. 2000 WO 1 6003 1500 700 1000 800 500 900 0 1000 1/1/13 1/31/13 3/2/13 4/1/13 5/1/13 5/31/13 6/30/13 7/30/13 8/29/13 9/28/13 10/28/13 11/27/13 12/27/13 1/26/14 2/25/14 3/27/14 4/26/14 — --N-18 Guage BHP model BHP —BHP Buildup estimate —B--N.18 oil rate ODSN-18 2014 RWO ESP Replacement Program Version 1.0 6 April 11th, 2014 Rig Activity: POOH with 2-7/8" ESP Completion 1. Hold pre job meeting a. Weatherford Packer Hand should be on location one day prior to releasing ESP packer. b. Baker Fishing Hand should be on location one day prior to releasing ESP packer. c. Ensure contingency fishing equipment is inventoried and accessible. (See RWO SID). a. Ensure safety valves with XO's to 2-7/8"tubing are operational and drifted. b. Review NORM monitoring plan with HSE team. 2. Prep rig floor to pull 2-7/8" ESP completion. c. Ensure safety valves with XO's to 2-7/8"tubing are accessible and in the open position. d. Ensure ESP cable cutter is operational and accessible. e. RU HAL control line spooler post hanger pull. f. Identify a person to count and maintain Cannon Clamps. Note location of each Cannon Clamp recovered on the tally. i. ODSN-18 has 7 bands across the ESP(5 on pump and 2 on MLE splice) 3. BOLDS and unseat 3-1/2"tubing hanger with use of 4" drillpipe landing joint. a. Hanger was landed with 155k PU and 65k SO. WellIView Report: 5/12/2011. 4. Release 2-7/8"x 7" ESP packer with a straight pull (See RWO SID). a. Packer Shear Release: 33,000 lbs b. 80%Tensile Limit: 115,000 lbs i. 165,000 lbs Tensile limit including top drive and block weight ii. Contact Rig Superintendent if more than 80% is required 5. Allow ESP packer elements to relax while RU tubing pulling equipment. a. Stroke ESP packer as required to accelerate process. Stroke ESP packer slowly so as to not swab or reduce hydrostatic pressure at the FSV significantly enough to allow FSV to open. b. Keep hanger below bottom ram on BOP. 6. Circulate a tubing depth surface-to-surface volume of 10.1 ppg Brine around. a. Wellbore/production fluids below ESP packer should be expected to circulate back to surface. Circulate to flowback tank as required. 7. Monitor well for 30 min and ensure well is dead or on vacuum. 8. Pull hanger to floor. a. There is no need to reestablish %"control line connection to open the TRSV as it was locked out. 9. POOH and LD 2-7/8" ESP completion string as per Oooguruk specific Centrilift 2-7/8" ESP completion string pulling procedure. (See RWO SID) a. If unable to hold fluid column during POOH fill hole with 150% DP displacement plus 5 bbl of 10.1 ppg Brine every half hour. b. Inspect 2-7/8"tubing for scale or corrosion and report on WellView. a. Clean all completion equipment at the rig floor with water. b. If influx is observed stab floor safety valve, space out, close annular and circulate 2 ODSN-18 2014 RWO ESP Replacement Program Version 1.0 7 April 11th, 2014 surface-to-surface volumes of 10.1 ppg brine to 7"shoe at 6 bpm. Shut down and monitor well for 30 min. If well continues to flow continue to circulate and contact Rig Superintendent to discuss increasing fluid weight. Once well is confirmed dead continue POOH. c. Have ESP cable cutter ready and prepare to cut cable and secure with cannon clamp and duct tape, allowing space for rams to close around tubing. d. If junk is left in hole contact Rig Superintendent and discuss fishing options. 10. Review clamp band count and compare with original completion. a. Install BOPE junk screen, function rams, flush stack with BOPE flushing tool, and retrieve junk screen. b. Discuss fishing options with Rig Superintendent if necessary. 11. Clean rig floor and prep for scraper cleanout run. r i a. Monitor hole during pP re a at o n. Riq Activity: Scraper Cleanout Run 1. Install 4" rams in lower BOPE ram body. Test 250 psi low/4500 psi high according to the test pressures outlined in the AOGCC Permit to Drill. 2. RIH with scraper, magnet, and mule shoe 100' MD below Baker FH packer setting depth (-8300' MD)on 4" DP and POOH. a. If unable to hold fluid column during RIH fill hole with 5 bbl of 10.1 Brine every half hour. b. Circ 150% DP capacity prior to POOH c. If unable to hold fluid column during POOH fill hole with 150% DP displacement plus 5 bbl of 10.1 ppg Brine every half hour. 3. Close blind ram a. Continue to fill hole with 5 bbl of 10.1 Brine every half hour as required. 4. Function blind rams, Clean rig floor and prep to pull FSV completion. a. Monitor hole during preparation. ODSN-18 2014 RWO ESP Replacement Program Version 1.0 8 April 11th, 2014 Rig Activity: POOH with FSV Completion 1. Hold pre-job meeting a. Review FSV job record (See RWO SID) b. Discuss possible fishing runs required to retrieve equipment lost in hole from previous ESP completion during POOH. c. Ensure Weatherford Arrow-Pak retrieving tool in on location d. Ensure Baker FSV contingency fishing milling equipment is inventoried and accessible. (See RWO SID). e. Ensure 4" DP safety valve is operational and drifted. f. Review NORM monitoring plan with HSE team. 2. RIH to FSV(-11,850' MD)with ArrowPak Packer retrieving BHA. b. Arrowpak retrieving tool 2-7/8 EUE Box x Pin (pinned for 25,000 lbs. +/-) c. Bumper Sub d. Hydraulic Jar e. Drill Collars 3. Circulate and condition 10.1 Brine for a minimum of two surface to surface circulations to ensure RWO fluid is clean. It will likely be lost downhole after FSV is pulled. 4. Release the FSV ArrowPak Packer as per the Weatherford Rep. a. Record PU &SO weights prior to tagging packer b. Circulate down into packer, set down 2000-3000 lbs. to engage latch on retrieval tool. c. Pickup and apply 4,000 lbs. shear above pickup weight(shear pins in packer& retrieval tool is pinned at 25,000 lbs. shear. d. Once packer is free, packing elements are not going to relax and will have to drag free & wear out packing element by continuing to pullout of the hole/ rubbing the packing element against the casing wall. e. NOTE: If tailpipe is stuck attempt to jar free in 10,000 lbs. increments max allowable pull will be 85%of 2-7/8 EUE thread on retrieval tool = 123,250 lbs. over pickup weight. f. Contingency i. If unable to pull stuck assembly free, pull 5,000 lbs. over pick up weight&rotate 8 rounds to the right at tool to release the retrieval tool. ii. Fishing Option 1: RIH with contingency fishing BHA consisting of a spear and shoe to grab the 3.5" packer bore or the 2.992" pup joint below. iii. Fishing Option 2: Cut pup joint below the packer and RIH with ArrowPak Packer retrieving BHA. POOH with packer and RIH with a spear to retrieve the tailpipe. 5. Close annular and bullhead 150% 7"annulus volume. 6. Monitor well for 30 min and ensure well is dead or on vacuum. 7. POOH with FSV completion. ODSN-18 2014 RWO ESP Replacement Program Version 1.0 9 April 11th, 2014 Rig Activity: RIH with 2-7/8"Tubing String i Cp 1. Install 2-7/8" rams in lower BOPE ram body. Test 250 psi low/4500 psi high according to the test pressures outlined in the AOGCC Permit to Drill. 2. Hold pre job meeting a. Baker is responsible for tally at rig site. The Tally is to include: i. Tubing measurement by joint(composite tubing tally is not acceptable) ii. Equipment type, Serial#, Length, OD, ID, Top and bottom connection. b. Pioneer RWO Completion Supervisor to create independent tally as outlined in the Pioneer Tally &Schematics Recommended Practice. Confirm jewelry installation and location with vender tally. c. CoMan to confirm jewelry installation and location with Pioneer RWO Completion Supervisor and record in Wellview. d. Tally is to be emailed to Alex Vaughan once compiled for confirmation. e. Tally is to be confirmed by Nabors Driller during RIH. 3. Confirm zero pressure below blind ram and open ram a. Continue to fill hole with 5 bbl of 10.1 Brine every half hour. 4. PU & RIH up 2-7/8"tubing string as per tally. a. Continue to fill hole with 5 bbl of Brine every half hour. b. Circ/fill 150% tubing volume 1/3 (-4,000' MD) and 2/3 (-8,000' MD) into the way in the hole. ODSN-18 2014 RWO ESP Replacement Program Version 1.0 10 April 11th, 2014 An outline of the completion equipment is as follows. This is intended to provide an understanding of the purpose of each piece of the equipment. It is provided as supplemental information along with the completion tally. GE 3-1/2"Tubing Hanger er Halliburton TrSSSV • Install at 2,000'TVD. Schlumberger GLM#2 • Install 1 jt below TrSSSV. • Run with Shear valve pinned for 2500 psi. o 1" SDCK-2 Shear Valve, IA to Tubing shear. o 1" SBEK-2C Ported latch for shear valve. • Purpose: Freeze protection circulation point. • Requires: EUE XO pups. Halliburton X-Nipple • Install 1 jt below GLM#2. • Primary Purpose: XX Plug set location for freeze protection circulation. Schlumberger GLM#1 • Install 1 joint above Baker FH packer. • Run with dummy valve installed. o 1" E Dummy. o 1" BK-5 Latch. • Purpose: Lift gas injection location. Baker FH packer • Install at 8,208' MD, 100' MD above 7"X 9-5/8"tie-back slips. • • Pin to 30 klbs shear release. Baker sliding sleeve • Install 1 joint below the FH packer. • Primary Purpose: Allows gas to be bleed from IA on a future RWO. Halliburton XN-Nipple • Install one joint below sliding sleeve. • Run with RHC installed. • Primary Purpose: Required to set packer and is a pressure test location for the 2-7/8"tubing ID with a XXN Plug. Halliburton Self Aligning Mule Shoe • Install inside 4-1/2" x 7" LHP. • Ensure the 2-7/8" IBT-M Box X 4-3/4 8UN-2B Pin XO is built with no more no more than a 30° bevel inside looking up to allow for easy tool passage. No internal square shoulders allowed. ODSN-18 2014 RWO ESP Replacement Program Version 1.0 11 April 11th, 2014 Rig Activity: Land 2-7/8"Tubing String 1. RIH with 2-7/8"completion to 20' above 4-1/2"x 7" LHP tie back extension. 2. Record PU and SO weights. 3. Locate the top of the liner, fully insert Self Aligning Mule Shoe assembly into tie-back extension, slack off 40,000 lbs, if achievable, and mark the pipe. 4. Pull out of LHP tie-back extension and space out. a. Space-out-pups should be below Tubing Hanger 3-1/2" IBT-M x 2-7/8" IBT-M XO. 5. With 4" landing joint and FOSV, land tubing hanger while maintaining 4,500 psi on TrSSSV control line. Once landed, RILDS for Tubing Hanger. Test both the upper and lower Tubing Hanger body seals to 5000psi. a. As long as Self Aligning Mule Shoe assembly is confirmed to be at least 10' into tie-back extension it is not necessary to stack weight on assembly as it is pressure neutral. 6. Hold pre-job meeting a. Double check that the RHC plug was installed in the XN-Nipple. b. Review freeze protection procedures c. Review packer setting procedures 7. Drop ball and rod and displace down to RHC body. a. Run ball and rod on slickline if fluid level of tubing is not at surface. 8. Fill tubing with 10.1 ppg Brine and set Baker FH packer per Baker rep instructions a. Increase tubing pressure to a minimum of 1,000 psi to initiate setting of the FH packer. The hydrostatic pressure of the well will complete the 2600 psi pressure required to set the packer with a 10.1 ppg fluid. 9. Pressure test the tubing and IA to 3,500 psi for 30 min a. A DCR-1 shear out valve pinned to 2500 psi is installed in the upper GLM and requires that pressure testing operations are executed in the following order: • Pressure test the tubing to 3,500 psi for 30 min. • Bleed tubing pressure down to 2,500 psi • Pressure Test 2-7/8"x 7"annulus to 3,500 psi for 30 min. • Bleed tubing pressure down to zero. This will result in shearing the shear-out valve • Pump fluid both directions through the shear-out valve to confirm communication. 10. Install TWC 11. ND BOP's and NU Tree with the following well control barriers in place a. 2-7/8" Tubing: i. Closed TrSSSV ii. TWC b. 2-7/8"x 7"Annulus: i. Pressure tested 2-7/8"x 7" annulus ii. Pressure tested tubing hanger packoff 12. Test X-mas Tree void to 5,000 psi. ODSN-18 2014 RWO ESP Replacement Program Version 1.0 12 April 11th, 2014 13. Remove TWC with rod. 14. Hold post job meeting a. Ensure proper handover of well from Drilling to Operations. b. Confirm Well Handover Document has been filled out and received by Operations. 15. RDMO Nabors 19AC a. Baker to supply CoMan, Completions Supervisor, and Alex Vaughan with a digital copy of Tallys, Pressure tests, and Post job report prior to leaving location. b. Halliburton to supply CoMan, Completions Supervisor and Alex Vaughan with a digital copy of post job report, SAMS sheet and/or strap sheets prior to leaving location. c. Schlumberger to supply CoMan, Completions Supervisor and Alex Vaughan with a digital record of strapped GLM's and GLV model's installed in well. Post Rio: Slickline 1. RU slickline on ODSN-18. 2. Hold pre job meeting. 3. Hold open TrSSSV. 4. Circulate diesel down 2-7/8"x 7" annulus through shearout valve and up 2-7/8" tubing to surface. 5. Pull Ball and Rod. 6. Pull Dummy Valve from lower GLM (GLM#2) and install 5/16" OV. 7. Pull Shearout Valve from upper GLM (GLM#1)and install Dummy Valve. 8. Pull RHC. 9. Function test TrSSSV. 10. RD slickline unit. ODSN-18 2014 RWO ESP Replacement Program Version 1.0 13 April 11th, 2014 IN Description V.d® r�Y w Fie Ccs 014004' g t �7 haro Tubing Hanger GE Vetco ODS Office Ext#6618 Andrew Cater 907-244-9427 TrSSSV Halliburton Jeff/Bob 907-670-5952 Dan Brown 907-748-2674 GLM Assembly Schlumberger Jeff/Bob 907-670-5954 Chris Cooper 907-748-7525 X&XN Nipple Assembly Halliburton Jeff/Bob 907-670-5952 Dan Brown 907-748-2674 FH Packer Baker Hughes Jeff/Troy Fraser Kiddie 907-903-2513 Sliding Sleeve Baker Hughes Jeff/Troy Fraser Kiddie 907-903-2513 Self-Aligning Shoe Halliburton Jeff/Bob 907-670-5952 Dan Brown 907-748-2674 RWO Fluid's Bariod ODS Office Ext#6639 Ethan Laufer 907-223-1697 Bob Smejkal Robert.Smejkal@pxd.com Mark Meier Mark.Meier@pxd.com Alex Vaughan 907-343-2186 907-748-5478 Alex.Vaughan@pxd.com Rob Tirpack 907-343-2121 907-903-9454 Rob.Tirpack@pxd.com Rami Jasser 907-343-2182 907-230-9390 Rami.Jasser@pxd.com Charlene Franklin 907-343-2172 Charlene.Franklin@pxd.com Rachel Davis 907-343-2159 Rachel.Davis@pxd.com ODSN-18 2014 RWO ESP Replacement Program Version 1.0 14 April 11th, 2014 AV Weatherford® Completion Systems SEAL BORE PACKERS ARROW-PAK RETRIEVABLE SEAL BORE PACKER The Weatherford Arrow-Pak delivers high performance with simplicity of design and desirable economics. It is a 10,000 PSI plus rated packer through 7-5/8 size and can be equipped to withstand severe corrosion and high temperatures.The Arrow-Pak is set on wireline or tubing and is easily retrieved. - The Arrow-Pak is designed with a unique sealing system. The ECNER Array Packing Element System (patent pending) has proven itself to be a superior seal.The packing elements pack-off easily and still resist swab-off. ' Applications: Use as a gravel pack packer but will also handle deep, high-pressure completions. Features: • High pressure and temperature rating , • ECNER Array Packing Element System • Rotationally locked for millability • • Sets in a wide range of casing I.D. • Extremely short design - 1, • Minimal o-rings required • Wireline set • Optional tubing set using AH Hydraulic Setting Tool {it: k ARROW•PAK SPECIFICATION GUIDE CASING PACKER MIN. BORE BASE THROUGH PRODUCT • O.D. WEIGHT MIN. I.D. MAX. I.D. O.D. BORE SEALS NUMBER • in/mm lb/ft in/mm in/mm in/mm in/mm in/mm 4-1/2 9.5 - 10.5 4.052 4.090 3.906 2.500 1.910 265-46 114,30 102,92 103,89 99,21 63.50 48,51 -- 4-1/2 11.6 - 13.5 3.920 4.000 3.771 2.500 1.910 265-45 114,30 99,57 101,60 95,78 63.50 48,51 5 18.0 - 21.4 4.126 4.276 3.969 2.688 1.938 265-52 I,' 127,00 104,80 108,61 100,81 68.28 49,23 5 11.5 - 15.0 4.408 4.560 4.250 2.688 1.938 265-50 127,00 111,96 115,82 107,95 68.28 49,23 5-1/2 4.670 4.778 4.500 3.000 2.375/2.270 20.0 - 23.0 265-56 139,70 118,62 121,36 114,30 76,20 60,36/57,66 5-1/2 13.0 - 20.0 4.778 5.044 4.625 3.000 2.375/2.270 265-55 139,70 121,36 128,12 117,48 76,20 60,36/57,66 1 ; 7 29.0 - 35.0 6.004 6.184 5.813 3.250 2.406 265-71 177,80 152,50 157,07 147,65 82,55 61,11 7 23.0 - 32.0 6.094 6.366 5.938 3.250 2.406 265-70 177,80 154,79 161,70 150,83 82.55 61,11 7 29.0 - 35.0 6.004 6.184 5.813 4.000 3.000 265-73 177,80 152,50 157,07 147,65 101,60 76,20 7 23.0 - 32.0 6.094 6.366 5.938 4.000 3.000 265-74 177,80 154,79 161,70 150,83 101,60 76,20 7-5/8 20 0 29 7 6.875 7.125 6.688 4.000 3.000 265-76 193,68 174,63 180,98 169,88 101,60 76,20 7-5/8 29 7 39 0 6.625 6.875 6.438 4.000 3.000 265-75 193,68 168,28 174,63 163,53 101,60 76,20 '1 :., 9-5/8 47 0 - 53.5 8.535 8.681 8.319 4.000 3.000 265-94 244,48 216,79 220,50 211,30 101,60 76,20 9-5/8 8.755 9.001 8.539 4.000 3.000 244,48 32.3 - 43.5 222,38 228,63 216,89 101,60 76,20 265-93 ,_ • 9-5/8 47.0 - 53.5 8.535 8.681 8.319 4.750 3.750 265-95 244,48 216,79 220,50 211,30 120,65 95,25 Arrow-Pak 9-5/8 47.0 - 53.5 8.535 8.681 8.319 6.000 4.875 265-96 Seal Bore Packer 244,48 216,79 220,50 211,30 152,40 123,83 C/2000 WEATHERFORD.All Rights Reserved. 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L l0 N W W ,0 0 n y d iliK 2.F,1-2 O CA 1-' < W M N M n ,p W O < ?•3 O` .- OI OD N N N of QC Q Ce N C L a C m om.d Z 000000 Ed5 a O 3 000WWWWWW > 2�A 0 o I ca`) c U7 >>> 700 dD U < -62 a m W X W W W W W W w . j u Z O 0 o = Z m t0 CD .. OD N N z y E m < idi N j ~ 0 (? c? ,-- N '- '" Q Lr` N `1 J�L-• O la 0 N N N N A OS 7 CAN N a • v a,, I— t3 < ceoommrnrnd rn m J mV ° C 0 W ° WNNNNNNNd N G 0 x odhdd0moS y kv a ZDNo °� OCV�gei • O vau, Lc)Lc) ,LparcO < mE2: fn 0a22 ILr = 1 uJ ooQ° 2 JW ,...,o < o• 1'gg c � Z $ � 5on • ! y Fw Z L=Oa Vm NNMN7d0 VI- F .- .L OH ma 0 1- 5 O 0 W K n a 0 (n X LL 6 7 0 v Li O y I ra w 3 0 II • N M 7,. L_LL O o m T a y 7a a, 2r o p8ZppppaY D 60, 6,0?� = st N0, n O N= 0 y N M M 4 0 MC Z Ao W a C n o ZO coOa C N Z O O O N Z O O O N a I x Z CO N W E a ` 0 r 2 0 (O ` 0 W v O N 1- LU I- U( 3 —p V) ao(Cuiai U) ,-Na) v J Daa W Em Zo O a IX E N Z CO O OM OO Z CO0 0 0 r aa F I 3 V 01 Y W CO < O (0 L° W LL. M FO) O r F W O M V N (O I J 5A N ri m v°g - _ 2 8-0) (0000 I m (0(0 Or 0p88 ZN 0/ < W CO O (O NOC I- N N M M N 4 CD Q Z Q d 0 I - Q y.L Z 212 -272 Z V V V V w W- =• o 0Dd (0ro (O CO 000_ (OCOCO (0 w / \ I 2° "� WXW W WW , wxWWWW S LL 1- O21 = 000 [VfV = Z °C\C\ f1Nd I Z FZm \ I- Q yOMn ✓ J . 0 NNcoO LMSrcScS o0. \ / m d L D C)• N N C9 V W (0 m m N U W (0 m m N T U w I- Ld Z DED-1 o � � 6 ' > a Itr'r4. re 3 V o 0 «° LL tfi LL W fl, V WOZvi,Ng (� OZ ((, Ngr.Am QJ � 00WOOON rem1 = Ld - (0 N O VE£ • e Weatherford Completion Systems Introduction -FormationSaver Lockout The Weatherford FormationSaver Lockout Valve is a high integrity device offering significant performance benefits over standard industry check valves. Although suited to all general check valve applications the design metallurgy is specifically aimed at oil industry applications where reliability, longevity and integrity are primary requirements. Specific Advantages of the 'FORMATIONSAVER LOCKOUT' 1. All sealing components including the surface of the main flapper are protected from the flow path minimising the potential for failure due to seal erosion, solids deposition etc. 2. The valve uses an API qualified Safety Valve Flapper and is therefore robust and reliable. 3. The valve is only actuated closed by the passage of fluid against the tri-flapper mechanism and therefore the seals are non-reliant on the condition of the tri-flapper mechanism. 4. Both opening and closure are dampened to prevent damage through long term cycling. 5. Specific features can be provided, i.e. varied closing rates, pressure equalisation across the closed valve, a lock open sleeve for wireline access through the valve etc. 6. The patent pending design provides Reservoir protection from well bore fluids. The design provides this protection with full bore ID giving minimal pressure drop. 7. The lockout feature allow for the valve to be temporarily locked into the opened position so that both sets of flappers do not impede on the ID of the tool. This allows for work to be performed downhole without the risk of damaging the flappers or any equipment run down hole. -1- Weatherford products and services are subject to Weatherford's standard terms and conditions. For more information conceming the full line of Weatherford's product and services,please contact your authorised Weatherford representative.Unless noted otherwise,trademarks and services marks noted herein are the property of Weatherford. http.//wwwweatherford con ©2002 Weatherford.All rights reserved. Weatherford' Completion Systems Operation The FORMATIONSAVER utilizes a flapper valve type closure mechanism which has proven to be one of the most effective sealing devices in the oil industry. The innovative step which makes the FORMATIONSAVER unique is the use of 3 springs actuated triangular flappers which are spring biased closed allowing the check valve to be `self-piloting'. In normal flowing conditions the main flapper valve is open by a flow tube, which protects all sealing components from the effects of flow. In the event of flow contrary to the norm the flappers automatically move into the flow path creating an applied force which overcomes the power spring and moves the flow tube which allows the main flapper to close against its seat. Once conventional flow is again directed against the main flapper to the point at which pressure generated by the reverse flowing conditions is overcome the flow tube returns back to its normal position, the flappers will be displaced open by movement of the fluid and normal flow can recommence. -2- Weatherford products and services are subject to Weatherford's standard terms and conditions. For more information concerning the full line of Weatherford's product and services,please contact your authorised Weatherford representative.Unless noted otherwise,trademarks and services marks noted herein are the property of Weatherford. huo://www.weaherford cons' ©2002 Weatherford.All rights reserved. Weatherford` Completion Systems Wiper Wiper Backup Snap II Ring \„)/ ./ -9- Weatherford products and services are subject to Weatherford's standard terms and conditions. For more information concerning the full line of Weatherford's product and services,please contact your authorised Weatherford representative.Unless noted otherwise,trademarks and services marks noted herein are the property of Weatherford. htro://www weatherford corn/ ©2002 Weatherford.All rights reserved , , 4 /,,, �, 0 Q sO � fl 1 111 ° ,. E IIS, , E 2 . -.,.. Et 4 9 v J N C v g ,, fill 011\ uu A I l; UI' ii bo;aai t , d EV 3"' ` /11111: 1 I 1 E1 It E \ 1 1 111 M 1 II ai ii illi Ii /� 1 a N N l i / / / Bit Ii V i JIp ,1 j Unit No. 8126-2 5-10-07 FHL Double-Grip Large Bore Hydrostatic Single Rev. A Page 4 of 7 String Packer FHL Double-Grip Large Bore Hydrostatic Single String Packer Assembly and Dimensional Data Drawing No. 186-095 2 6 9 11 13 15 17 19 20 23 25 28 30 31 34 35 37 39 41 37 44 46 48 49 5 8 10 12 14 16 18 15 22 24127 29 32 33 50 36 38 40 42 43 45 47 B..... . -rr►`l—r L 1 YY _ MIIh1Mlli=li - L � %.1r r fill/ s� —`—I lir 1 010 atria 01® III ellllllllllllll rl K 1 1 1 A i E D F F G r G H J —M— L,H. THD L.H, THD N--- GREASE P PACK Q - - R- S Assembly and Dimensional Data Drawing No. 185-972 36 1 5 8 10 12 14 7 17 19 15 20 22 25 28 30 32 34 37 39 42 37 44 46 49 B 2 6 9 11 13 15 16 18 24 27 29 31 33 38 40 41 43 40 45 48 L ---:Ii���rr i iris--��-..'iasi�i�J�� '�os�mr.. Y W\.11 R:�:R_a Ra'i' MIM � a_� �33cr-iii• q� KE1BY u110 I- WPM. A ct I 50 47 K D LF F 6 G H GREASE J —M— PACK N L.H. THD P 0 R S F T Assembly Drawing No. 186-150 OPTIONAL ROTATIONAL RELEASE 54 55 56 57 54 56 57 iamitaW lil MINIII I Mill uI!hiI_ IIliuu1uI JIIIJNIll■ SIZE 47 W/ 3.000 BORE SIZE 51 W/ 4.000 BORE .... .. FARO BAKER HUGHES Tool Ratings Type of Tool : Sliding Sleeve CMU F.E. : Aaron Miller Date : 11-April-14 A --; 1 t CMU Non-Elastomeric Sliding Sleeve 2.312" Size: 2.875, 2-7/8"Tubing Max Working Pressure: 10,000 PSI @ 100-375°FE Tensile: 140,000 lbs Torsional Rating: 2,300 ft-lbs Connection Rating: 2,810 ft-lbs'` Threads: 2.875 IN 6.50 LB/FT EU 8RD Profile: 2.312 BX Commodity Number: H810-79-3833 3.750" Material: 9Cr-1 MO 80 KSI MYS Shifting Tool: H811-19-2250 --46" 4 I- I. I M I" E 375°F service temperature with a 1,500 psi maximum shifting differential, 50 open/close cycles * Maximum Final Make Up Torque(ft-lbs),API Recommended Practice 5C1 "Nominal Dimension • 2.312" • 1 i NOTE:Shear forces and pressures recommended on this tool rating sheet are theoretical values only,calculated from nominal shear screw values and nominal piston areas.Observed shear values in the well may vary due to tolerance in shear strength of screws,internal tool friction,mud lubricity,cuttings or other solids in the mud and a number of other variables.Tools which shear"out of range"do not necessarily indicate a tool malfunction. This document is and contains unpublished,copyrighted and confidential information of Baker Hughes,and is revealed for limited purposes only.This document is the property of Baker Hughes and is to be returned to Baker Hughes on request and may not be reproduced,used or disclosed to persons not having a need to know consistent with the purpose of the document,without the written consent of Baker Hughes.This document is not rented,loaned or sold,either alone or in conjunction with equipment or product. ©5/11/2013 Baker Hughes Incorporated. Page 1 of 1 HALLIBURTON Engineering Data Sheet EQUIPMENT MATERIAL NO.: 102009618 SELF-ALIGN MULESHOE GID,5.250,4 3/4-8 PART NUMBER: 212SDG52500-F DESIGN SPECIFICATIONS MAXIMUM OD 5.220 inch MINIMUM ID 4.100 inch LENGTH 39.67 inch MATERIAL 13%CHROME MATERIAL YIELD STRENGTH-MIN 80000 pounds/sq.inch TOP THREAD 4 3/4-8 UN-2B CONNECTION TYPE BOX MATING SEAL BORE ID-MIN 5.250 inch SERVICE H2S/CO2 SERVICE REMARKS H2S AND/OR CO2 SERVICE BASED ON CUSTOMER DEFINED, WELL SPECIFIC CONDITIONS. APPLICATIONS MUST BE REVIEWED FOR SPECIFIC ENVIRONMENTAL COMPATIBILITY. COMPRESSION LOAD RATING,CALC/1000 30.0 pound DRIFT 102009622(81T25349)5.248/5.252 (O.D. DRIFT) BDMI/TECHNICAL OPERATIONS MANUAL 212SDG00000 TEST FIXTURE 101660143(83MO623),ASSEMBLY AND(DRIFT O.D. COMPRESSION FIXTURE , 1404/863134T2MS808), 6-32 BOL (END) (Unless specified,Dim-inches,pres-psi,weight-lbs,temp-deg F) NOTE:Values of pressure,force and operating depths presented above are based upon empirical data and theoretical calculations.These values will vary within accepted engineering limits due to variations in material strength,dimensional tolerances and actual installed conditions. NOTE:Halliburton makes no warranty,either expressed or implied,as to the accuracy of the data or of any calculation or opinion expressed herein.Halliburton,Dallas,Texas,U.S.A. • I 5 I 4 I 3 I 2 I 1 D 0 0 0 0 ATASSEMBLIVE ©O D A.1_ C ...----rlt , Ib ._ hb .. C A...I "AR SECTION A-A ASSEMBLY NOTES: 1.ASSEMBLE WITH CAUTION-DO NOT ATTEMPT TO ASSEMBLE IMTHOUT THE ASSEMBLY FIXTURE LISTED ON THE DSO. p B 2.ON THE ASSEMBLYTFIXTURE AND COMPRESS THE SP NG4UNTIL THE HOES V,THE SDL EV AND SMANND EL L NEE UP. B 3.INSTALL LUGS((TEM 3)FROM THE INSIDE THROUGH THE SLOTS IN THE ASSEMBLY FIXTURE END PLATES.ONE METHOD IS TO OR WIRE TO THE A HOLE LTAND USEN NOUTEEDLE NOSE PLIERS EACH O PULL THE LUG INTO PPLL.ACE.OR WIRE,THEN FISH THE STRING ORROoFls�Oaairn"iTF+iNn)ON AYANYM11FmSINCI umn ARE TAe°xvFFR ISGROH-1 a°txcFdr"IINAccwOINCF ,IIi s9I WANONHL T.PO ICY INS DOiladietA,Ms caerre.fr6 Aft 4.WITH ALL FOUR LUGS IN PLACE,LOOSEN THE ASSEMBLY FIXTURE ENOUGH TO CHECK THAT THE SLEEVE IS BEING ro. UNLESS OTHERWISE SPECIFIED s m+)m HALLIBURTON .'� NOOSTCNT .— PUSHEDOUTBYTHESPRINGANDTHELUGSARENOTBINDINGINTHEIRHELICALTRACKS. .AN VOO CO BUCCB ORAIxMi swuas '."'1nnE ...ATM ENERGY _ 2.CMeRARECE IIONOCO 5.WITH THE LUGS JUST STARTED IN THEIR TRACK(THE SPRING COMPRESSED)DRIFT THE OD.THEN COMPLETELY �• FARCATIW ; .. ...9_• 2+29D0.TOWOF SELF ALIGNING MULE SHOE GUIDE LOOSEN THE FIXTURE WHILE WATCHING TO SEE THAT THE SLEEVE DOES NOT BIND AND DRIFT THE OD AGAIN. ..Dr/4::/.4',,'"::,=,::".,74174, REIR.gAv uE114rµo - _4 5.250 BORE 4 3/4-0 UN-2B B.INSTALL THE MULE SHOE(ffEM 8 USING IOC-TTE AND THE SET SCREWS(ITEM I3 FILE OR GRIND THE SET SCREWS MinAP4°"�" nE - g A FLUSH WRH THE OD AND THEN DRIFT THE OD AOAN AND DRIFT THE ID IF THAT DRIFT IS LISTED ON TiE DSD. �,`7:=1 I\ Gel ovc.xo. 212$DG525DD-F IN' p1....,gs. a.4�.�.0. Eki i Awrr:Pluisw=JL ® a , Ivhlcxr.sn lOWE:r+ 5 I 4 1 3 1 2 SES , m 1 ,,.,,, 2 KBMG OM/Product Description 2 Upper swage N N N o —Body N a) N u- o O D a O O II O O Guard rail/ —Tool discriminator control line protector 5 (optional) g Integral connection Lu (LTS) 4d•' / Lug(LTS) i —Pocket 0111 4114 Or, .41 o41. 0 —Lower swage M N / N Standard LTS Configuration Configuration _c oFigure 1-1: KBMG mandrel 1.2 Features and Benefits • Tool discriminator excludes larger tools from pocket area. CES • Orienting sleeve facilitates kickover tool alignment in highly deviated wells. m Private–Customer Use Copyright©2012 Schlumberger, Unpublished Work. All rights reserved. 9 KBMG OM/Specifications 9 3 Specifications 3.1 Engineering Data TAB DATA 1 o Attribute co �; Value N [ACTIVE FLOW WETTED MATERIAL-YIELD STRENGTH(KSI) 4130[80] `s, 'APPROXIMATE WEIGHT(LBS) 123 E3 'CASING-MIN.RECOMMENDED DUAL,SIZE(IN),WT(PPF) 9.625,47.00 u_ 1 CASING-MIN.RECOMMENDED,SIZE(IN),WT(PPF) 5.500,15.50 'CERTIFICATION STATUS STD SLB -§ DIMENSION(CRITICAL LENGTH)-L5(IN) 47.000 g DIMENSION(MAJOR O.D.)-OD2(IN) 4.750 DIMENSION(MINOR O.D.)-OD1 (IN) 4.000 co DIMENSION(SWAGE,LOWER-MAX.I.D.)-ID2(IN) 2.376 [DIMENSION(SWAGE,LOWER-MIN.O.D.)-OD4(IN) 3.485 o DIMENSION(SWAGE,UPPER-MAX.I.D.)-ID1 (IN) 2.376 5 [DIMENSION(SWAGE,UPPER-MIN.O.D.)-OD3(IN) 3.485 cn p [DIMENSION-L1 (IN) 87.500 DIMENSION-L2(IN) 7.500 E-3 _ Ci' DIMENSION-L3(IN) 7.500 T N g DIMENSION-L4(IN) 1.718 ri Q I.D.-DRIFT(IN) 2.347 a> p I.D.-MIN.(IN) 2.366 m LOWER THREAD CONNECTING-SIZE(IN),WT(PPF),TYPE,CONFIG 2.875,6.50,EUE(TURNDOWN),PIN O MAKE-UP LENGTH(IN) 85 MATERIAL(KSI) LHT 4130[80], N MINOR DIA.BODY PIPE(IN) 4.000 N a 1 O.D.-DRIFT SIMULTANEOUS DUAL(IN) NA o [O.D.-DRIFT SINGLE(IN) 4.887 L U [O.D.-DRIFT STAGGERED SIMULTANEOUS DUAL(IN) 8.379 7 1— [OVERALL LENGTH(IN) 87.500 m 'POCKET SIZE(NOMINAL)(IN.) 1 [QUALITY CONTROL PLAN QCP STD SLB m [SERVICE NACE(YES/NO) YES 'SIZE i2-7/8 m [TENSILE STRENGTH(EOEC AT AMBIENT)(LBS)(80 KSI) 253000 a) 'TENSILE STRENGTH(EOEC AT AMBIENT)(LBS)(95 KSI) 300000 O [TENSILE STRENGTH(LBS) 145000 J m Private—Customer Use 3 Q Copyright©2012 Schlumberger, Unpublished Work. All rights reserved. KBMG OM/Specifications 9 TENSILE STRENGTH(LBS)-EOEC AT SPECIFIED TEMP(F) 253000[72] TEST PRESSURE EXTERNAL(EOEC)(PSI)(80 KSI) 5000 1TEST PRESSURE EXTERNAL(EOEC)(PSI)(95 KSI) I 6000 TEST PRESSURE EXTERNAL(PSI)(KSI) 5000[80] 1TEST PRESSURE INTERNAL(EOEC)(PSI)(80 KSI) 6000 11-EST PRESSURE INTERNAL(EOEC)(PSI)(95 KSI) 7500 1TEST PRESSURE INTERNAL(PSI)(KSI) 6000[80] THREAD NUMBER Al THREAD RECUTS ZERO[0] [UPPER THREAD CONNECTING-SIZE(IN),WT(PPF),TYPE,CONFIG 12.875,6.50,EUE(TURNDOWN),BOX Private—Customer Use Copyright©2012 Schlumberger, Unpublished Work. All rights reserved. 1 KBMG OM/Specifications 9 3.2 Fishing Diagram L1 Overall Length(in) 87.50 OD3� ID1 L5 Critical Length (in) 47.00 001 Minor OD(in) 4.000 OD2 Major OD(in) 4.750 0OD3 Swage(Upper)Min OD(in) 3.485 OD4 Swage(Lower)Min OD(in) 3.485 N I01 Swage(Upper)Max ID(in) 2.376 IO2 Swage(Lower)Max ID(in) 2.376 o L1 o L5 a rn co co rn 5 2 N ' O co OD1/OD2 m N a) N M N N0 r/ 1D2 OD4 t _ Figure 3-1: KBMG Fishing Diagram m m c6 m L J Private—Customer Use c9 Copyright©2012 Schlumberger, Unpublished Work. All rights reserved. Schlumberger Camco Dummy Valves Isolation devices that prevent communication between the tubing and the casing APPLICATION Camco*retrievable dummy valves have two sets of packing that • Mandrel strings without gas lift valves straddle and pack off the casing ports in the side-pocket mandrel. or side-pocket accessories This line of valves comprises the 1-in[25.4-mm]OD E and DK-1 BENEFIT valves and the 11A-in[38.1-mm]OD RD valve. • Reliable operation OPERATION FEATURES Communication between the tubing and the casing is positively • Premium materials sealed off until the dummy valve is retrieved from the side-pocket mandrel using standard slickline methods. • Precision manufacturing Engineering Data for Camco Dummy Valves Valve Nominal OD, Latch Running Pulling Mandrel Type in[mm] Tool Tool Series E 1.000 125.4] BK series JK JDC KBM,KBMM, KBMG,KBG DK-1 1.000(25.41 Integral GA-2 JDCt KBM,KBMM, bottom KBMG,KBG RD 1.500(38.11 RA JC-3 JDC MMA RD 1.500138.11 RK RK-1 JDS MMM,MMG, MMRG 'Use core extension with this wiling tool for integral bottom latch valves. i I ri l `J a ip DK-1 dummy valve. RD dummy valve. 'Vent et Scnunbvger Odle,canpe.cy product and zeruce Rennes are tte prapernes d Mee rYSpeStiYe owners am2ezSet mr•pergee.utigmrase iaAL-mz www.slb.com/artificlallift :, Schlomherger . • • CanicoSiogIePoiot Orifice Gas Lift Valves Retrievable valves for continuous tubing flow production APPLICATION An integral choke controls the flow of gas that passes through the • Continuous tubing flow production normally open Camco*single-point injection orifice gas lift valve into _ the production tubing.This reliable line of valves comprises the 1-in BENEFITS • Reliable operation [25.4 mm]OD DKO-2,BKO-3, and OM 21R valves and the 1i4 in Iii 11 [38.1-mm]OD RD0-20,0-21R,and 02-30-R valves.02-30-R valves Jim • Highly efficient and '_ 9 IY have dual reverse-flow checkvalves.DKO-2 valves have nonfloating, economical performance replaceable chokes,while the others have floating chokes.All the FEATURES valves contain integral reverse-flow check valves. • Field-proven design Pon sizes • Integral reverse-flow check valves Port sizes for these valves are available in 46-in[1.6-mm]increments. and replaceable floating and • 1-in[25.4-mm]OD valves: nonfloating seats DKO-2 valve ports are available from 1/4 to%in[32 to 9.5 mm]. BKO-3 valve ports are available from Y to 1'S11 in[3.2 to 7.9 mm]. OM-21R valve ports are available from''to MIM in[3.2 to 11.1 mm]. • 1Y2-in[38.1-mm]OD valves: RD0-20 valve ports are available from%to%in[3.2 to 12.7 mm]. I1 0-21R valve ports are available from 1 to w%in[3.2 to 17.4 mm]. 02-30R valve ports are available from i to 34 in[32 to 15.9 mm]. Operation Injection gas enters the valve through the external ports between the valve packing seats and travels through the choke,past the reverse- flow check valve,and into the production tubing. e If i Engineering Data for Camco Single-Point Injection Orifice Gas Lift Valves ; `. Valve Type Nominal OD, Latch Running Pulling Mandrel l'. in[mm] Tool Tool Series .'s DK0-2 1.000[25.4] Integral GA-2 JDC' KBM,KBMM, bottom KBMG,KBG BKO-3 1.000[25.4) BK series JK JDC KBM,KBMM, KBMG,KBG OM-21R 1.000[25.4] BK series JK JDC KBM,KBMM, KBMG,KBG R0O-20 1.500(38.1) RA JC-3 JDC MMA 1 F100-20 1.500[38.1] RK RK-1 JDS MMM,MMG, MMRG • 0-21R 1.500[38.1] RA JC-3 JDC MMA • ili! 0-21R 1.500[38.1] RK RK-1 JDS MMM,MMG, MMRG 02-30R 1.500[38.1] RA JC-3 JDC MMA BKO-3 orifice valve. 02-30R 1.500[38.1] RK RK-1 JDS MMM,MMG, MMRG '!.tan;ch scn.retterger 'Use core extension with this pulling tool for integral bottom latch valves. uther canpenr•.rrar,n and sen,ce names are the araperces et mem rnpeative cycler, :.payeg+rc:d 2V2 Schknaerget.NI rights reserve[UAL OIGC www.slb.com/gaslift .. . Schiumberger Camco Valve Top Latches For locking retrievable gas lift valves and side-pocket accessories without integral latches in the appropriate side-pocket mandrels APPLICATION Camco*retrievable valve top • Normal and corrosive latches comprise the BK-2, I downhole environments BK-4,BK-5,BEK-2,BEK-3,RA, RK,RK-1,and RKP latches. I ; FEATURES 1 t I I + , • Available in a varietyof materials for a BK-2,BK-4,BK-5,BEK-2,and1 wide range of applications BEK-3 spring-loaded,ring style L' • Ring-and cam-style latches for various latches lock 1-in[25.4-mm] �1• is i •s • •• OD valves and accessories in lie ' is a • ; • applications and mandrel types12 'III the appropriate Camco KBM, a •• .• • KBMM,KBMG,and KBG ., _ series mandrels. II I II' I r IANBK-4 and BK-5 latches fea- ture a tangential locking pin in the latch stop,similar to RK latches.The no-go angle on BK-2 BK-4 BK-5 BEK-2 the BK-5 latch stop is a 15° bevel,compared with 30°for the fir. a /other latches.BEK 2 and BEK 3 I — I I III. latches allow flow through11 - the latch center and have a i� Il I�l -I 1 0.375-in[9.5-mm]bore.BEK-3 I 1 I'lt 1 latches have a specially treated, �a iAir i' ■ • erosion-resistant ID and are --. I ideal for use with circulating or ; � a ■ flow devices. e e - RA latches and RK,RK-1,and j N �I a I , RKP spring-loaded,ring-style latches are attached to i -in I N. I I [38.1-mm]OD valves and acces- I is sories in the appropriate L • ? Camco mandrels. RA RK RK-t RXP • RA latches are used in MMA series mandrels. • RK latches are used in MMM,MMG,and MMRG mandrels. • RK-1 and RKP latches are used in MMG and MMRG mandrels. RK latches have two 0-rings on the latch stop to provide a debris barrier at the top of the mandrel pocket RK-1 latches feature longitudinal grooves that serve as flow conduits between the latch and the mandrel pocket,while RKP latches allow flow through the latch center and have a 0.453- in[11.5-mm]bore. . . Valve Top Latches Engineering Data for Caeca Valve Top latches Type Mex.Running OD, Mi..ID, Side Pocket Accessory 0D, Running Head Finking Neck Running Pulling in[mm] in lnim] in(ern] OD,in[rum] OD,in[mm] Tool Tool BK-2 1.358134.51 NAt 1.000125.41 0.750[19.11 0.875122.21 JK 1.250-in JDC BK-4 1.358[34.5] NA 1.000[25.4] 0.750119.11 0.875[22.2] JK 1.250-in JDC BK-5 1.358[34.5] NA 1.000[25.4] 0.750[19.1] 0.875[22.2] JK 1.250-in JDC BEK-2 1.358[34.51 0.375[9.51 1.000[25.41 0.750[19.1] 0.875[22.2] JK 1.250-in JDC BEK-3 1.358[34.51 0.375[9.5] 1.000[25.4] 0.750[19.1] 0.875[22.2] JK 1.250-in JDC RA 1.750[44.5] NA 1.500[38.1] 1.359[34.51 1.343[34.1] JC-3 2.000-in JDC RK 1.786[45.4] NA 1.500[38.1] 0.937[23.8] 1.187130.11 RK-1 1.625-in JDS RK-1 1.786[45.4] NA 1.500[38.1] 0.937[23.8] 1.187[30.1] RK-1 1.625-in JDS RKP 1.786[45.4] 0.453[11.51 1.500[38.1] 0.937[23.8] 1.187[30.1] RK-1 1.625-in JDS Not applicable 1 'Merit Schlumberger altar company,product and sewne mens arc the araPertDss C1 thewreapectioe Meats £epynaM2,2al2 soh lumberpr All rights reserver 12-AL 012211 0 ...72....._....._-- el PARTS LIST 0 A4. ITEM DESCRIPTION PART NUMBER QUANTITY W, A © 1 Upper Packing Barrel 01077-013-00000 1 2 *Packing JM 01057-005-00000 �— 4 ( � (1-1/32" x 23/32") v 3 *Adapter Ring 01057-006-00000 __ 2 V 11 4 Lock Ring 01077-002-00000 1 0 5 *0-Ring 01057-008-00000 1 l 6 Spring Retainer 01077-004-00000 1 r,' I17 O 7 C-Spring 01077-005-00000 _ 1 I8 Piston 01077-006-00000 1 1 © 9 *0-Ring #015 01334-001-00000 1 1 10 Shear Screw See Chart for Part • (4-40 x 1/4 Lg.) Number ,' - 11 Shear Screw See Chart for Part IN �� 12 (2-56 x 1/4 Lg.) Number Body 01077-003-00000 1 _ ,�A'\ 7 13 *0-Ring #012 01009-007-00000 1 * ` 'i 14 Nose 01077-007-00000 1 17 it15 *Packing 01077-008-00000 4 II 9 16 *Packing MF (1-1/32" x 23/32") 01057-005-00000 8 17 *0-Ring #111 01053-013-00000 1 t; FiL.CEIVED STATE OF ALASKA ALF &OIL AND GAS CONSERVATION COMM. MON ‘`., `' i t/ ' :'? REPORT OF SUNDRY WELL OPERATIONS 11.Operations Abandon U Repair Well ❑ Plug Perforations LI Perforate ❑ Other U Tubing Punch Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown 0 Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Pioneer Natural Resources Alaska LLC Development] Exploratory❑ 210-142 • 3.Address: 700 G Street,Suite 600 Stratigraphic Service ❑ 6.API Number: Anchorage,AK 99501 50-703-20624-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: .. ADL 355036/ADL 355037 ODSN-18 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): t. N/A Oooguruk- Nuiqsut Oil Pool 11.Present Well Condition Summary: Total Depth measured • 16,689 feet Plugs measured N/A feet true vertical 6,229 feet Junk measured N/A feet Effective Depth measured 16,399 feet Packer measured See Attachment,pg 3 feet true vertical 6,232 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3,557' 11-3/4" 3,600' 3,309' 5,830 psi 3,180 psi Drilling Liner 5,504' 9-5/8" 3,320'-8,824' 3,124'-5,329' 5,750 psi 3,090 psi Tie-Back 8,270' 7" 8,308' 5,149' 7,240 psi 5,410 psi Intermediate 3,801' 7" 8,289'-12,090' 5,143'-6,175' 7,240 psi 5,410 psi Liner 4,485' 4-1/2" 11,915'-16,400' 6,144'-6,232' N/A ,7 N/A Perforation depth Measured depth See Attachment,pg 2 feet sCANNED MAY 2 7 2014 True Vertical depth See Attachment,pg 2 feet Tubing(size,grade,measured and true vertical depth) 2-7/8",6.5# L-80,IBT-M 10,986'MD 5,948'TVD Packers and SSSV(type,measured and true vertical depth) See Attachment,pg 3 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDM5424111AY 15 2014 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl I Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A-Well shut-in as of Q3-2013 Subsequent to operation: 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory El Development] * Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil .plj Gas ❑ WDSPL LI GSTOR ❑ WINJ ❑ WAG ❑ GIN • 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: 314-061 Contact Jack Kralick,343-2185 Email jack.kralickapxd.com Printed Nam Jack Kralick Title Wells Supervisor Signature 16(--4/ . Phone 343-2185 Date /r D/� Pioneer Natural Resources Alaska LLC ODSN-18 Page 2 AOGCC Form 10-404, Report of Sundry Present Well Condition - Box #11 Perforation Depth (MD/TVD) - Attachment 4-W, 12.6#, L-80 Hyd 521 Uncemented Liner Perforated Pups w/6-1/2" Holes @ depths listed: MD TVD 12,302' - 12,306' 6201' - 6202' 12,506' 11' ' - ' 2 506 5 6222 6222 12,628' - 12,632' 6225' - 6225' 13,005' - 13,009' 6211' -6211' 13,168' - 13,173' 6207' -6207' 13,535' - 13,540' 6217' -6217' 13,734' - 13,739' 6230' -6230' 13,934' - 13,939' 6233' -6233' 14,138' - 14,143' 6235' -6235' 14,300' - 14,304' 6239' -6239' 14,463' - 14,468' 6242' -6242' 14,840' - 14,844' 6238' -6238' 15,043' - 15,048' 6244' - 6244' 15,247' - 15,252' 6242' - 6242' 15,448' - 15,453' 6249' -6249' 15,648' - 15,653' 6251' - 6251' 15,867' - 15,872' 6239' -6239' 16,029' - 16,034' 6232' -6231' 16,234' - 16,239' 6230' -6230' Pioneer Natural Resources Alaska LLC ODSN-18 Page 3 AOGCC Form 10-404, Report of Sundry Well Operations Present Well Condition Summary, Box #11 Present Well Condition Summary attachment: Packers and SSSV (type, measured and true vertical depth) SSSv TRMA)OX-5E SSSV (Locked Open) 2068' MD /2043' TVD Packers Hydro II Packer w/ Gas Vent Valve 2570' MD /2523' ND 11-3/4" x 9-5/8" Liner Hanger Packer 3320' MD / 3123' ND 7" x 9-5/8" Liner Top Packer 8308' MD / 5150' ND Arrow Pak Retrievable Packer 11,873' MD /6136' ND 4-1/2" x 7" Liner Top Packer 11,930' MD /6147' ND pp PIONEER Operations Summary Report-State Well Name: ODSN-18 NATURAL RFSOURCES Well Name: Contractor: Rig Number: Job Category: Start Date: End Date: Start Dep lh Foot'Meters Dens Last Start Date End Date (ttKB) (ft) Mud(Ibbaft Summary 2/4/2014 2/5/2014 0.0 MIRU HES slickline on ODSN-18 to begin the pre RWO work scope. *Ensure that the flap on the ScSSSV is in the open position. *RIH with a 2.25"gauge ring to 8500' 2/5/2014 2/6/2014 0.0 2/6/2014 2/7/2014 0.0 *Monitor wind speed * Bled csg psi off 2/7/2014 2/8/2014 0.0 *Monitored wind. *Slickline crew on island and continue with pre-rig workover program. *Pulled OV from GLM 8374 SLM *Attempt to set 1-1/2 DGLV with no success *POOH *SDFN 2/8/2014 2/9/2014 0.0 Continue with Pre Rig Workover activities. *Set DGLV in GLM#1 @ 8,374"SLMD. *Pull Orifice Valve from GLM#3 @ 2,464'MD *Make dummy XX Plug run. *Freeze protect I/A.&Tubing w/diesel *Set 1-1/2"DGLV into GLM#3 @ 2,464'MD. *Call out HES E-Line to punch holes in tubing below Hydrow-II 2/9/2014 2/10/2014 0.0 .Continue with Pre Rig Workover activities. *Rig up E-Line for tubing punch. *Tubing punch was completed and E-Line rigged down and slickline was called back. *Lube&bleed tbg. *Displace tbg w/diesel 15 bbls. *Rig up slickline&set"XX"plug. *Pressure test to 2500 psi. *Bleed off tbg pressure. 2/10/2014 2/11/2014 0.0 Continue to monitor tubing for gas. III 2/17/2014 2/18/2014 0.0 Move in rig up for slickline activities. *Move HES slickline and LRS hot oil equipment. *Spot CH2 crane. *RIH w/2.25 OD gauge Ring 2486'SLMD' *RIH w/ Equalizing Prong&equalize"XX"plug at 2689'SLMD. *RIH w/"GR"Pulling Tool&Latch&Pull"XX"Plug at 2489'SLMD 2/18/2014 2/19/2014 0.0 Continue with Pre Rig Workover activities.. *Recovered"XX"Plug. *Attempted to displace tbg w/diesel. *Tbg pressured up to 2400 psi. *Set"XX"plug in SSSV &retrieved. *Set"XX"Plug in"X"nipple at 2516'MD. *Suspend operations due to weather-47. *Monitor temperature. 2/19/2014 2/20/2014 0.0 Monitor Temperature. 2/20/2014 2/21/2014 0.0 Monitor Temperature. 2/21/2014 2/22/2014 0.0 Continue with Pre Rig WorkoverActivites. *RIH equalize"XX"plug. *Thaw out stuffing box on lubricator. *Pull"XX"plug from 2489'slm. *LRS pressured up tubing to 3500 psi,unable to establish injection rate. *LRS pressured up tubing to 4000 psi,unable to establish injection rate. *Consult with town,decision made to rig down HES Combo Unit and move over to ODSN-24. Page 1/2 Report Printed: 4/7/2014 Operations Summary Report-State Well Name: ODSN-18 PIONEER NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud MAIM) Summary 3/15/2014 3/16/2014 0.0 MIRU HES Eline for Pre-Rwo. *Drift with 2"dummy drift(2"weight bar&CCL)to 10,700'ELMD.Unable to get any deeper. Target depth was 10,877'ELMD. *RIH with guns and correlate with CCL to the GLM and X nipple *Tag 10.720 and correlate collars. *At 10,656.7'with top of guns and fire.!/ *POOH and RDMO l�i2(/ 3/17/2014 3/18/2014 0.0 MIRU SLB coil unit. *Change 2"reel to 1 3/4"coil. v J 3/18/2014 3/19/2014 0.0 Complete coil reel swap from 2"to 1-3/4".MIRU SLB Coil. MIRU SLB coil with 1-3/4"coil. *Test BOPs with LRS. 3/19/2014 3/20/2014 0.0 Ru lines to sparge tank.Drift 1-3/4 CT with 7/8 od ball.Begin testing BOP,s,bonnet leaked.Order parts out&fix. 3/20/2014 3/21/2014 0.0 Fixed BOPs&Retest BOP,s.MU BHA&RIH. 3/21/2014 3/22/2014 0.0 RIH to 10877'CTMD&tag ADV.Circulate 10.1#Brine.Freeze protect with diesel from 2500 ft.RD SLB CTU#1.RU HES slickline.Shut down for high winds. 3/22/2014 3/23/2014 0.0 Monitor wind speed.Resume operations when wind speed fell below 30 mph.RIH with gauge ring to 2570'ft SLMD.Bled tbg 564 psi to 0 psi.RIH set 2.313"XX"plug in"X"nipple at 2489'ft SLMD.PT plug to 1000 psi 15 min.RD HES slickline.PT IA to 2500 psi.move HES slickline to ODSN 28.Tum well over to Op,s. Page 2/2 Report Printed: 4/7/2014 _ ,/ ® ®7I/ - B HE STAT .-'1 c',: y, _ r , ?6- s}{ 1 333 West Sevenih Avenue d^" �i�',\'t:R 10R SEAN PARNE;I[. Anchorage, Alaska 995Ci 572 r s.,_ �Aai 907.2v9 1/33 � L, , . C„7.?/ Is/, Alex Vaughana. I 0 — 1 L -' Sr. Drilling Engineer l Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-18 S(p,NHcD Sundry Number: 314-061 Dear Mr.Baughan: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, l , / Cathy Foerster Chair Si- DATED this'day of January, 2014. Encl. , RECEIVED . . STATE OF ALASKA ` -/`jr ejJJA 292014 ALASKA OIL AND GAS CONSERVATION COMMISSION �S // 3o// -- APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1.Type of Request: Abandon 0 Plug for Redrill 0 Perforate New Pod 0 Repair Well 0 Lq•/N Change Approved Program 0 Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 lime Extension 0 Operations Shutdown 0 Re-enter Susp.Well 0 Stimulate 0 Alter Casing 0 Other:4=24,1 4_k i wi 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Exploratory 0 Development 0• 210-142• 3.Address: 700 G Street, Suite 600 Stratigraphic 0 Service ❑ 6.API Number: Anchorage,AK 99501 50-703-20624-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ODSN-18- Will planned perforations require a spacing exception? Yes 0 No Q . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036 /ADL 355037 • Oooguruk-Nuiqsut Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 16,689' • 6229' . 16,399' • 6232' ' N/A N/A Casing Length Size MD ND Burst Collapse Conductor 110' 16" 158' 158' N/A N/A Surface 3557' 11-3/4" 3600' 3309' 5830 psi 3180 psi Drilling Liner 5504' 9-5/8" 3320'-8824' 3124'-5329' 5750 psi 3090 psi Tie-Back 8270' 7" 8308' 5149' 7240 psi 5410 psi Intermediate 2 3801' 7" 8289'-12,090' 5143'-6175' 7240 psi 5410 psi Liner 4485' 4-1/2" 11,915'-16,400' 6144'-6232' 8430 psi 7500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment, pg. 2 / See Attachment, pg.2 2-7/8",6.5# L-80, IBT-M 10,986' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): See Attachment, pg.3 / See Attachment, pg.3 12.Attachments: Description Summary of Proposal El- 13.Well Class after proposed work: I Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development❑r • Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 1/29/2014 Oil In • Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned 0 Commission Representative: GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alex Vaughan,343-2186 Email alex.vaughan@pxd.com Printed Name Alex Vaughan Title Sr. Drilling Engineer Signature -hone Date .4111111r001.17- 343-2182 1/28/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ‘4"-( r 1 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: RBDM MAY 1) 9 2014 Spacing Exception Required? Yes 0 No r7 Subsequent Form Required: /6 —yo Y I r1 APPROVED BY Approved by: / J � _ COMMISSIONER THE COMMISSION Date: /- 3/.74,)ll� II Submit Form and ,_Form 10-403( evised 10/2012) Appr RlitaG INf 1 months from the date of aYoyal. Attachments in Duplicate RECEIVE® • PIONEER JAN 292014 NATURAL RESOURCES ALASKA AOGCC Pioneer Natural Resources Alaska, Inc. 700 G Street,Suite 600 Anchorage,Alaska 99501 Tel:(907)277-2700 Fax:(907)343-2190 January 28th, 2013 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite#100 Anchorage, AK 99501 RE: ODSN-18 Sundry Application to Punch Tubing REF: Permit To Drill #210-142 Pioneer Natural Resources, Alaska (PNRA) is submitting a proposal to perforate the tubing of ODSN-18 to prep well for a forthcoming ESP Workover. The proposed plan is as follows: Pre-Riq Work: 1. RU slickline over ODSN-18. ,7 2. Tubing punch 2-7/8"tubing using 4 spf(45 holes total)from 2,590'-2,601.' MDrkb. 3. Sweep tubing with 1.5 tubing volume filter seawater. f 4. Displace filtered seawater with 2000'TVD of diesel freeze protection. 5. Run WRP at 1,500'. 6. Install BPV. Re-Complete ODSN-18 with ESP 1. (Sundry to recomplete ESP will be provided prior to ESP workover) Alaska Oil & Gas Conservation Commission January 28th, 2013 Page 2 of 2 Please find attached information for your review: 1) Form 10-403 Application for Sundry. 2) ODSN-18 Schematic The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Alex Vaughan, Senior Drilling Engineer (20 AAC 25.070) (907) 343-2186 alex.vaubhana,pxd.com 2) Geologic Data and Logs Paul Daggett, Operations Geologist (20 AAC 25.071) (907) 343-2134 paul.daggetta,pxd.com Sincerely, Al- - .. an Senior Drilling Engineer Attachments: Form 10-403 Supporting information cc: ODSN-18 Well File Pioneer Natural Resources Alaska Inc. ODSN-18 Page 2 Form 10-403, Application For Sundry Approvals Present Well Condition Summary, Box #11 Perforation Depth (MD/TVD) - Attachment 4-'/2", 12.6#, L-80 Hyd 521 Uncemented Liner Perforated Pups w/6-1/2" Holes @ depths listed: MD ND 12,302' - 12,306' 6201' - 6202' 12,506' - 12,511' 6222' - 6222' 12,628' - 12,632' 6225' - 6225' 13,005' - 13,009' 6211' - 6211' 13,168' - 13,173' 6207' - 6207' 13,535' - 13,540' 6217' - 6217' 13,734' - 13,739' 6230' -6230' 13,934' - 13,939' 6233' - 6233' 14,138' - 14,143' 6235' -6235' 14,300' - 14,304' 6239' - 6239' 14,463' - 14,468' 6242' -6242' 14,840' - 14,844' 6238' -6238' 15,043' - 15,048' 6244' -6244' 15,247' - 15,252' 6242' -6242' 15,448' - 15,453' 6249' -6249' 15,648' - 15,653' 6251' - 6251' 15,867' - 15,872' 6239' - 6239' 16,029' - 16,034' 6232' - 6231' 16,234' - 16,239' 6230' - 6230' • • Pioneer Natural Resources Alaska Inc. ODSN-18 Page 3 AOGCC Form 10-403, Application For Sundry Approvals Present Well Condition Summary, Box #11 Packers and SSSV Type (MD/TVD) - Attachment SSSV TRMAXXX-5E SSSV 2068' MD /2043' TVD Packers Hydro II Packer w/ Gas Vent Valve 2570' MD /2522' TVD 7" x 9-5/8" Liner Top Packer 8309' MD / 5150' TVD Arrow Pak Retrievable Packer 11,872' MD /6137' ND 4-1/2" x 7" Liner Top Packer 11,931' MD /6147' ND DDSN-18 Nuiqsut Production Well Completion- Current 1 ' 1) Dil CD iiiiiiii Casing 16" 109 ppf H 40 Conductor Item# Item MD(ft) TVD(ft MD 0 gill A 16"Conductor 158 1 Q J Packer Fluid mix: B 11-3/4"60#L-80 Hydril 521, 10.772" ID 3,600 33 Inhibited Kill weight C 9-5/8"40#L-80 Hydril 521, 8.835" ID* 8,824 56 r i .`."II wBithe TVD D 7'26#L-80 BTC-M,6.276" ID,Tieback 8,309 51 °"`°'` wth OE 7"26#L-80 Hydril 511,6.276" ID" 12,090 61 [. 10 -' diesel cap F 41/2" 12.6#Hydril 521 3.958" ID 16,400 62 G 2-7/8"6.5#L-80 IBT-M 10,986 59 11-3/4" 60 ppf L-80 Hydril 521 OB Surface Casing ________________________________________________________ @ 3600' MD/ 3309' TVD 1 VetcoGray Tubing Hanger 34 cemented to surface 2 2-7/8"Wellstar Tubing Retreivable ScSSSV 2,068 2,0' 3 GLM#1 -2-7/8"x 1-1/2"(min. 3 jts above top X nipple) 2,454 2,4' 7" 26 ppf L-80 2-7/8"XNipple 2.313" I.D. (min. 2jts above Gas Vent iiii,` — Intermediate 2 Casing 4 Valve Packer) 2,518 2,4 'i'i J )0 Tie-Back Sleeve 5 WFT 7'x 2-7/8"Gas Vent Valve Packer(max. TVD 2500') 2,550 2,5( • • H'I' @ 8308' MD/5150' TVD 6 GLM#2-2-7/8"x 1-1/2"(min. 2 jts above X nipple) 8,400 5,1( IIIII 0 iiiii 7 26 ppf L-80 BTC-M to 2-7/8"X Nipple, 2.313" ID(max. incl. 70 deg)w/RHC-M IV iii surface 7 Plug Body 8,464 5,2( 08 Automatic Divert Valve(ADV) 10,904 5,9; 9-5/8"40 ppf L-80 Hydril 521 9 ESP(Pump, Motor, and Jewelry) 10,914 5,9: 0000 Intermediate 1 Casing End of Assembly 10,986 5,9' @ 8824' MD/5307' TVD — (Top @ 3320' MD/3123' TVD) Up Item# Item MDrkb(ft) TVDrkb( O 10 WFT 7"x 3-1/2" Retrievable Packer 11,850 6,1: 11 WFT 3-1/2" Pressure Activated Sleeve 11,875 6,1; 12 WFT 3-1/2" Formation Saver Valve 11,900 6,1/ / 2-7/8" 6.5 ppf L-80 IBT-M Tubing 13 1 jt 3.5"TC-Il and WLEG 11,910 6,1' 0 S _ End of Assembly 11,945 6,1: Lower Completion 000 ° Item# Item MD(ft) TVD(ft �® 13 WFT PBR Tie Back Sleeve 15ft 11,915 6,1' \<uparuk OC Estimated 14 WFT"NTH" Liner Top Pkr 11,930 6,1' 00'above top of 15 WFT"PHR" Rotating Hyd Set Liner Hanger 11,934 6,1' 16 Resman Tracer Pup(heel location) 12,975 6,2' 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes), See separate attachrrer • 18 spaced eery 200'. €s; 19 Resman Tracer Pup(midlateral location) 14,708 6,Z ""` �s 20 Resman Tracer Pup(toe location) 15,814 6,2' `:.:. 21 Liner Shoe(PLUGGED)w/4-1/2"Hydril 521 16,398 6,2: 0 End of Assembly 16,400 6,2: 7" 26 ppf L-80 " �7 Hydril 511 S ��479/;- a ,g zo Intermediate 2 47/ ®'� o o a o . . 1 . 0 0 o a o 0 0 0 Casing o 0 0 0 a o o 0 0 0 0 , o o o @ 12090' MD/ 4 1/2' 12.6'' 21 6175' TVD ppf L-80 Hydril 521 4-1/2" 12.6#/ft L-80 Hydril 521 6-1/8" Hole TD at Liner Liner w/ Pre-Perforated pups at 16689' MD/ (6 holes—0.50" Diamenter) 6229' TVD spaced @ 200 ft apart RECEIVED STATE OF ALASKA �uyp� (3 ALASKA OIL AND GAS CONSERVATION COMMISSION 1 W JI ii.►g 2014 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug for Redrill 0 Perforate New Pod 0 Repair Well 0 Change Approved Program 0 Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing[l,// Time Extension 0 Operations Shutdown 0 Re-enter Susp.Well 0 Stimulate 0 Alter Casing Other.Run Clean-cut String 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Pioneer Natural Resources Alaska, Inc. Exploratory 0 Development ❑✓ // 210-142 3.Address: 700 G Street, Suite 600 Stratigraphic 0 Service 0J 6.API Number. Anchorage,AK 99501 / 50-703-20624-00-00 7.If perforating: .Well Name end Number. What Regulation or Conservation Order governs well spacing in this pool? N/A / ODSN_18 Will planned perforations require a spacing exception? Yes 0 No ❑✓ / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036 /ADL 355037 Ooogur ti-Nuiqsut Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TV (ft): Plugs(measured): Junk(measured): 16,689' 6229' 16,399' 62 ' N/A N/A Casing Length Size MD / TVD Burst Collapse Conductor 110' 16" 158' / 158' N/A N/A Surface 3557' 11-3/4" 3600' / 3309' 5830 psi 3180 psi Drilling Liner 5504' 9-5/8" 3320'-882f 3124'-5329' 5750 psi 3090 psi Tie-Back 8270' 7" 8308'i 5149' 7240 psi 5410 psi Intermediate 2 3801' 7" 8289'-18;090' 5143'-6175' 7240 psi 5410 psi Liner 4485' 4-1/2" 11,915't 16,400' 6144'-6232' 8430 psi 7500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size:/ Tubing Grade: Tubing MD(ft): t See Attachment, pg.2 See Attachment, pg.2 ?}7/8",6.5# L-80, IBT-M 10,986' Packers and SSSV Type: / Packers and SSSV MD(ft)and ND(ft): • See Attachment,pg. 3 See Attachment, pg.3 12.Attachments: Description Summary of Proposal 0.,/ X13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ / Exploratory 0 Stratigraphic 0 Development 9 Service 0 / 14.Estimated Date for F 15.Well Status after proposed work: 1/29/2014 ' Commencing Operations: / Oil Q Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: ,r WINJ 0 GINJ 0 WAG 0 Abandoned ❑ Commission Representative: GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to best of my knowledge. Contact Alex Vaughan,343-2186 / Email alex.vaughan@pxd.com Printed Name Alex Vaughan / Title Sr. Drilling Engineer Signature / Phone Date 343-2182 1/28/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so/that a representative may witness Sundry Number: /— 11 6 Plug Integrity 0 BOP Tst 0 Mechanical Integrity Test 0 Location Clearance 0 Other: i I Spacing Exception Required? Yes 0 No 0 Subsequent Form Required: APPROVED BY Approved by: / �� COMMISSIONER THE COMMISSION Date: l_ 5/._/e7. n n_i n I A_LA _1 Submit Form and RECEIVED PIONEER JAN282014 NATURAL RESOURCES ALASKA AOGCC Pioneer Natural Resources Alaska, Inc. 700 G Street,Suite 600 Anchorage,Alaska 99501 Tel:(907)277-2700 Fax:(907)343-2190 January 28th, 2013 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite#100 Anchorage, AK 99501 RE: ODSN-18 Sundry Application to Punch Tubing REF: Permit To Drill #210-142 Pioneer Natural Resources, Alaska (PNRA) is submitting a proposal to perforate the tubing of ODSN-18 to prep well for a forthcoming ESP Workover. The proposed plan is as follows: Pre-Rig Work: 1. RU slickline over ODSN-18 2. Tubing punch 2-7/8"tubing using 4 spf(45 holes total)from 2,590'-2,601.' MDrkb. 3. Sweep tubing with 1.5 tubing volume filter seawater. 4. Displace filtered seawater with 2000' TVD of diesel freeze protection. 5. Close ScSSSV 6. Install BPV Re-Complete ODSN-18 with ESP 1. (Sundry to recomplete ESP will be provided prior to ESP workover) Alaska Oil & Gas Conservation Commission January 28th, 2013 Page 2 of 2 Please find attached information for your review: 1) Form 10-403 Application for Sundry. 2) ODSN-18 Schematic The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Alex Vaughan, Senior Drilling Engineer (20 AAC 25.070) (907) 343-2186 alex.vaughan(a).pxd.com 2) Geologic Data and Logs Paul Daggett, Operations Geologist (20 AAC 25.071) (907) 343-2134 paul.daggetta,pxd.com Sincerely, Alex Y- •: - Senior Drilling Engineer Attachments: Form 10-403 Supporting information cc: ODSN-18 Well File Pioneer Natural kesources Alaska Inc. ODSN-18 Page 2 Form 10-403, Application For Sundry Approvals Present Well Condition Summary, Box #11 Perforation Depth (MD/TVD) - Attachment 4-'/2", 12.6#, L-80 Hyd 521 Uncemented Liner Perforated Pups w/6-1/2" Holes @ depths listed: MD TVD 12,302' - 12,306' 6201' -6202' 12,506' - 12,511' 6222' -6222' 12,628' - 12,632' 6225' - 6225' 13,005' - 13,009' 6211' - 6211' 13,168' - 13,173' 6207' - 6207' 13,535' - 13,540' 6217' -6217' 13,734' - 13,739' 6230' -6230' 13,934' - 13,939' 6233' -6233' 14,138' - 14,143' 6235' - 6235' 14,300' - 14,304' 6239' - 6239' 14,463' - 14,468' 6242' -6242' 14,840' - 14,844' 6238' -6238' 15,043' - 15,048' 6244' -6244' 15,247' - 15,252' 6242' - 6242' 15,448' - 15,453' 6249' - 6249' 15,648' - 15,653' 6251' -6251' 15,867' - 15,872' 6239' -6239' 16,029' - 16,034' 6232' - 6231' 16,234' - 16,239' 6230' - 6230' Pioneer Natural Resources Alaska Inc. ODSN-18 Page 3 AOGCC Form 10-403, Application For Sundry Approvals Present Well Condition Summary, Box #11 Packers and SSSV Type (MD/TVD) - Attachment SSSV TRMAXXX-5E SSSV 2068' MD /2043' TVD Packers Hydro II Packer w/ Gas Vent Valve 2570' MD / 2522' ND 7" x 9-5/8" Liner Top Packer 8309' MD / 5150' TVD Arrow Pak Retrievable Packer 11,872' MD /6137' ND 4-1/2" x 7" Liner Top Packer 11,931' MD /6147' ND ODSN-18 Nuiqsut Production Well Completion- Current iiii Casing Ali •••• 16"109 ppf H-40 Conductor Item# Item MD(ft) TVD(ft) © ii ii i A 16"Conductor 158 158 Nilili 0 J iiiiliii Packer Fluid mix: B 11-3/4"60#L-80 Hydril 521, 10.772"ID 3,600 3309 Inhibited Kill weight C 9-5/8"40#L-80 Hydril 521, 8.835"ID* 8,824 5607 a Brine D T'26#L-80 BTC-M,6.276"ID,Tieback 8,309 5150 i„iii with 2000'TVD 611111111 diesel cap E 7"26#L-80 Hydril 511,6.276"ID** 12,090 6175 ' = F 4-1/2"12.6#Hydril 521 3.958"ID 16,400 6232 a iiIiiiiE G 2-7/8"6.5#L-80 IBT-M 10,986 5948 11-3/4"60 ppf L-80 Hydril 521 Upper Completion 2 kilt Surface Casing Item# Item MDrkb(ft) TVDrkb(ft) 0 @ 3600' MD/3309'TVD 1 VetcoGray Tubing Hanger 34 34 cemented to surface 2 2-7/8"Wellstar Tubing Retreiveble ScSSSV 2,068 2,043 3 GLM#1-2-7/8"x 1-1/2"(min.3 jts above top X nipple) 2,454 2,415 s 7"26 ppf L-80 2-7/8"X Nipple 2.313"I.D.(min.2 jts above Gas Vent i€€ .:.: Iii;€ + Intermediate 2 Casing 4 Valve Packer) 2,518 2,475 `' J J 0 Tie-Back Sleeve 5 WFT 7 x 2-7/8"Gas Vent Valve Packer(max.TVD 2500 2,550 2,504 rili @ 8308' MD/5150'TVD 6 GLM#2-2-7/8"x 1-1/2"(min.2 jts above X nipple) 8,400 5,182 0 ?ii 7"26 ppf L-80 BTC-M to 2-7/8"X Nipple,2.313"ID(max. incl.70 deg)w/RHC-M ,iii , surface 7 Plug Body 8,464 5,204 O9 5/8"40 ppf L 80 Hydril 521 8 Automatic Divert Valve(ADV) 10,904 5,926 Intermediate 1 Casing 9 ESP(Pump, Motor,and Jewelry) 10,914 5,929 O•00@ 8824' MD/5307'TVD End of Assembly 10,986 5,948 (Top @ 3320' MD/3123'TVD) Up er Completion 1 0 10 WFT T'x 3-1/2"Retrievable Packer 11,850 6,133 11 WET 3-1/2"Pressure Activated Sleeve 11,875 6,137 12 WFT 3-1/2"Formation Saver Valve 11,900 6,142 / 2-7/8"6.5 ppf L-80 IBT-M Tubing 13 1 jt 3.5"TC-II and WLEG 11,910 6,143 00 Z End of Assembly 11,945 6,150 Lower Completion 00 Item# Item MD(ft) TVD(ft) � lii, TOC Estimated 13 WFT PBR Tie Back Sleeve 15ft11,915 6,144 14 WFT"NTH"Liner Top Pkr 11,930 6,147 500'above top of 15 WFT"PHR"Rotating Hyd Set Liner Hanger 11,934 6,148 Kuparuk 16 Resman Tracer Pup(heel location) 12,975 6,211 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes), See separate attachment 18 spaced every 200'. ® Q . 19 Resman Tracer Pup(midlateral location) 14,708 6,237 ,s 20 Resman Tracer Pup(toe location) 15,814 6,243 21 Liner Shoe(PLUGGED)w/4-1/2"Hydril 521 16,398 6,233 15 I;. 0 End of Assembly 16,400 6,233 7"26 ppf L-80.'ill Si& Hydril Y �� 0 s zo Intermediate 2 `��' ' o 0 0 '���� o 0 0 0 0 0 0 0 0 0 0 0 0 Casing 0 o 0 0 0 0 o a o a o 1° @ 12090' MD/ 4-1/2" 12.6''- ° 0 z, 6175'TVD ppf L-80 Hydril 521 4-1/2" 12.6#/ft L-80 Hydril 521 6-1/8"Hole TD at Liner Liner w/Pre-Perforated pups at 16689' MD/ (6 holes-0.50" Diamenter) 6229'TVD spaced @ 200 ft apart . . , RE EIVED STATE OF ALASKA j nlJ� :14 ALASKA OIL AND GAS CONSERVATION COMMISSION ''''''���d��'''' `"'I APPLICATION FOR SUNDRY APPROVALS AOrCC 20 MC 25.280 1.Type of Request: Abandon 0 Plug for Redrill 0 Perforate Nes Pod 0 Repair Well 0 Chang Approved Program 0 I Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension 0 Operations Shutdown 0 Re-enter Susp.Well 0 Stimulate 0 Alter Casing 0 Oth=.Run Clean-out String 0 2.Operator Name: 4.Current Well Class: 5.Permit to a rill Number: Pioneer Natural Resources Alaska, Inc. Exploratory 0 Development ❑✓ / 210-142 3.Address: 700 G Street, Suite 600 Stratigraphic 0 Service 0 6.APIs tuber. Anchorage,AK 99501 5003-20624-00-00 7.If perforating: 8.Well Name and/Number. What Regulation or Conservation Order governs well spacing in this pool? WA ,/ ODSN-18 Will planned perforations require a spacing exception? Yes 0 No 12 / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036 /ADL 355037 Oooguruk-Nuigsut it Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): PI gs(measured): Junk(measured): 16,689' 6229' 16,399' 6232' / N/A N/A Casing Length Size MD WD Burst Collapse / Conductor 110' 16" 158' /158' N/A N/A Surface 3557' 11-3/4" 3600' / 3309' 5830 psi 3180 psi Drilling Liner 5504' 9-5/8" 3320'-8824' /3124'-5329' 5750 psi 3090 psi Tie-Back 8270' 7" 8308' / 5149' 7240 psi 5410 psi Intermediate 2 3801' 7" 8289'-12,090' // 5143'-6175' 7240 psi 5410 psi Liner 4485' 4-1/2" 11,915'-16,400'/ 6144'-6232' 8430 psi 7500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment, pg.2 See Attachment, pg.2 2-7/8",6.515 L-80, IBT-M 10,986' Packers and SSSV Type: Pa/Ars and SSSV MD(ft)and TVD(ft): See Attachment,pg.3 $t?e Attachment, pg.3 12.Attachments: Description Summary of Proposal Q /13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 // Exploratory 0 Stratigraphic 0 Development Q Service 0 14.Estimated Date for / 15.Well Status after proposed work: Commencing Operations: 1/29/2014 / Oil Q Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: / WINJ 0 GINJ 0 WAG 0 Abandoned 0 Commission Representative: / GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the besot my knowledge. Contact Alex Vaughan,343-2186 / Email alex.vauohan@pxd.com Printed Name Alex Vaughan '+ Title Sr. Drilling Engineer Signature ' `- Prione Date -lir343-2182 1/28/2014 Adilli ,/ COMMISSION USE ONLY / Conditions of approval: Notify Commission so that/a representative may witness Sundry Number: /� �k - - c t Plug Integrity 0 BOP Test fj Mechanical Integrity Test 0 Location Clearance 0 Other: /f / / / Spacing Exception Required? Yes 0 No 0 Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: / Submit Form and in isI Form 10-403(Revised 10/2012) App : • a••I v lil*fits from the date of approval. Attachmentss in Duplicate PIONEERRECEIVED JAN 282014 NATURAL RESOURCES ALASKA q()(;CC Pioneer Natural Resources Alaska, Inc. 700 G Street,Suite 600 Anchorage,Alaska 99501 Tel:(907)277-2700 Fax:(907)343-2190 January 28th, 2013 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite#100 Anchorage, AK 99501 RE: ODSN-18 Sundry Application to Punch Tubing REF: Permit To Drill #210-142 Pioneer Natural Resources, Alaska (PNRA) is submitting a proposal to perforate the tubing of ODSN-18 to prep well for a forthcoming ESP Workover. The proposed plan is as follows: Pre-Rig Work: 1. RU slickline over ODSN-18 2. Tubing punch 2-7/8"tubing using 4 spf(45 holes total)from 2,590'-2,601.' MDrkb. 3. Sweep tubing with 1.5 tubing volume filter seawater. 4. Displace filtered seawater with 2000' TVD of diesel freeze protection. 5. Close ScSSSV 6. Install BPV Re-Complete ODSN-18 with ESP 1. (Sundry to recomplete ESP will be provided prior to ESP workover) Alaska Oil & Gas Conserv .on Commission January 28th, 2013 Page 2 of 2 Please find attached information for your review: 1) Form 10-403 Application for Sundry. 2) ODSN-18 Schematic The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Alex Vaughan, Senior Drilling Engineer (20 AAC 25.070) (907) 343-2186 alex.vaughanC).pxd.com 2) Geologic Data and Logs Paul Daggett, Operations Geologist (20 MC 25.071) (907) 343-2134 paul.daggettapxd.com Sincerely, 10111 Alex - .: Senior Drilling Engineer Attachments: Form 10-403 Supporting information cc: ODSN-18 Well File • Pioneer Natural resources Alaska Inc. ODSN-18 Page 2 Form 10-403, Application For Sundry Approvals Present Well Condition Summary, Box #11 Perforation Depth (MD/TVD) - Attachment 4-'/2", 12.6#, L-80 Hyd 521 Uncemented Liner Perforated Pups w/6-1/2" Holes @ depths listed: MD TVD 12,302' - 12,306' 6201' -6202' 12,506' - 12,511' 6222' -6222' 12,628' - 12,632' 6225' -6225' 13,005' - 13,009' 6211' - 6211' 13,168' - 13,173' 6207' - 6207' 13,535' - 13,540' 6217' -6217' 13,734' - 13,739' 6230' - 6230' 13,934' - 13,939' 6233' -6233' 14,138' - 14,143' 6235' -6235' 14,300' - 14,304' 6239' - 6239' 14,463' - 14,468' 6242' - 6242' 14,840' - 14,844' 6238' -6238' 15,043' - 15,048' 6244' -6244' 15,247' - 15,252' 6242' -6242' 15,448' - 15,453' 6249' -6249' 15,648' - 15,653' 6251' -6251' 15,867' - 15,872' 6239' -6239' 16,029' - 16,034' 6232' -6231' 16,234' - 16,239' 6230' -6230' Pioneer Natural Resources Alaska Inc. ODSN-18 Page 3 AOGCC Form 10-403, Application For Sundry Approvals Present Well Condition Summary, Box #11 Packers and SSSV Type (MD/TVD) - Attachment sssv TRMAXXX-5E SSSV 2068' MD /2043' TVD Packers Hydro II Packer w/ Gas Vent Valve 2570' MD /2522' ND 7" x 9-5/8" Liner Top Packer 8309' MD / 5150' ND Arrow Pak Retrievable Packer 11,872' MD /6137' ND 4-1/2" x 7" Liner Top Packer 11,931' MD /6147' ND • ODSN-18 Nuiqsut Production Well Completion- Current ,,_) gill Casing All 16"109 ppf H-40 Conductor Item# Item MD(ft) TVD(ft) © A 16"Conductor 158 158 IiIIIIII O J iiiiiiii Packer Fluid mix: B 11-3/4"60#L-80 Hydril 521, 10.772"ID 3,600 3309 is Inhibited Kill weight C 9-5/8"40#L-80 Hydril 521,8.835"ID* 8,824 5607 a " Brine D 7"26#L-80 BTC-M,6.276"ID,Tieback 8,309 5150 1111111I with 2000'TVD ' diesel cap E T'26#L-80 Hydril 511,6.276"ID** 12,090 6175 ```�$ F 4-1/7 12.6#Hydril 521 3.958"ID 16,400 6232 ilit G 2-7/8"6.5#L-80 IBT-M 10,986 5948 l? 11-3/4"60 ppf L-80 Hydril 521 Os Surface Casing @ 3600' MD/3309'TVD 1 VetcoGray Tubing Hanger 34 34 cemented to surface 2 2-7/8"Wellstar Tubing Retreivable ScSSSV 2,068 2,043 3 GLM#1-2-7/8"x 1-1/2"(min.3 jts above top X nipple) 2,454 2,415 7"26 ppf L-80 2-7/8"X Nipple 2.313"I.D. (min.2 jts above Gas Vent Intermediate 2 Casing 4 Valve Packer) 2,518 2,475 ili!lO Dii J ,y�� Tie-Back Sleeve 5 WFT T'x 2-7/8"Gas Vent Valve Packer(max.TVD 2500) 2,550 2,504 1 811 @ 8308' MD/5150'TVD 6 GLM#2-2-7/8"x 1-1/2"(min.2 jts above X nipple) 8,400 5,182 .7 i 1111. 0111117"26 ppf L-80 BTC-M to 2-7/8"X Nipple,2.313"ID(max.incl. 70 deg)w/RHC-M surface 7 Plug Body 8,464 5,204 08 Automatic Divert Valve(ADV) 10,904 5,926 9-5/8"40 ppf L-80 Hydril 521 9 ESP(Pump, Motor,and Jewelry) 10,914 5,929 Ob00 Intermediate 1 Casing @ 8824' MD/5307'TVD End of Assembly 10,986 5,948 - (Top @ 3320' MD/3123'TVD) Q 10 WFT x 3-1/2'Retrievable Packer 11,850 6,133 11 WFT 3-1/2"Pressure Activated Sleeve 11,875 6,137 12 WET 3-1/2"Formation Saver Valve 11,900 6,142 / 2-7/8"6.5 ppf L-80 IBT-M Tubing 13 1 jt 3.5"TC-II and WLEG 11,910 6,143 0►�� S End of Assembly 11,945 6,150 Lower Completion 00 ° Item# Item PAPA• TVD Or or® 13 WET PBR lie Back Sleeve 15ft 11,915 6,144 TOC Estimated 14 WET"NTH"Liner Top Pkr 11,930 6,147 500'above top of 15 WFT"PHR"Rotating Hyd Set Liner Hanger 11,934 6,148 Kuparuk 16 Resman Tracer Pup(heel location) 12,975 6,211 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes), 18 spaced every 200'. See separate attachment ® i;: 19 Resman Tracer Pup(midlateral location) 14,708 6,237 "' ,6 20 Resman Tracer Pup(toe location) 15,814 6,243 21 Liner Shoe(PLUGGED)w/4-1/7'Hydril 521 16,398 6,233 's End of Assembly 16,400 6,233 7"26 ppf L-80''< �,: Hydril 511 � 19 zo Intermediate 2 , 4 '8 Q Casing �'� °° °° °° °° °° °° °° °° .. °° °° 00 °° °° / @ 12090'MD/ 4-1/2" 12.6 0 00 ° ° ° 00000 z, 6175'TVD ppf L-80 Hydril 521 4'/:" 12.6#/ft L-80 Hydril 521 6-1/8" Hole TD at Liner Liner w/Pre-Perforated pups at 16689' MD/ (6 holes-0.50"Diamenter) 6229'TVD spaced @ 200 ft apart 4 c o a X X w w a w w a a w w 9al w w o oor X oc oor oor X IX N z I wa wa �a ca 0 0� oa oa �� �0 oa oa p (> �! 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C ` J O 0 w H aa)) a) E \ t ` \ l \ 1 \ \ 1, ` , \ ♦ `\ o a U a ;,'> E `O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0) a) I 0 >m .0 c aa)) o a 2 J J J J J J J J J J J J J J J J J J3 _ Q > 0 <L 0 1 0 9 o N rtN COz N .� r) 0_ r 0 in o i z a a e J a rco P �wr U reN O 7 li to toCe re C O g U Om M UJ z oe c W U.1 z z V o Z a o m N y 7 CL N ° c O � E 0 1 CO i Z I— o e-- a5 Z C N c Z r W Y p cc a) CO O QCo Qa o E Q z E U Z =y rn N 1 N I co N m a 0 3 N d N a' D co0 (<D C .2 r f0 a cp 0 1 0 a d 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reggc/16 13 DATE: 8/13/2013 p P. I. Supervisor k2Ti I FROM: Jeff Jones SUBJECT: No Flow Test Petroleum Inspector Oooguruk ODSN-18 Pioneer Natural Resources PTD 2101420 6/29/2013: I traveled to Oooguruk Island — operated by Pioneer Natural Resources (Pioneer) —to witness a No Flow Test on Well ODSN-18. Warren Gangwar and Greg Garvin were the Pioneer representatives for the test today. We met to discuss the test procedure. The well production was bled down prior to my arrival and lined up through an Armor-Flo Model 3461-03T0 flow meter, Serial #131509, to and open top container. Flow from the well was monitored for 3 hours and did not exceed 350 scf gas per hour, and producing less than 1 cup of fluid total. Oooguruk ODN-18 passed the AOGCC V criteria for No-Flow status. Summary: I witnessed a successful No Flow Test on Pioneer's Oooguruk ODSN-18. Attachments: none 2013-0629_No-Flow_Oooguruk_ODSN-18_j j.docx `1 \ I7 ,i.e.4. THE STATE Alaska Oil and Gas ��- _ °'ALAS Conservation Commission *h, I il GOVERNOR SEAN PARNELL 333 West Seventh Avenue SFA�P Anchorage, Alaska 99501-3572 AL I Main: 907.279.1433 Fax: 907.276.7542 Rami Jasser Sr. Staff Drilling Engineer Pioneer Natural resources Alaska, Inc. 700 G Street, Suite 600 ca '0 P-I-D--.Anchorage, AK 99501 �'C Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-18 Sundry Number: 313-392 Dear Mr. Jasser: 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. Since -1, Err o an o • loner DATED this qday of July, 2013. Encl. RECEIVED STATE OF ALASKA JUL 18 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Alid 2813 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repairrf Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull'fig ng❑✓ . Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other:Run Clean-out String El- 2. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Pioneer Natural Resources Alaska,Inc. Exploratory ❑ Development 0' 210-142 3.Address: 700 G Street,Suite 600 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99501 50-703-20624-00-00 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ODSN-1 8 • Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): . 10.Field/Pool(s): ADL 355036 /ADL 355037 Oooguruk- Nuiqsut Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 16,689' ' 6229' ' 16,399'• 6232' N/A N/A Casing Length Size MD ND Burst Collapse Conductor 110' 16" 158' 158' N/A N/A Surface 3557' 11-3/4" 3600' 3309' 5830 psi 3180 psi Drilling Liner 5504' 9-5/8" 3320'-8824' 3124'-5329' 5750 psi _ 3090 psi Tie-Back 8270' 7" 8308' 5149' 7240 psi 5410 psi Intermediate 2 3801' 7" 8289'-12,090' 5143'-6175' 7240 psi _ 5410 psi Liner 4485' 4-1/2" 11,915'-16,400' 6144'-6232' 8430 psi 7500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment,pg.2, See Attachment,pg.2 2-7/8",6.5# L-80, IBT-M 10,986' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): See Attachment,pg.3 See Attachment,pg.3 - 12.Attachments: Description Summary of Proposal Q • 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 7/31/2013 Oil Q• 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 Rami Jasser,343-2182 Email rami.jassera..Dxd.com Printed Name Rami Jasser Title Sr.Staff Drilling Engineer Prepared By:Kathy Campoamor, 343-2183 Signature A Phone Date 343-2182 7/17/2013 7 //,� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 5-)3tea Plug Integrity ❑ BOP Test RI/ Mechanicalt:. Integrity Test ❑ Location Clearance Other: 3Sao Ps:. EcD(' 7e RBDMS JUL 2 6 2011 Spacing Exception Required? Yes ❑ No P/ S :. -nt Form Required: 'Q C 1-1 0r /7 APPROVED BY o Approved by: CO,• SSIONER THE COMMISSION Date: �� 3 Subm Form and Form 10-403(Revised 10/2012) Approv• 6RtatittAtths from the date of approval. Attachments in Duplicate �� 7.VA•t3 /(\,�\�� RECEIVED PIONEER JUL. 1 8 2013 NATURAL RESOURCES ALASKA AOGCC Pioneer Natural Resources Alaska, Inc. 700 G Street,Suite 600 Anchorage,Alaska 99501 Tel:(907)277-2700 Fax:(907)343-2190 July 17th, 2013 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite#100 Anchorage, AK 99501 RE: ODSN-18 Sundry Application to Replace Tubing REF: Permit To Drill # 210-142 Pioneer Natural Resources Alaska (PNRA) hereby submits an Application For Sundry to pull the existing ESP Completion String and replace with a new 2-7/8" Clean-out Sting with Packer to facilitate cleaning the production liner on ODSN-18. The workover will be conducted with the CUDD Energy Services Hydraulic Unit. See the proposed plan attachment and supporting documentation. Sincerely, R-miJasser Sr. Staff Drilling Engineer Attachments: Form 10-403 Supporting information cc: ODSN-18 Well File Pioneer Natural resources Alaska Inc. ODSN-18 Page 2 AOGCC Form 10-403, Application For Sundry Approvals Present Well Condition - Box #11 Perforation Depth (MD/TVD) - Attachment 4-W, 12.6#, L-80 Hyd 521 Uncemented Liner Perforated Pups w/ 6-1/2" Holes @ depths listed: MD TVD 12,302' - 12,306' 6201' - 6202' 12,506' - 12,511' 6222' - 6222' 12,628' - 12,632' 6225' - 6225' 13,005' - 13,009' 6211' - 6211' 13,168' - 13,173' 6207' - 6207' 13,535' - 13,540' 6217' - 6217' 13,734' - 13,739' 6230' - 6230' 13,934' - 13,939' 6233' - 6233' 14,138' - 14,143' 6235' - 6235' 14,300' - 14,304' 6239' -6239' 14,463' - 14,468' 6242' - 6242' 14,840' - 14,844' 6238' - 6238' 15,043' - 15,048' 6244' - 6244' 15,247' - 15,252' 6242' - 6242' 15,448' - 15,453' 6249' - 6249' 15,648' - 15,653' 6251' - 6251' 15,867' - 15,872' 6239' - 6239' 16,029' - 16,034' 6232' - 6231' 16,234' - 16,239' 6230' - 6230' Pioneer Nacural Resources Alaska Inc. ODSN-18 Page 3 AOGCC Form 10-403, Application For Sundry Approvals Present Well Condition Summary, Box #11 Packers and SSSV Type (MD/TVD) - Attachment sssV TRMAXXX-5E SSSV 2068' MD /2043' TVD Packers Hydro II Packer w/ Gas Vent Valve 2570' MD / 2522' TVD 7" x 9-5/8" Liner Top Packer 8309' MD / 5150' TVD Arrow Pak Retrievable Packer 11,872' MD / 6137' TVD 4-1/2" x 7" Liner Top Packer 11,931' MD / 6147' TVD PIONEER NATURAL RESOURCES ODSN-18 Version 1.0 Snubbing Unit Work-over Program — Nuiqsut Lateral Permit # 210-142 AFE# 023726 — $6.276 MM — 10 days Sundry #TBD DRAFT July 17, 2013 Prepared: Date: Rami Jasser: Sr. Staff Completion Engineer Reviewed: Date: Tim Crumrine: Sr.Staff Completion Engineer Reviewed: Date: Jack Kralick: Well Work Supervisor Reviewed: Date: Andy Bond: Reservoir Manager Approved: Date: Vern Johnson: Drilling Manager 1 PIONEER NATURAL RESOURCES Table of Content Table of Content 2 1. Work-over Overview and Objectives 3 1.1. Overview: 3 1.2. Completion Objectives: 3 1.3. Current Well Conditions: 3 1.4. Summary Procedure for Completion Operations: 4 2. Well Information 5 2.1. Casing/Tubing Data: 5 2.2. Tubular and Annular Capacity Data: 6 2.3. Tubular Data• 6 2.4. Workstring Data: 6 2.5. Barriers during Completion Operations: 6 3. ODSN-18 Completion Schematic - Current 7 4. ODSN-18 Completion Schematic—Proposed 8 5. Pre- Snubbing Unit Work: 9 5.1. SLICKLINE PROCEDURE 9 6. Well De-Completion• 10 7. Middle Completion Run 13 8. Upper Completion Running Procedure 14 9. Vendor Contact Information: 17 2 PIONEER NATURAL RESOURCES 1. Work-over Overview and Objectives 1.1. Overview: The purpose of this program is to pull the existing ESP completion string out of ODSN-18 and replace it with a cleanout 2-7/8" string. The tie-back sleeve at 8308' MD has a leak and will not pressure test. The entire work-over will be conducted using a Cudd Energy Services Hydraulic Workover Unit. ODSN-18 has not produced despite favorable logging data and oil shows while drilling. If post workover testing proves the well has continued poor production, future plans include: • Pulling the temporary completion, remediate the tie-back leak, side track the well and perform a mechanical diversion frac. If post workover testing proves improved production, future plans include: • Pulling the temporary completion, remediate the tie-back leak and recomplete with a ESP. History Notes: • The 7" liner's mechanical integrity is compromised. An IA PT was conducted to determine the leak rate in the annulus prior to the frac job on 2/5/11. The IA was pressured up to 2000 psi and bled down to 1900 psi after 20 minutes. This resulted in an increase in pressure on the OA of 75 psi. The leak rate is not suspected to have increased but any pressure testing of the IA should be conducted while monitoring the OA. • The control line is plugged to the ScSSV somewhere in the tree or close to the surface. Attempts made to free control line were unsuccessful. Fluids: k w(' • 8.5 ppge brine with scale inhibitor will be the completion fluid and kill fluid.Note the expected BHP of the Nulgsut is 2500 psi. • Fluid should be mixed and filtered to less than 20 NTUs. • In a well control situation, discontinue filtering if needed. 1.2. Completion Objectives: • No HS&E incidents. • Complete well within time and budget. • Recomplete well by removing ESP completion/Formation Saver and placing a 2-7/8" completion string • Clean out lateral. • Flow test well. 1.3. Current Well Conditions: • BHP is estimated @ 2,500 psi (7.7 ppge @—6,229' TVD) • Well was shut in on 6/10/2013 • RKB 34.16' 3 PIONEER NATURAL RESOURCES 1.4. Summary Procedure for Completion Operations: 1. Prepare well for pulling tubing out of the hole. 2. Displace to kill weight brine—8.5 ppge filtered SW. ' 3. Pull existing 2-7/8"ESP upper completion string out of the hole. • 4. Pull formation saver assembly out of the hole. • 5. Pick up 2 3/8"work string and clean out to tie-back • 6. Pick up and run sump packer assembly. Set Sump Packer 50 ft above existing lower completion tie- ' back. 7. Spot corrosion inhibited brine. ' 8. Pick up and run new 2-7/8"upper completion string and snap into sump packer. . 9. Land tubing hanger and run in lock down screws. 10. Set the Retrievable Packer. ' 11. Pressure test tubing and annulus. ° 12. Shear DCK-2 and Install the 2 way check into the tubing hanger. 13. Test tubing hanger+2 way check from below. • 14. Nipple down BOP stack, and install tree.• 15. Pull two way check. 16. Freeze protect well. • 17. Install back pressure valve with lubricator. 18. Rig down, move out. - 4 PIONEER NATURAL RESOURCES 2. Well Information Unless noted otherwise, all depths,well deviations, reservoir pressures, pipe depths, and other reservoir and/or drilling-specific parameters referenced in this procedure are as per prognosis, and do not represent final or actual data. The Pioneer on-site supervisor should ensure that updated information is obtained for these parameters and updated as necessary especially in the final handover form. 2.1. Casing/Tubing Data: Top Bottom Hole Csg/ Depth Tb Wt I.D. Drift Burst Collapse Hole Section (ft) D(e) h (oize Size (Ib/ft) Grade Connection (inch) (inch) (psi) (psi) (inch) Surface 34'MD 3,600'MD 14-1/2 11-3/4 60 L-80 Hydril 521 10.772 10.616 5830 3180 3,309'TVD Intermediate 1 D 8,824'MD 5,307'TVD 11-3/4 9-5/8 40 L-80 Hydril 521 8.835 8.679 5750 3090 Intermediate 2 34'MD 8,308'MD 8-1/2 7 26 L-80 BTC-Mod 6.276 6.151 7240 5410 Tie-Back 5,150'TVD Intermediate 2 8,308'MD 12,090'MD 5,150'ND 6,175'TVD 8-1/2 7 26 L-80 Hydril 511 6.276 6.151 7240 5410 Lateral 12,090'MD 16,689'MD 6-1/8 N/A 6,175'ND 6,229'ND Lower 11,916'MD 16,400'MD 6-1/8 4-1/2 12.6 L-80 IBT-M w/ 3.958 3.833 8430 7500 Completion 6,145'TVD 6,233'ND torque rings Upper Completion 34 MD 143 MD - 3-1/2 9.2 L-80 VAM TC-II 2.992 2.867 10160 10540 (Tubing) Upper Completion 11,300 MD 143 MD - 2-7/8 6.5 L-80 IBT-M 2.441 2.347 10570 11170 (Tubing) 6,176 ND 5 • PIONEER NATURAL RESOURCES 2.2. Tubular and Annular Capacity Data: Tubing size Weight I.D. Capacity Capacity Annulus Annular Annular (inch) (Ib/ft) (inch) (bbls/ft) (cu ft/ft) Volume Volume (bbls/ft) (cu ft/ft) 3-1/2 9.2 2.992 0.00870 0.04883 3-1/2"x 7"26# 0.0264 0.1480 2-7/8 6.5 2.441 0.00580 0.03250 2-7/8"x 7"26# 0.0302 0.1697 2.3. Tubular Data: Liner and Tubing Specifications and Required Make-Up Torque: Tensile Tensile Min Target Max OD ID Drift Wt/ Thread Grade Body Conn. Torque Torque Torque (inches) (inches) (inches) ft Connection (1000 (1000 Ibs) Ibs) (ft-Ib) (ft-Ib) (ft-Ib) 3-1/2" 2.992 2.867 9.2 VAM TC-II L-80 207 207 2,100 - 2,500 2-7/8" 2.441 2.347 6.5 IBT-M L-80 145 145 To Mark 2.4. Workstring Data: Min Opt Max Displace Capacit ID Drift Wt Thread Tensile OD(in) Grade Torque Torque Torque ment y (in) (in) /ft Connection (ft-Ib) (ft-Ib) (ft-Ib) (Ibs) (gal/ft) (gal/ft) 2-3/8"pipe With 2.906" 1.805 1.773 5.95 PH-6 P-110 2,700 3,035 3,370 186,000 0.08792 0.14222 upset 2.5. Barriers during Completion Operations: Procedure Status Well Barriers and Elements 7" casing run and 1. Kill weight fluid, well static for 30 minutes. cemented, open hole 2. BOP, wellhead and casing valves, 7" casing hanger Pull out existing upper completion string horizontal, open topack-off, 7" casing (cemented and pressure tested). formation below 7" f shoe. 7" casing run and 1. Kill weight fluid, well static for 30 minutes. cemented, liner run 2. BOP, wellhead and casing valves, 7" casing hanger Pick-up and run the upper completion and liner top packer pack-off, 7" casing (cemented and pressure tested). , assembly set, open to formation through liner tail. Tubing hanger 1. Kill weight fluid, well static for 30 minutes. installed and 2. Two way check valve tested in direction of flow, pressure tested, tubing hanger seal tested in direction of flow, ball and Nipple down BOP tubing stabbed into rod on XN nipple with Kill weight brine on top, stack and install tree SBE, liner top packer wellhead and casing valves, 7" casing hanger pack- set and pressure off, 7" casing (cemented and pressure tested). tested, ball and rod on XN nipple with RHC Plug. 6 PIONEER NATURAL RESOURCES 3. ODSN-18 Completion Schematic - Current J Casing A _ © 16"109 ppf H-40 Conductor Item# Item MD(ft) TVD(ft) A 16"Conductor 158 158 0 J Packer Fluid mix B 11-3/4"60#L-80 Hydril 521,10.772"ID 3,600 3309 ' Inhibited Kill weight C 9-5/8"40#L-80 Hydril 521,8.835"ID* 8,824 5607 Brine D 7"26#L-80 BTC-M,6.276"ID,Tieback 8,309_ 5150 with 2000'TVD E 7"26#L-80 Hydril 511,6.276"ID** 12,090 6175 $ ( diesel cap F 4 1/2 12.6#Hydril 521 3.958"ID 16,400 6232 s ■ G 2-7/8"6.5#L-80 IBT-M 10,986, 5948 11-3/4"60 ppf L-80 Hydril 521 Upper Completion 2 OSurface Casing iiiimilimimmift MDrkb(ft) TVDrkb(ft) a @ 3600' MD/3309'TVD 1 VetcoGray Tubing Hanger 34 34 cemented to surface 2 2-7/8"WellstarTubing Retreiveble ScSSSV 2,068 2,043 3 GLM#1-2-7/8"x 1-1/2"(min.3 jts above top X nipple) 2,454 2,415 7"26 ppf L-80 2-7/8"X Nipple 2.313"I.D.(min.2 jts above Gas Vent - Intermediate 2 Casing 4 Valve Packer) 2,518 2,475 J ,O Tie-Back Sleeve 5 WFT T'x 2-7/8"Gas Vent Valve Packer(max.TVD 2500) 2,550 2,504 5150' 'di 8308'MD/ TVD 6 GLM#2-2-7/8"x 1-1/7'(min.2 jts above X nipple) - 8,400 5,182 7"26 ppf L-80 BTC-M to 2-7/8 X Nipple,2.313"ID(max.incl.70 deg)w/RHC-M t ► surface 7 Plug Body 8,464 5,204 8 Automatic Divert Valve(ADV) 10,904 5,926 9-5/8"40 ppf L-80 Hydril 521 9 ESP(Pump,Motor,and Jewelry) 10,914 5,929 . Se 0000 Intermediate 1 Casing End of Assembly 10,986 5,948 p @ 8824'MD/5307'TVD _ (Top @ 3320'MD/3123'TVD) 0t K a 10 WFT 7"x 3-1/2"Retrievable Packer 11,850 6,133 11 WFT 3-1/2"Pressure Activated Sleeve 11,875 6,137 12 WFT 3-1/2"Formation Saver Valve 11,900 6,142 g so \ / 2-7/8"6.5 ppf L-80 IBT-M Tubing 13 1 jt 3.5"TC-II and WLEG 11,910 6,143 (, 02 8 End of Assembly 11,945 6,150 _ Lower Completion 7,-10 00 0 tJ.' Item# Item MD(ft) _ TVD(ft) ® Fa^. 1/11/, 13 WFT PBR lie Back Sleeve 15ft 11,915 6,144 TOC Estimated 14 WET"NTH"Liner Top Pkr 11,930_ 6,147 D 500'above top of 15 WFT"PHR"Rotating Hyd Set Liner Hanger 11,934 6,148 r y Kuparuk 16 Resman Tracer Pup(heel location) 12,975 6,211 00t1 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/61/2 holes), See separate attachment 18 spaced every 200'. ® q 19 Resman Tracer Pup(midlateral location) 14,708 6,237 I,ik s 20 Resman Tracer Pup(toe location) 15,814 6,243 21 Liner Shoe(PLUGGED)w/4 1/2"'Hydril 521 16,398 6,233 s r `O End of Assembly 16,400 6,233 7"26 ppf L-80 Hydril 511 `,wwi:i . . ____ e 19 ® Intermediate 2 �, ;�'� o ° ° ° o ° ° ° �0 Casing �. F @ 12090'MD/ 4-1/2"12.6% ° z 6175'TVD ppf L-80 .- Hydril 521 4-Y%"12.6#/ft L-80 Hydril 521 6-1/8" Hole TD at Liner Liner w/Pre-Perforated pups at 16689'MD/ (6 holes-0.50"Diamenter) 6229'TVD spaced @ 200 ft apart 7 PIONEER NATURAL RESOURCES 4. ODSN-18 Completion Schematic - Proposed 1 Upper Completion MD TVD 1 1)Tubing Hanger 34' 34' A 1 , 16"109 ppf H-40 Conductor 2)3-W 9.V/ft TC-II Tubing(2jts) II: 3)3-W 9.3#/ft TC-II x 2-7/8"6.5#IBT-M Crossover Sub 4)2-7/8" 6.5#/ft IBT-M Tubing Packer Fluid mix 5)2-7/8"Halliburton Wellstar TRSV w/2.313""X"profile with 2,000 1,977 I Inhibited Kill weight single1/4"x0.049'SS Control Line to surface Cannon Brine Cross-coupling clamps on every joint 1 6)2-7/8" 6.5#/ft IBT-M Tubing I with 2000'TVD 7)2-7/8"x 1.5"GLM 6.5#IBT-M BxP w/DCK2 3,500 3,245 diesel cap 8)2-7/8" 6.5#/ft IBT-M Tubing I MI 9)2.313""X"Nipple 9 Cr w/2-7/8"6.5#/ft IBT-M BxP 3,590 3,303 © I 10)2-7/8" 6.5#/ft IBT-M Tubing IL. 11-3/4"60 ppf L 80 Hydril 521 11)2-7/8"x1.5'GLM 6.5#IBT-M BxP w/DV 8,885 5,309 y 12)2-7/8" 6.5#/ft IBT-M Tubing Surface Casing 13)2.313""XN"Nipple 9 Cr(2.205'No-Go) 10,400 5,788 OI @ 3600' MD/3309'TVD w/2-7/8"6.5#/ft IBT-M BxP GL cemented to surface 14)2-7/8" 6.5#/ft IBT-M Tubing 15)2-7/8"Halliburton'ROC'Gauge Carrier with singlel-wire 11,8017 6,124 to surface ,7-4-304/7"26 ppf L-80 16)2-7/8" 6.5#/ft IBT-M Tubing Intermediate 2 Casing 17)Snap Latch with GBI-22 Bonded Seal Assembly 11,903' 6,142 3.25"Seal OD&2.406"ID w/WLEG Tie-Back Sleeve End of Assembly. 11,906' 6,143' @ 8308'MD/5150'TVD I• 7"26 ppf L-80 BTC-M to Middle Completions 118)T'Model D Sump Packer(w/2ft3.25"Seal Bore) 11,900' 5,920 41 i , surface 19)3-%"9.2#TC-II Tubing 20)5.85"OD Locator Sub 11,916' 6,145 GL J1 9-5/8"40 ppf L-80 Hydril 521 21)3-1/2"9.2#TC-116ft pup with WLEG Intermediate 1 Casing End of Assembly. 11,923' 6,146' 13 0 I8824MD/5307TVD @ ' ' Lower Completion Mil n(Q (Top @ 3320'MD/3123'TVD) 22)Weatherford15'Tie-Back Sleeve(5.80"OD) 11,915 6,145 23)Weatherford"NTH"Liner Top Packer 11,931' 6,147 _.� I 24)Weatherford"PHR"Rotating Hydraulic Set Liner Hanger 11,934' 6,148 0 :1-1 25)4'h"12.6#/ft L-80 Hydril 521 Liner vi Pre-Perforated pups (6 holes-0.50"Diamenter)spaced@ 200 ft apart 26)Reman Tracer Pup@ Heel 12,795 6219 2-7/8"6.5 ppf L-80 IBT-M Tubing 27)4-W 12.8#/ft L-80 Hydril 521 Liner W Pre-Perforated pups (6holes-0.50"Diamenter)spaced@ 200ft apart 28)Reman Tracer Pup@ Middle of Lateral 14,709 6,237 29)4'/:"12.6#/ft L-80 Hydril 521 Liner v./Pre-Perforated pups (6 holes-0.50"Diamenter)spaced @ 200ft apart 30)Reman Tracer Pup@ Toe 15,815' 6,243 31)4-14"12.6#/ft L-80 Hydril 521 Liner%A/Pre-Perforated pups (6 holes-0.50"Diamenter)spaced @ 200 ft apart TOC Estimated 32)4%"Hydril 521 Plugged Liner Shoe 16,399 6,253 500'above top of End of Assembly. 16,400' 6,233' Kuparuk it me "A- CVc11)511/4 © 2423 \� 7"26 ppf L-80 Hydril 511 •, \ 29 ®� Q Q Intermediate 2 ;•. 1 Casing \ /®�� IN ° ° ° ° o I ° ° ° �I @ 12090'MD/ 4-1/2"12.6 "-. ° s2 6175' TVD ppf L-80 Hydril 521 4-1/2"12.6#/ft L-80 Hydril 521 6-1/8" Hole TD at Liner Liner w/Pre-Perforated pups at 16689'MD/ (6 holes-0.50"Diamenter) 6229'TVD spaced @ 200 ft apart 8 PIONEER NATURAL RESOURCES 5. Pre- Snubbing Unit Work: 5.1. SLICKLINE PROCEDURE . 1. Record tubing,IA,and OA pressures. Record BHP and Temp.Note on Daily Well Work Report. 2. MIRU slickline. Conduct a pre job safety meeting with the rig crew,well work supervisor, and all associated service companies. 3. Spot slickline unit,hang load cell, and necessary sheaves. 4. Add a second swab valve for slick-line work. 5. Open PVV and vent gas from below packer into IA. Bleed IA and tubing as necessary. 6. Assure control line pressure and diagnose ScSSV—assure flapper is open. 7. Verify ScSSV actuation,close and verify,monitor control line pressure. PT ScSSV from below to 500 psi. Leave ScSSV open when finished. It may be necessary to set a plug in the X nipple at 2518' MD to test the ScSSV. . 8. If not open-- lock out ScSSV per Halliburton procedure. 9. Pull gas lift/dummy valves from GLM at 8400' MD and from GLM at 2454' MD.No catcher necessary. NOTE: The open GL mandrel at 8400' MD will be used to vent gas from the annulus below the packer. 10. Fluid pack IA,tubing with 8.5 ppg Brine: o Circulate annulus volume+tubing volume down to GLM at 2454' MD at 2-3 bpm. Reverse circulate if needed. Record the pump pressure and WHP while pumping. Bullhead down the tubing as needed. 11. Freeze protect TxIA to 2000' with diesel(well may be underbalanced after freeze protecting). NOTE: If the CUDD Unit is going to move onto this well within 2 days(or as seen prudent by the Well work Supervisor and Company Man)then this step can be skipped. If this step is skipped,the fluid must be frequently circulated using the P6 pumps to prevent freeze- up: o Reverse circulate diesel. o If well is on losses,bullhead the tubing with diesel 12. Bleed ScSSV control line pressure. Conduct differential test across ScSSV. NOTE: If ScSSV control line pressure does not bleed off or flapper does not function run a WRP to 1,500ft MD(above ScSSV).Test WRP by applying 2,500 psi on tubing. 13. Set BPV. 14. Secure well for Cudd Hydraulic workover. 15. Monitor WHP and IAP via operator's daily reading schedule until Cudd moves on location,Prep surface equipment for rig move. *COMPLETE PRE-RIG WORKOVER CHECKLIST AND SUBMIT TO WELL WORK SUPERVISOR* 9 PIONEER NATURAL RESOURCES 6. Well De-Completion: 1. Monitor Tubing x IA x OA pressures. 2. If necessary, circulate out diesel freezeprotect and fluidpack Tubingx IA bycirculatingwith 8.5kill ppg weight brine as needed. 3. Ensure BPV and test dart installed. �p 4. ND the swab valve and NU the BOPE. Test BOP's as per standard AOGCC requirements. With low(250 psi)and high(322_p§1) 5 minutes each. State will need to be notified to witness test. a. NOTE: Because this is a rig workover BOP testing is on a one week cycle. b. Have FOSV available and drifted to accommodate the WRP (if run) and to ensure e-line cuttings tools can pass through ID. c. Ensure as a contingency that e-line on location with string shot and jet cutter in case packer does not release. See contingency tubing cut operational details below d. Ensure as a contingency that Baker Hughes fishing is on location with an assortment of spears, burn over shoes,junk baskets, casing scrapers etc. e. Pull the BPV and test dart from the tubing hanger.If trapped pressure is observed below the BPV, bullhead KWF down the tubing as needed. 5. Install 2-7/8" landing joint in the tubing hanger w/FOSV made up. Heat up wellhead to make unseating tubing hanger easier. 6. If WRP run/Rig up Slickline and pull WRP. 7. Monitor the well for 30 minutes. 8. BOLDS. Check PU distance so BOP's will function on landing joint. a. Unseat hanger. When landing the tubing the PU was 155k and S/O wa_s_65.k. This includes 40000 block weight. b. After hanger is unseated,attempt to pull packer free. This completion is 2-7/8"tubing. i. 2-7/8", 6.5 ppf, L-80 joint yield is 145,000 lbs c. Be aware that pulling packer may require pulling 90% the 2 7/8" tensile strength, however, the first joint of 2-7/8"is a pup joint above the ScSSSV. i. Notify Cudd Project Manager before exceeding 80% of tensile strength(80%-116,000 lbs *not including block weight) ii. If 90% must be exceeded be ready to cut and pull tubing. Reference basic fishing operations information at the end of this procedure. d. Packer will shear release with 33,000 lbs of straight pull at the tool. 1ei. Landed PU of 155,000 lbs+33,000 lbs= 188,000 lbs of PU required 41— e. . Keep tubing hanger below annular preventer and if possible below pipe rams. f. Turn off hole fill,and monitor for losses/gains. g. Gas may be present below the packer, Close the annular(open choke)around the landing joint in anticipation of a gas bubble once the packer is released. Gas will be bled through the choke to the EXPRO system if necessary. h. Watch for an influx. If influx is seen begin pumping kill fluid. Otherwise, after packer is released monitor for losses or gains for 30 minutes before pulling uphole. 10 PIONEER NATURAL RESOURCES i. Keep hole full until elements have relaxed. j. Once the tubing hanger is at the window,mark an orientation mark on the floor. k. Pull tubing and packer up hole until packer elements relax. Elements should be relaxed in pulling of 3-4 stands. When packer elements relax you will be able to pump down the annulus. Attempt to pump in well every joint until elements have relaxed. Work pipe as necessary to relax elements. 9. Pull the 2-7/8" completion string out of the hole. While tripping pipe, pump 2 x pipe displacement+ 5 bbls/hr. If not tripping pipe pump 10 bbls per hour if fluid level is not at surface. a. RU HES Control Line spooling unit and hydraulic lines to Cudd's power pack and HES spooler on ground. b. RU Centrilift Spooling unit to pull ESP cable to the Cudd power pack c. Pull Tubing Hanger to the basket and disconnect control lines and ESP connections. d. Pull control line and ESP cable with tubing ensuring a lx1 ratio. e. If cable or control line are oil covered utilize the elephant trunk and absorb method to contain any residual oil. f. During pipe tripping, the annular can be closed around the control line and echometer used to determine fluid level. Continue filling hole until at least 3 echometer recordings confirm static fluid level. g. Count number of SS bands and clamps. 10. Lay down the 2-7/8"tubing,jewelry and pups. The landing joint with FOSV should be in the basket as a contingency. a. No completion jewelry will be re-run. The tubing and jewelry will be sent in for inspection. b. Leave ScSSV and gas vent valve open to help with swabbing whild pulling out of the hole. c. Have control line cutters and ESP cutters on the floor should an influx be seen. d. If influx is seen, PU contingency tubing joint, close annular and bleed control lines, flush annulus (1.5 x annulus volume to 7"intermediate shoe)@ 6 bpm. SD and monitor for 30 minutes. e. If junk is left in the hole, discuss with Completions Engineer before attempting fishing operation. f. Install wear ring. 11. RIH with the following retrievin — P•�f� ut`` !� '°''• • Arrowpak retrieving tool 2-7/8 EUE Box x Pin(pinned for 25,000 lbs. +/-) • X-O Sub 2-3/8 if Box x 2-7/8 EUE Pin 4U l! 3 3 OD Bumper Sub 2-3/8 IF Box x Pin 10S .• ' • 3 OD Oil Jar 2-3/8 IF Box x Pin 3I$ 3• Quantity 6—3 '/2 OD Drill Collars 2-3/8 IF Box x Pin(Recommended Drill Collars Weight 3,000 415 —5,000 lbs.) • X-O Sub 2-3/8 PH6 Box x 2-3/8 IF Pin 12. Record PU& SO weights prior to tagging packer 13. Circulate down into packer, set down min 2,000—3,000 lbs.to engage latch on retrieval tool. 14. Pickup and apply 4,000 lbs. shear above pickup weight(shear pins in packer & retrieval tool is pinned f/ 11 PIONEER NATURAL RESOURCES 25,000 lbs. shear 15. Once packer is free, packing elements are not going to relax and will have to drag free & wear OUT PACKING ELEMENT by continuing to pullout of the hole / rubbing the packing element against the casing wall. NOTE: If tailpipe is stuck attempt to jar free in 10,000 lbs. increments max allow pull will be 85% of 2-7/8 EUE thread on retrieval tool= 123,250 lbs.over pickup weight. NOTE: In the event unable to pull stuck assembly free, pull 5,000 lbs. over pick up weight& rotate 8 rounds to the right at tool to release the retrieval tool. POOH, cut pup joint below the packer& re- run retrieval tool&fish out packer. Baker Hughes fishing will retrieve the tailpipe. NOTE: If wire line cut as to be done, space out joints or pup joints to be below bottom safety ram and told joint at basket level. Make sure that whatever wire line tools are ran can drift through the tubing ID. 16. Once Upper and Middle completions are out of the hole, RIH with 2-3/8", 5.95 ppf, P-110, PH-6 workstring+casing cleanup BHA including magnets to make a clean-out run just above the liner tie-back (11900' of 2 3/8"). 12 • PIONEER NATURAL RESOURCES 7. Middle Completion Run • Hold a safety meeting with the rig crews and all contractors to ensure that the driller and workers understand the order of installation and how to communicate clearly if there are problems. • Verify that all completion components have been function and pressure tested as appropriate. Ensure dimensions of each component are recorded on the completion tally. • Ensure that tubing dope is applied to the pin only.Note that ALL couplings/connections below the packer are to be thread locked. • No right hand rotation while RIH to avoid premature release of the packer setting tool. • Run the completion as follows (from bottom to top): Equipment MD TVD OD ID (ft) (ft) (in) (in) Locator Mandrel with 6ft 3-1/2"9.3 ppf spacer pup&Ratcheting Mule 5.850 2.992 Shoe(No Seals) 3-'/2"9.3#/ft,TC-II Tubing—i Joint 3.500 2.992 Baker 80-32 Model `D' Production Packer run on a Model"B-2" 6.500 4.000 Hydraulic Setting Tool 2-3/8"5.95ppf PH-6 Workstring 5.000 2.564 1. Fill drill pipe every stand while running in the hole with kill weight brine. 2. Confirm middle completion entering tie back receptacle by watching the weight indicator. 3. Continue running the middle completion until the locator mandrel tags the lower completion tie back sleeve(11,916 ft MD—Packer Top)based on drill pipe tally. 4. Shut down and drop 1-7/16"Kirksite Baker ball. 5. Pump the ball down the tubing with 30 bbls of kill weight brine watching closely to avoid pressuring up above packer initiating pressure. Slow pump rate to 1 bpm and continue pumping kill weight brine. 6. Set packer by applying---2,000 psi on the tubing. Consult with Baker Oil Tools on pressures. 7. While holding 2,000 psi tubing pressure pull 30,000 lbs on surface to set the packer. Consult with Baker Oil Tools representative to determine the amount of pull on surface. 8. Bleed pressure to zero. 9. Pressure up to approximately 3,000 psi tubing pressure, pull 17,000 lbs on surface to shear the ball seat. Watch for pressure drop in the tubing to verify that the ball seat sheared. 10. Close the Annulus and apply 1,000 psi tubing pressure and hold for 15 minutes to confirm that the packer is set. Bleed off pressure from both tubing and annulus. 11. Put setting tool in neutral position and rotate 15 rounds to the right to release. 12. Once the packer setting tool releases, POOH and monitor volumes. 13 PIONEER NATURAL RESOURCES 8. Upper Completion Running Procedure 1. Hold a safety meeting with the rig crews and all contractors to ensure that the driller and workers in the pipe shed understand the order of installation and how to communicate clearly if there are problems. 2. Drift 3-1/2" (2.876" Drift) & 2-7/8" (2.347" Drift) tubing with a Teflon drift. Discuss the importance of drifting all tubing and the implications. Inspect all threads and remove any equipment with visible damage on the threads. 3. Verify that all completion components have been function and pressure tested as appropriate. Ensure dimensions of each component are recorded on the completion tally. 4. ROC gauge will be run in accordance to the Halliburton representative guidance. You must consult with Halliburton gauge representative prior to making any decisions / changes on upper completion running procedure. Halliburton representative will be present on the rig floor during the entire Upper completion run. NOTE: Please review Halliburton's gauge run—in—hole procedure for special consideration and precautions prior to running the ROC gauge.Main points are: • Once ROC gauge is on location,store in a warm area. • Do not impact the mandrel at any time.This will damage the electronic sensors in the mandrel. • Be aware when using the Pneumatic Rig Slips,and make sure that the Halliburton representative inspects the canon clamps passing through the slips and the control line prior to setting the pneumatic slips on every connection.Halliburton Representative will need a clear field of vision as the Pneumatic slips are close around the tubing string. • Prior to spacing out conduct a PJSM and discuss the space-out portion of the procedure with the Halliburton ROC gauge representative. • In the event that there is an issue or problem that requires the Tubing String to be moved an excessive number of times"up or down"or"rotated"contact the Pioneer Completions Engineer immediately. The key during space-out and when running in the hole is to limit the number of times the string is raised out and lowered in the hole. • When landing the tubing hanger avoid rotating the tubing string while running in the hole. Consult with the Halliburton representative and make sure we do not deviate from his/her recommendations. • DO NOT EXCEED 20 ft. per minute while running in the hole with the upper completion. Keep RIH speed consistent between drillers. • Secure ROC gauge I-Wire to tubing with one Cannon cross-coupling clamp per tubing joint.Maintain clamp count. 5. Run the completion as follows, ensuring that tubing dope is applied to the pin only. • When running the SSSV: o Visually inspect the SSSV to ensure the ID is clear of obstructions before running it. o Purge and test the hydraulic control line and connections to SSSV. o Run in with SSSV while Halliburton representative maintains pressure on the control line (Valve in open position). Secure control line to tubing with one Cannon cross-coupling clamp per tubing joint. o Ensure that the tubing running wear bushing is removed. 14 PIONEER NATURAL RESOURCES Upper Completion Pick-up Order(Bottom to Top): Description OD(in) ID(in) Length Depth Depth (ft) MD(ft) TVD(ft) Snap latch with GBH-22 Bonded Seal Assembly (3.25"Seal OD&2.406: ID)w/ WLEG 2.406 11,903 6,142 2-7/8"6.5#1 ft. IBT-Mod Tubing 2.875 2.441 TBD HES Roc Gauge Mandrel w/1-wire to Surface 4.800 2.965 4.73 11,800 6,124 2-7/8"6.5#/ft. IBT-Mod Tubing 2.875 2.441 TBD TIES 2.313""XN"Nipple w/2.205"No-Go 9Cr w/2-7/8 6.5#IBT-Mod Box x Pin 1.44 10,400 5,788 2-7/8"6.5#/ft. IBT-Mod Tubing 2.875 2.441 TBD H ES Vanoil 2-7/8"x 1.5"Gas Lift Mandrel w/2-7/8"6.5#IBT-Mod Box x Pin w/ ▪ummy in place 8.85 8,885 5,309 2-7/8"6.5#1 ft. IBT-Mod Tubing 2.875 2.441 TBD HES 2.313"X"Nipple 9Cr w/2-7/8 6.5#IBT-Mod Box x Pin 1.27 3,590 3,303 2-7/8"6.5#/ft. IBT-Mod Tubing 2.875 2.441 TBD Fillingbil 2-7/8"x 1.5"Gas Lift Mandrel w/2-7/8"6.5#IBT-Mod Box x Pin w/DCK- 2 irMee w/2,500 psi shear 8.85 2,000 1,977 2-7/8"6.5#/ft. IBT-Mod Tubing 2.875 2.441 TBD HES Wellstar TRSSSV w/2-7/8"6.5#IBT-M Box x Pin 9 Cr w/2.313"X"Profile w/ 1/4 x.049 SS Control Line to surface 5.200 2.813 6.88 2,005 1,928 2-7/8"6.5#/ft.IBT-Mod Tubing 2.875 2.441 TBD 3-1/2"9.3#TC-Il x 2-7/8"6.5#IBT-M Cross-Over Sub 3.500 2.441 3-1/2"9.3#TC-Il Tubing(2 Joints) 3.500 2.991 Vetco Gray Tbg Hanger w/3.725 MCA Box x 3-1/2 TC-11 Box 10.812 2.950 1.54 , 6. Run in the hole with upper completion string until the seal assembly is - 20 ft above the top of the Middle completion packer. 7. Record pick-up and slack-off weights. 8. Locate the top of the sump packer, fully insert seal assembly into packer sealbore, slack off 40,000 lbs and mark the pipe. 9. Pull back to neutral position and test the seals by applying-200 psi to annulus for 5 mins. 10. Pick up Upper completion string until seal assembly is 20 ft above the packer sealbore to space out with tubing pups.Keep an eye on the weight indicator needle to see snap latch releasing from the Sump Packer. 11. Slowly lower the sting into Packer sealbore looking for a slight weight decrease as seals enter the seal bore. 12. Land upper completion with 40,000 lbs. on the string. Test upper and lower tubing hanger seals. 13. Make up the tubing hanger to the last joint of tubing and orient the completion so the hanger matches up with the centering guide in the tubing bowl. Make up feed through for SSSV control line and downhole gauge I- wire. Maintain and monitor control line+ROC gauge I-Wire while landing tubing. 14. Pressure test annulus to 500 psi (do not exceed 1500 psi to avoid shearing DCK-2) to confirm seals are stabbed in. Bleed down annulus. Leave landing joint in place. RILDS. 15. Pressure test both upper and lower completion strings to 3500 psi for 30 minutes. Bleed down tubing to 2200 psi. Pressure test the 3-1/2" x 7" annulus to 3500 psi for 30 minutes. Leave landing joint in place. There was a leak detected on the 7"casing tieback previously on this well. 16. Bleed down tubing to shear the DCK-2 valve(DCK-2 is set to shear at 2500 psi casing to tubing differential). 15 PIONEER NATURAL RESOURCES Bleed tubing and annulus down to 0 psi. 17. Confirm DCK-2 is fully sheard by pumping 1 —2 bbls of kill weight brine from each direction. 18. Install 2-way check into tubing hanger. 19. Pressure up inner annulus to 2,500 psi to test two way check from below (direction of flow) and tubing hanger from below(direction of flow). 20. Flush stack to clean brine. 21. Nipple down BOPE 22. Nipple up tree&test to 5000 psi. 23. Rig up lubricator and pull two way check valve and set BPV. 24. Secure well. 25. Lay down drill pipe&prepare rig for rig move. 26. Freeze protect well Post Rig. 27. Ensure handover form is completed and turned over to: • Wellwork supervisor • Production/Operations supervisor. • Kathy Campoamor(Kathy.Campoamor@pxd.com) 16 PIONEER NATURAL RESOURCES 9. Vendor Contact Information: UPPER COMPLETION ITEM Description Vendor Contact Tubing Hanger Vetco Ben/Derrick x6618 Safety Valve Landing Nipple Halliburton Jeff/Bob 907-670-5952 GLM Halliburton Jeff/Bob 907-670-5954 XN Nipple Assembly Halliburton Jeff/Bob 907-670-5952 ROC Gauge Carrier Halliburton Jeff/Bob 907-670-5952 Ratcheting Mule Shoes/ Eccentric Shoe Weatherford 307-922-2548 Packers/Seals Baker Hughes 907-685-1073 17 21-11 RECOMMEND. PRACTICES 9511160 Pulling an ESP Completion Issue Date: February 2008 Revision Date: April 02,2013 SCOPE&BACKGROUND Electric Submersible Pumps (ESP) are a commonly utilized form of artificial lift. The standard practice is for a drilling rig to drill and case the well and then move off. A workover rig then moves on to perforate, stimulate, and complete the well. At Oooguruk, the drilling rig will handle all of these procedures. This recommended practice covers pulling an ESP completion. PREPARATION Confirm spooling unit is aligned to provide a straight pull on the cable,and to provide operator clear view. ESP power cable may be damaged if rig is not positioned properly. Spooler to be spotted far enough back from the rig to allow adequate slack in the cable i.e. (Being able to see the entire derrick). Confirm Baker Hughes technician has reviewed operation of unit with operator and has signed operator off as qualified on Baker Hughes check off sheet. Confirm sheave is 54" in diameter. Confirm safety cable is attached to sheave. Normal running height shall not exceed 40'above floor. Confirm power to the ESP is locked out and cable is disconnected. All locks shall be attached in accordance with lock-out tag-out procedures. A pre-job safety/planning meeting shall be held prior to pulling the pump and during crew changes to identify risks and mitigations. A Baker Hughes representative will be on the rig floor at all times during the ESP pull. Refer to previous install records and tally sheets for a list previously installed clamps. Keep an accurate count of all small parts pulled from the well. A Baker Hughes representative shall be on the rig floor to disconnect penetrator, make down-hole electrical checks,and to disassemble and inspect ESP. A Baker Hughes representative will check and record phase-to-phase and phase-to-ground conductivity for all three ESP cable legs at each electrical connection/splice. PULLING PROCEDURE 1. RU ESP cable spooling unit with empty cable spool installed.Ensure that the rig is properly centered over the well to prevent damage to the cable when pulling the ESP-remember that the tree is off center on the ESP wells and the rig must be centered with the tubing head adapter. 2. Notify Baker Hughes representative prior to releasing the hanger.A Baker Hughes representative shall be on location when the hanger penetrator is pulled.Close annular preventor.Slowly PU assembly until hanger is off tubing spooL If well is stable, open annular preventer. Record pick up and slack off weights. Continue PU until hanger is at rig floor. LD landing joint and hanger. • Check and record ESP conductivity phase-to-phase and phase-to-ground for all three Version 2.2 Page 1 of 8 This doc,m,mt is the property cif Baker Hushed and the informedon coahined herein In Pulling an EP Completion confidential and may not be distributed.either In part or In whole.nor cammuniaeted to ray competitor or potential ca npedmr a[Baker Higbee inc.0 2013 RECOMMEND PRACTICES phases below the hanger penetrator. • High-pot the hanger penetrator prior to reusing. This test shall be performed and recorded in accordance with manufacturer's recommended procedures. • Confirm ESP cable sheave is 54"in diameter.Confirm safety cable is attached to sheave. 3. Pull ESP completion. Spool the ESP cable onto the spooling unit while pulling out of hole.Wipe the cable with absorbent to prevent oil contamination.Depending on well conditions,it may be possible to keep some diesel cap as solvent in the annulus to aid in pulling the tubing with less residual crude oil. However,under no circumstance should the well be under-balanced. • Verbal acknowledgement between driller and spooler operator is required each time the completion is moved. • Portable gas detectors shall be available on the rig floor and in the spooling shed. Detectors shall be tested for proper operation prior to pulling cable. Gas checks shall be made periodically on the rig floor.Checks shall be made in the spooling unit whenever personnel enter the unit. • The entire length of the ESP cable shall be visually inspected as it conies out of the hole by the spooler operator. Flag visible bad spots in ESP cable and record approximate depths and cut out any damaged cable 5 foot above and 5 foot below the damage.Label each piece with the well,source,and depth-these will be sent to Baker Hughes at the end of the well for analysis. If there are several bad spots send the entire reel to Baker Hughes for analysis. • When bands are used they should be cut of;not twisted off as they come out of the hole. Record the number of bands suspected of being lost. • The hole shall be covered at all times when bands are being removed. • Cut out all pigtails and examine for signs of damage.Pigtails shall not be reused. 4. Pull ESP assembly but DO NOT lay it down. The ESP assembly must be inspected by section in the vertical position while on the rig floor by a Baker Hughes representative and a Pulling Inspection Report completed. 5. Lay down ESP 5.1. Discharge Assembly and Pump 5.1.1. All findings of the pump removal will be documented on the field service pull report. 5.1.2. Install the proper clamp on top of the pump. 5.13. Check the inside surface of the pump discharge for debris or wear.If shaft can be reached,rotate shaft(s)to check for side play and smooth shaft can be reached,rotate shaft(s)to check for side play and smooth rotation;record results on pull report. 5.1.4. Observe the pump as it is being lifted from well and look for paint scrapes,dings,scale,scratches,corrosion and scars.Check for indication of sand or scale behind protectors,flat cable and flat cable guards.Record findings on the pull report 5.1.5. Place an additional clamp on the lower pump and set on the work table. Cover the wellbore and carefully separate the pump,be ready to catch Vanden 2.2 Page 2 of 8 This document is the property&W m How math.information coot la.d herein I. Pulling an CSP Compilation oonedentl.l and may not be di.h+but.e,either in pare or in whole,nor communicated to any camp.titor or potential competitor of ads theism Inc.0 2013 R<COMMINDIPRACTICIIII I S the coupling. 5.1.6. After the two pumps are separated chock shaft rotation of both pumps and check the condition of o-rings,coupling and shaft. 5.1.7. Put the shipping cap on upper pump and carefully lay down upper pumP• 5.1.8. Check the top shaft of lower pump far shaft side play,plugging,scale, corrosion,erosion,shaft rotation. 5.1.9. Lift the lower pump to the intake and visually check the intake/gas sep. 5.1.10. Install a lifting clamp on the seal head 5.1.11. Cover the wellhead and disconnect the pump from the seal,catch the coupling.Check shaft for side play. 5.1.12. Place the coupling on the pump shaft and then shipping cap. 5.1.13. Carefully lay down the pump and intake. 5.1.14. The procedure for checking the rotary gas separator and recirculation pump is the same as checking the pump. 52. Seal Section 52.1. Check the shaft rotation of the seal and motor coupled together using the proper coupling wrench. 5.22. Remove the plug from the head vent. Note:Use caution when removing the vent plug,as the oil inside the seal section could be under pressure. 5.2.3. Remove the vent plug from the upper guide drain and drain off the well fluid.The fluid that drains from this area should be well fluids. 52.4. Remove the vent plug from the center guide drain and drain off the contents(should be motor oil only).Record the type and quantity of fluid drained from all chambers on the pulling report. 52.5. Remove the vent plugs from the lower guide drain and drain the fluid from the chamber. 52.6. Reinstall the vent plugs in the center guide and lower guide drains. 52.7. Reinstall the vent plug in head vent and the upper guide drain. 52.8. Clean and dry off the pothead motor connection area plus about 18 52.9. inches above the motor head with solvent,motor oil,rags or other means. Version 2.2 Page 3 of 8 This doormat is the property darker Hasher and the iafottnation cootained herein is Pulling en ESP Completion conlldeotlal and may not be distributed,either in put or in whole,nor communicated to any competitor or potential competitor oraeker Hushes bc.02013 RECOMMEND PRACTICES atinIES 52.10. Tie a rag around the bottom of the seal to prevent contamination of the pothead connection. 52.11. Disconnect the pothead by removing the socket head cap screws. 5.2.12. Remove the pothead with a straight pull,do not twist cr bend back and firth. CAUTION:WHILE YOU ARE DISCONNECTING THE POTHEAD, MAKE SURE NO WELL FLUID,WATER,OR OTHER FOREIGN MATERIAL GETS INTO THE OPEN TERMINAL INSULATION BLOCK. 52.13. Use the oil pump assembly to flush any foreign material out of the terminal insulation block area.Put the pothead shipping cap on the motor head. CAUTION:The motor electrical tests must always be done a safe distance from the wellhead as a safety precaution to prevent sparks generated by a megohmmeter igniting gasses emitted from the wellhead 52.14. Always perform the megobmeter test last;residual voltage charge left in the motor windings can damage motor rotation indicator and/or ohmmeter.Electrical test performed after a megohmmeter test should only be performed after the item has been shorted to ground for one (1)minute through the meter. 5.2.15. Put the correct clamp and lifting sling on the motor and set it on the wellhead. 52.16. Cover the wellhead to prevent fasteners or couplings from being dropped down the well. 52.17. Unbolt the seal section and lift it off the motor. 52.18. Capture a sample of the oil draining from the bottom of the seal section;note the condition of the oil on the pulling report 52.19. Set the motor shipping cap on the motor head and install two hex head cap screws to hold it temporarily in place while checking the seal section shaft rotation. 5220. Shaft rotation of seal section. 5221. Check the seal shaft for side play the same way the pump shaft was checked. 52.22. With the assistance of a rig hand,hold the seal section to one side while you pull the shipping cap off and check the motor shaft rotation. 52.23. Flush the motor to seal coupling with clean oil and put it back on the shaft. 5224. It is important to put the couplings back in the same location as shipped from the service center. Version 2.2 Page 4 of 8 nil domino is the property&Baker Hashes and the inform/dm osottised herds is Pulling an IsP Completion ooalfd.dd sad mg oat be diwlbured,tither is put err in whole,oar communicated .ryes pMhororpot•tiatoo.pedt.dasket Haden loo_02013 RECOMMEND PRACTICES 5.2.25. Install a clean shipping cap on the seal base flange and bolt it securely with two bolts and two nuts.Carefully lay the seal down. 5.3. Motor 5.3.1.Put the shipping cap on the top of the motor and secure with bolts. 5.3.2.Lift the motor from the well and look for drag marks and corrosion. 5.3.3.Remove the lower drain from the base of the motor to remove an oil sample for inspection. 5.3.4.Note the condition of the oil on the pulling report;dark,water, brass,steel,black,etc. 5.3.5.Replace the lower drain in the base and carefully lay the motor down. 5.3.6.After the equipment has been laid down and the motor has been moved a safe distance from the wellhead,perfonn the following electrical tests: 5.3.7.Use an ohmmeter and measure the motor phase to phase resistance (A to B,A to C and B to C),record the results on the pulling report. 5.3.8.Use a megohmmeter to measure the motor phase to ground resistance(A to ground,B to ground,and C to ground).The mcgohmmeter D.C.test voltage should be 1,000 volts for one minute,record readings on pulling report. 6. Ensure Baker Hughes ESP checklists are completed. 4) Ensure the Baker Hughes ESP Checklist has been • completed. • Version 2.2 Page 5 of!! Thin daunted is the property cl Baker Hughes and the information omuina herein is Pulling an ESP Completion confdmnei and may not be dimlbuted,either in part or in whole,nor communicated to my competitor or pomtlel oompettor of Braker Hughes Inc 0 2013 RECOMMEND PRACTICES S OOOGURUK ESP CI1ECKLIST PULLING THE ESP ASSEMBLY PART 1 OF 2 WELL: BAKER HUGHES REP (INITIAL ITEMS AS THEY ARE COMPLETED) Confirm spooler operator is qualified to operate spooler. Confirm all power is disconnected and properly locked out. Safety/planning meeting held at beginning of job describing all work to be done and safety procedures to be followed. Entire length of cable visually inspected.Bad spots flagged. Depths of bad spots: Identify any junk left in hole while pulling ESP completion. Number of cable bands suspected lost in hole= Phase conductivity checked at the hanger penetrator and recorded on Baker Hughes pulling report Phase conductivity checked below the hanger penetrator pigtail and recorded on Baker Hughes pulling report. Phase conductivity checked at the motor pothead and recorded on Baker Hughes pulling report Examine areas for solids,metal,vibration,or drag marks and record: Pump Discharge: Pump Intake: Pump Body: Seal Body: Motor. Motor Pothead: Version 2.2 Page 6 of tl This doorman is the property or Baker Hughes end dm information contained herda to Putting an ESP Completion confidential end may not be distributed,either in pert or In whale,nor eommuoinw to any competitor or potential competitor dasher Hughes Inc 0 2013 R■COMMuND PRACTIC!$ Motor Body: Version 2.2 Page 7 of 8 This doormat at ie the property cf Biker}tuition aad the information contained herein is Pulling an ESP Completion cmlldeotW rod may not be distributed,either in put or io whole,nor communicated to say cmtpsdtor or potential competitor of Baker thyltr km 0 2013 RECOMMINpdf RACTICIS 1101168 000GURUK ESP CHECKLIST PULLING THE ESP ASSEMBLY PART 2 OF 2 WELL: BAKER HUGHES REP -(INITIAL ITEMS AS THEY ARE COMPLETED) Attempt to manually turn.Check shaft play and coupling integrity for: Pump Discharge-Results: Pump Intake-Results: Gas Separator-Results: Seal Sections-Results: Motor-Results: Confirm Baker Hughes pulling report is completely filled out and is legible. Equipment boxed in shipping crates and ready to ship. Give completed form to Company Representative. Date: Comments: Version 2.2 Page 8 of 8 This document is the property drier.Hughes Ind the Information contained herein is Pulling an UP Completion oodldeodei sad may sot be distributed,either In pert or in whole,nor communicated to my ampedtor or potential competitor dBakr Hughes/no 01013 a -1 • v_____.: _1 • Liaf t o i I1 • I - p 0 II i1 I 4 — � �. i i a I \, > > �� "' I L . /�. km.,) -.- -1 , fix ,, 1 \ �T j 1 t. I If _= 7 c f§ i 4 414 ,-.-M I ! t F. r r I 1 r:.7 I 1 i 1::' 1 F_i Q r . . I ii 1 1 14 • 1 O ii `, . . I -1- 1 — O • I -__-- 0 1 w � I t ii‘w 0 - it- . 1 0 ► ' 1 V !to? ii sa r L 1 1 �� ti ien; , I _. M i i \ t_ — _ p.... 1 i 5 ife - - i11).# �$ :2 ����1 !i it allail 1 `i • A MAJOR O.D.: 5.500" SWAGE MINOR O.D.: 4.593" • ORIENTING CONNECTION O.D.: 3.625" 1111 SLEEVE WEIGHT: 6.4* MINIMUM LD.: 2.365" DRIFT LD.: 2.347" OVERALL LENGTH: 108' CONNECTION(s): TYPE: OVAL 5- MATERIAL: 4130 80 KSI I INTERNAL YIELD PRESSURE: 8,x00 PSI 1 EXTERNAL YIELD PRESSURE: 4,000 PSI j BODY YIELD STRENGTH: 250,000 LBF -" BODY PIPE BRINELL: 217-235 1 ROCKWELL C: 18-22 1 i 1 1 IOCKOVER TOOL: KOT 2,OM-1 RUNNING TOOL: RK-1 POCKET PULLING TOOL: 1518 JDS LATCH: RK,RKP 1.558"SEAL BORE VALVE: 1.5"O.D. --4 1.494"SEAL BORE �-- tj:l. aaea.moN 2.8 Fat SWAGE MANDREL ASSEMBLY sG� 641.1 liT OF O NO i 1 N/A 7 1 21125101 _J HALLIBURTON Engineering Data Sheet EQUIPMENT MATEIMAL NO.:I1000011172 Page lofl September 19,2019 1 LN 2313 X OCR BLNK I PART NUMBER:11Xm180-1 DESIGN SPECIFICATIONS LOCK PROFILE X SZE 2.313 MAXIMUM OD 3.240 Inah LENGTH 14.00 Inch MATERIAL OCR-1 MO SERVICE 1128 SERVICE REMARKS B BASED O C<sTOMER DEFINED, WELL SPECIFICapir4S. REVAPPENVI ENTAL SPECIFIC ITY MEETS MATERIAL SERVICE REQUIREMENTS OF MACE MR-01-75 TOP THREAD BLANK BOTTOM THREAD BLANK CONNECTION TYPE BLANK ==di w 1:7114�.�.+kwdepta==eilliove based koel dote and .These wkws wl1 wry%Whig aooepbd angIneedna Ani due b vandons In mannedeirsrylt.dMrsrsiorsl toleraross end stand Misled nonillions. NOTE Hlllrrlon nukes no meanly.seller expressed or kneled,as to the soaraoy riles deo or deny oakededona apinlon eiprssssd herein.Hswarbn,Odes.Turns.U.S.A. • Pape 1 of 3 HAWBURTON Sep6ember 19,2012 Engineering Oath Sheet EQUIPMENT MATERIAL NO.:182000100 TRSV,NE,4.e5 2313,1@8,5K PART NUMBER:478LXE11 DESIGN SPECIFICATIONS VALVE MODEL NE CLOSURE TYPE RAPPER SIZE 2 7A LOCK PROFILE X MINIMUM INSIDE DIAMETER WITHOUT PACKING BORE 2.350 Inch TOP SEAL BORE ID-MINIMUM 2.313 Inch BOTTOM SEAL BORE ID-MINIMUM 2.313 Inch MAXIMUM OD 4.65 Inds LENGTH 52.28 Inch p AVMs MATERIAL E �{1PH�STAINLESS STEEL SERVICE H28 SERVICE REMARKSS OL P _BASED MIlc BE ,�R SPECIFIC COMPATIBI MEETS MATERIAL SERVICE REQUIREMENTS OF NACE MR0175A8015158 TOP THREAD 2 7/84.40 DB BOTTOM THREAD 2 71 -8.40 DB CONNECTION TYPE BOX-PIN PRESSURE RATING 5000 poundu q.inch BURST PRESSURE 11541 pouddrq.loch API COLLAPSE PRESSURE AT AMBIENT 0155 pourdohq.Inch API COLLAPSE PRESSURE AT MAX TEMPERATURE RATING 8225 pourdo/oq.Inch EXTERNAL PRESSURE RATING 5000 pounddrq.Inch TENSILE WORK PRESS,WITHOUT TBO THD,AT AMBIENT, 144 pound CALC11 000 TENSILE WITHOUT WORK PRESS,WITHOUT 180 THD,AT 200 pond AMBIENT.CALC/1000 TENSILE WITH WORK PREVITHOUT TBG THD,AT MAX 117 pound TEMPERATURE RATING. 000 TENSILE HOT WORK PRESS. THOUT TB0 THD,AT MAX 182 pound TEMPERE RATING.CALC/1000 TEMPERATURE RATING 40 TO 300 Dog.F MAXIMUM FULL OPEN PRESSURE 2000 poud.Aq.loch Page 2 of 3 MINIMUM CLOSING PRESSURE 576 pound./q.Inch PISTON DISPLACEMENT VOLUME .58 ou.!rich EQUALIZING FEATURE YES MAXIMUM PRESSURE DIFFERENTIAL AT VALVE OPENING 5000 poud.Aq.kick CONTROL LINE PRESSURE TO EQUALIZE AT PRESSURE RATING 4000 pond. q.huh CONTROL UNE CONNECTION 7/16.20 HIF HIF KIT 101055653(83F1499) LOCKOUT TYPE NE COMMUNICATION TYPE NE LOCKOUT TOOL,PERMANENT 101597423(42L0X23107) LOCKOUT TOOL REMARKS asseAuro PRESSURE TO LOCK OUT 2000 poundwq.Inch EXERCISE TOOL. 101060065(42TL252) COMMUNICATION TOOL 101326555(42CTX23101) INSTALLATKMI EXTENSION PENDING WIRELINE REPLACEMENT VALVE 120065622(22FXE23112) RUNNINGIPULUNG PRONG EXTENSION PENDING ISOLATION ASSEMBLY LOCK MANDREL TYPE 2.313 X ISOLATION ASSEMBLY EQUALIZING VALVE TYPE 2.313 XO ISOLATION ASSEMBLY EXTENSION MANDREL PENDING ISOLATION SLEEVE 101073461 (75D2219) ISOLATION SLEEVE 0-RING 100006503(91QVI328-H) SPECIAL FEATURE EXERCISE PROFILE SEAT INSERT INSTALLATION TOOL 101281960(53012067) SEAT INSERT TORQUE-MIN 1600 bot pound BODY TORQUE 1900 bot pound SHOULDER BOLT TORQUE 90 Inch pound SPRING COMPRESSION TOOL gag(53M26811 101578655 DRIFT BAR 101085123(818104) DRIFT BAR OUTSIDE DIAMETER 2.303 Mt DRIFT BAR LENGTH 24.00 Inch TEST FIXTURE-BOX END 101906249(61724475) 101000811 (517121991 10100051 (51712200) TEST FIXTURE-PIN END 101905250(11724476),101090610 (81T12166),'10109061 (61 2200) APVISO TYPE SCTRSV MEETS QUALITY REQUIREMENTS API4311180 9001 MEETS INDUSTRY SPECIFICATION(8) API 14A/010 10432 APVISO SPECIFICATION EDITION ELEVENTH API/180 VALIDATION LEVEUSERVICE CLASS 1,38 APVISO VALIDATION DATE 05-12-11 API1180 VALIDATION METHOD VARIATION • Page 3 of 3 APVISO VALIDATION REFERENCE 79001213 OPERATING ENVELOPE 479LXE11 BDMVTECHNICAL OPERATIONS MANUAL 479LXE11 �oM� , l>� OTE:�VMii d p us.ioios and opealln0 depths=nose are Ord upon snplrbtl date and 1MonMoel calculations.Thee values err vary ea*accepted ariensedng Inds due to varledans In mewed sbanp/%.dimensional tolerances and acWsl installed wagons. OIdOTE:Hellburion melees no vrunanllr,slur expressed or implied,is lo the accuracy oldie data or of any alaidsnor opinion s.., N4 herein.tlallbuaten,Deis Tem,U A Pagel di I-IALLIBURTON ?Aay 23,2019 Engineering Data Sheet EQUIPMENT MATERIAL.NO.:181002771 HYDR CONTRL UNE,14,.049,3000,318L PART NUMBER:2381OLi1300 DESIGN SPECIFICATIONS TUBING MATERIAL 3181.STAINLESS STEEL TUBING TYPE WELDED AND SUNK TUBING OUTSIDE DIAMETER .25 Groh TUBING WALL THICKNESS .049 Inch LENGTH 9000 bat FITTING MATERIAL 3181.STAINLESS STEEL CONNECTION 1/4 TBG X 1/8 MP PRESSURE RATING 17000 poudahq.Inch TEST PRESSURE 18000 ponds/q.Inch SPOOL-OFF DEVICE 7X 20X 38 aeiD1 NOOsTEs: ddpn ONMwa,uloisuss,and wending Opine =blow to basad upon ampbioal dale end theorelkel CUndi forst.Thsaa Maus ea tory wllhln soospbd anniiaNUp Inns due to millions In aMMetUI Wen..dbeenslond tolerances and Elul InpYad conditions. NOTE:Nsbulon melon no slier syringed or Implied.es lob ammo of is dna or deny aladallon or opinion eopeaed amain.Newlon,Daae,Tsps.U.S.A. Wellhead, Conductor and Client: Pioneer Natural Resources Installation: Exploration �t Surface Loading Well: ODS K13 --- ops'#) " I Y J``"`- "`s Weight of Cudd 340T Snubbing Unit=91,100# Date: TBD se4-- '-4- Weight of BOP equipment and riser=34.000# 125,100# 42.7 0 0 c PIONEER 10%= 137,600# 100 0.34 221.19 168 0.16 130.95 20%= 150.120# Pull 11,800 ft of 3-%"9.2#/ft Tubing 115,000# 350 0.37 12533 7•z.-t• r3 Pull/Run 4'/" 12.6#/ft L-80 Hydril 521=150,000# 441 1.19 307.31 Worst Case is 300,000#on Wellhead 532 1.95 322.83 gni 573.71 1.85 317.8 626.58 3.17 315.66 Lm671.26 4.3 316.56 P.".9M&33 I I'I 763.81 6.86 316.45 _\--c V- Tree 813.54 8.01 316.35 s 860.24 8.6 315.98 909.76 9.51 313.9 A �.........t '''. OA 956.78 9.35 312.67 27"un-supported1,005.95 9.18 310.28 Ir_+EE- length 1.049.84 11.17 311.64 1,096.33 13.93 309.8 o Weldless Landing Ring on 1,145.56 15.24 312.6 a the 16"Conductor 1,194.22 15.31 310.88 n 1,240.56 16.78 310.92 0 1,289.96 18.95 309.46 (/) 1,336.79 20.72 308.92 CD 16" 109#/ft ID= 14.688"WT 1,384.42 22.51 306.84 °= =0.656"Conductor pile driven 1.430.42 23.07 305.99 0 o to 150 ft. 1,479.83 23.39 304.58 c) 1,525.32 23.94 305.1.5 1,576.16 24.01 305.92 1,621.34 24.33 306.96 1,671.07 25.79 307.41 y A 1,705.60 25.58 308.15 0 1,766.84 25.73 308.07 Halliburton PermaFrost L 1,811.68 2557 310.02 n Density= 10.6-10.9ppg 1,864.43 2554 31244 m Yield=3.77cf/sxs 3 1907.09 25.51 313.53 WR= 16.1 gal/sxs 1,958.99 26.92 315 Compressability=250-350 2.001.97 27.61 317.05 14-1/2"hole drilled to :::::: psi in 42 days 2.097.12 28.74 323.48 approximately 3500 :::::� 2,192.69 29.36 331.16 ft MD z 241.25 29.14 334.14 _� : Ran 3500 ft 11-3/4"60#/ft L- 2,287.81 29.36 334.8 :::: 80 Hydril 521 Surface 2,383.06 33.63 338.04 Casing 2,477.86 36.61 342.39 ID 0 10.77"DD= 10.62" 2,530.79 38.32 345.12 Internal Yield=5830 psi 2,572..80 40.97 347.17 Compression 3180 psi 2,619.68 42.07 349.45 . i;i:i; 2,668.18 44.23 350.62 2,763.56 46.77 352.08 2,857.18 49.32 354.88 2,953.56 52.79 357.15 3,048.04 54.5 358.46 Halliburton Premium Cement 3.143.06 57.3 358.73 01 o Density= 15.9 ppg 3,239.01 61.3 359.87 Yield= 1.19 cf/sxs 3,332.55 64.45 1.07 --I WR=5.23 gal/sxs 3,429.23 64.2 1.45 Compressability=2500-3500 3,a6s.z4 63.59 2.08 psi in 72 days 3,5'78.71 62.75 2.28 A 3,677.09 61.59 5.97 3,770.79 62.04 10.47 3500 ft 3,866.65 62.81 14.3 3,960.85 62.51 16.53 DRAWING#1 4,055.97 63.27 19.06 3404Leg 11" 5k (0002) J Snubbing Unit w/WO no 2,500-3,000 lb Gin Pole with j. A Stack _ Hydraulic winch to PUILD o tubulars and misc equipment Schematic for ODS K13 f PIONEER 2.0"1502 Fill up Hardline, Swivel Attaches wl Kelly Hose50ft 340 11"5 K 4 Leg 12 ft --Traveling Heavy Slips above jack plate stroke Snubbing Unit 1I\•all w/workover stack • r n I Rotary Table develop 3000k Torque at 100 RPM r IJ �r-111--...,.._____ rn 1 .� ravelers Pipe Light/Snubbing Slips AJack Cylinders o API Ring Requirements Cf ,1\ I14 Ctationary Pipe Heavy Slips �V,��-4 • 11.00" 5 k API Ring= R54 i' Stationary Pipe Light Slips 4-1/16"5k API Ring= R39 3-1/8"5k API Ring= R35 -4I--10 ft Work Window 2-1/16"5k API Ring=R24 Fluid in from PumpI. ,174111— Spider/Slips Heavy Slips and Tankage for k_ filling up of Tubular "4I 011111111401110 D i Aan®theeA., 11"5k Shaffer Spherical 11"5k Shaffer Spherical Annular / 11"5k NOV/T3 Double Gate , , ••. : , 2-1/16"15k Choke .� ��.` BOP w/2-7/8"X 5"VBR's �1 p.� Manifold Fluid in from Top&Blind Shears on Btm CQ�`•' - MC-1 r••• Pump and 301 •• Milli-4 I Tankage 1-4-1/16"5 k Manual Valve 1- .® O t] 4-ve••X 3-va DSA mind Q ft,3-1/18"5 4-1/16"HCR and 4-1/16'5k k C CV-4 check Valve m I i' CHOKE LINE 1 u :: ::::. .. :.... .. :EIIIIII MA 1.I 'Mud ICross , 11'=�I11::::: :EII*i■ 1111111 - I 50ft3-1/18"5k HP Ilk Kill Line Hose - araDI.•I `•m• 4-1/1r 5k Manual C-2 C-5 PMV 2 • • Top of Well House Iii '`Q •, Ill Valve w/HCR *IN 111-E'-HELI MC-2 11"5k NOV/T3 Single Gate PMV 1 KILL LINE p ii BOP w/2-7/8"X5"VBR's mill I I Eu.t.-> 11"5k X "5 I 94"Vetco Gray Spacer 3-1/8"5 K i PMV 3 A Studded Adaptor Reverse ��r' V-Lock with Gray Lock Clamp E-� Manifold III MB - �� �h EII I - Tree 2"1502 Fillup Line �`?� I Run to the Basket and _I' .)1 swivel T S • • 1 . I il II -- uuaa.0�-- OA ((WITH FILL UP SPOOL)) ((WITHOUT FILL UP SPOOL)) TOTAL STACK HEIGHT:162.70"(13'-. , I'AL STACK HEIGHT: 136.86"(11'-05") TOTAL STACK WEIGHT: 35,771#(EST.) TOTAL STACK WEIGHT:33,597#(EST.) 11"5M DRILUNG SPOOL W/(1)2"1502 PLUG VALVE 8 IL) LLB """"""""""'G" MO ■ (1)4-1/16"5M MANUAL GATE VALVE X 4"FIG.100 � THREAD OUTLET l 1� (FLANGED TOP/BTM) `' J HEIGHT:25.750" ■ LENGTH:83.250"(EST.) "'"" " ""m m WEIGHT:2,174#(EST.) l 1 1 1 AI.IIII.II.II.IIII 7 SURGE BOTTLE 11"5M SHAFFER ANNULAR 5 GALLON (STUDDED TOP/FLANGED BTM) 200 P.SI.PRECHARGE HEIGHT:41.500" CLEARANCE DIAMETER:44.750" WEIGHT:9,550#(EST.) OPEN:14.59 GAL/CLOSE:18.67 GAL. ,.amu ISI 11"5M(NOV/T3)MODEL"6012"DOUBLE BOP ' ' " , (W/LARGE BORE BONNETS&TANDEM BOOSTERS INSTALLED BTM) (STUDDED TOP/FLANGED BTM) HEIGHT:46.0468" LENGTH:(CLOSED)134.125" o ° o LENGTH:(OPEN)184.750" Ili 0.9: WEIGHT:12,800#(EST.) PIPE (PIPE)OPEN:6.2 GAL./CLOSE:6.2 GAL. (SHEAR)OPEN:6.8 GAL I CLOSE:13.5 GAL. K-1 ° ° ° ■ °�°� DRILLING SPOOL:11"5M (W14-1/16"5M CHOKE UNE(MANUAL I HYDRAULIC)) 0 SHR/BLD CL-2 0 C 2 (W/4.1116"5M KILL LINE(MANUAL I HYDRAULIC) � &4-1/16"5M FLAPPER STYLE CHECK VALVE) i rrn I/1 ' , (STUDDED TOP/BTM) HEIGHT:15.000" LENGTH:139.375"(EST.) WEIGHT:5,197#(EST.) IIII „ CL-1 1/11 W1 On IW ' ILIJ LW 1111 (4"5M HCR/EA.)OPEN:0.30 GAL/CLOSE:0.39 GAL. an m, mm, FM. MI _-= = SUPPLIED BY CPCI n K-2 " " " 0 D.S.A.:4-1/16"5M X2-1/16"5M "'In "' D.S.A.:4-1/16"5M X2-1116"5M 0 PIPE ii'I( 1.iu 11"5M(NOV/T3)MODEL"6017SINGLE BOP � (FLANGED TOP/BTM) uTZITL7TUui HEIGHT:34.3125" LENGTH:(CLOSED)96.25E' LENGTH:(OPEN)146.875" WEIGHT:6,050#(EST.) OPEN:6.2 GAL./CLOSE:6.2 GAL. BOP HYDRAULIC INFORMATION REFLECTED ON THIS SCHEMATIC ARE"PER CAVITY" PREMIUM PIONEER NATURAL RESOURCES/CUDD PRESSURE CONTROL INC. ,�. T 0 0 L s PRUDHOE BAY/ALASKA PROJECT LAFAYETTE,LA./WATFORD CITY,ND. 337-857-6511 AUTHORED BY: JIMMY HOLDEN DATE: 03/12/13 (REV#7) THIS IS A SCHEMATIC REPRESENTATION OF THE CUSTOMER'S ORDER AND DESIGN TO CONFIRM EQUIPMENT PIONEER NATURAL RESOURCES ALASKA BOP Testing Sequence ODSK-13 and ODSN-18 Cudd Rig 136 Workovers • Begin w/all valves open • Test to 250 psi low/3500 psi high both for 5 minutes each • Fill stack w/water • Makeup test string Test#1—Testing Ram#2(Blind/Shear), P-1, P-2,SP-1,PMV-1,PMV-3,C-3,C-4,C-5 • Close Ram#2 and Valves#P-1,P-2,SP-1,PMV-1,PMV-3,C-3,C-4,C-5 • Perform Pressure Test by pumping through lower kill line Test#2—Testing Ram#3(Safety) PMV-4 • Run Pipe and make up into hanger • Close Ram#3 and Valve#PMV-5 • Perform Pressure Test by pumping down test string. • Note: To bleed off test pressure, bleed off through choke manifold Test#3—Testing Ram#1(Safety)Valves#CV-1,C-1,C-2 • Open Ram#3 Valve# PMV-4 • Close Ram#1(ensure space out allows BOP closure,Valves CV-1,C-1, C-2 • Perform Test by pumping down test string. Test#4—Testing Ram#1(Safety), K-1,CL-2 • Open Valve#CV-1,C-1, C-2, Close Valve# K-1, CL-2 • Perform Test by pumping down test string. Test#5—Testing Annular Ram Valves#K-2,CL-1 • Open Ram#1 • Close Annular Ram • Close Valve#K-2, CL-1 • Open Valve#K-1, CI-2 • Perform Test by pumping down test string. Test#6—Make up (2)TIWs and Inside BOP together in ground • Open all Valves and fill with test pump • Close Inside BOP and test • Preform test Test#7—Testing TIW#1 valve • Open Inside BOP • Close#1 TIW • Perform test. Test#8—Testing TIW Valve#2 • Open TIW Valve#1 • Close TIW Valve#2 • Perform test. Test#9—Testing PMV-2, PMV-5 • Open TIW Valve#2 • Tie in Test pump into Tee on fluid pumps • Close PMV-2, PMV-5 • Preform Test *iiA la Y .4E-- y C 111111111111111111.1111111.11111 :::: of to H d !0 a, g N en 8 I ;{: a c 011. ii C A =J H Q h 8 0 O N N 70 a0 L el om 1.4' `' V O= J \I 11,::::::INI g ‘11 11%0=0E4 ..=.14-11mi .r _ H 'Ih^il o E , III 8 C'. 1' m =V\:> [ (i'-'7). 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R- IIIA I I -, m o v/ O N ® ® II • O F o A N ® o o x ® I o o a m p 64 Dm c IICD ® © ! ® p - ® O ❑ O 0 IIIiiiI. 1111111Alti' ® 0 ® * 0 O 0 O 0 0 of EL;;:177,:_-gl A) i Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-18 Permit to Drill: 210-142 API: 50-703-20624-00-00 Sperry Drilling Services Definitive Survey Report 31 January, 2011 HALLIBURTON Sperry Drilling Services Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+ 13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 Database: .Pioneer 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 ODSN-18-Slot ODS-18 Well Position +N/-S 0.00 ft Northing: 6,031,051.27 ft Latitude: 70°29'45.254 N +E/-W 0.00 ft Easting: 469,821.18 ft Longitude: 150° 14'48.375 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSN-18 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-18 PN11 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 13,156.84 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 290.79 Survey Program Date 1/27/2011 • From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 141.00 981.00 ODSN-18 PB1 Gyro 1 (ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 10/25/2010 1,027.53 1,027.53 ODSN-18 PB1 MWD 1 (ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/2/2010 t 1,123.00 1,123.00 ODSN-18 PB1 Gyro 2(ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 11/2/2010 1: 1,174.43 3,566.42 ODSN-18 PB1 MWD 2(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/26/2010 • 3,630.15 8,392.12 ODSN-18 PB1 MWD 3(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/1/2010 1; 8,438.00 12,090.00 ODSN-18 PB2 MWD 4(ODSN-18 PB2) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/5/2010 1: 12,122,46 12,771.79 ODSN-18 PB3 MWD 5(ODSN-18 PB3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/22/2010 12,850.00 13,156.84 ODSN-18 PB4 MWD 6(ODSN-18 PB4) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/30/2010 ' 13,250.00 16,630.89 ODSN-18 MWD 8(ODSN-18) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 1/6/2011 12: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-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 6,031,051.27 469,821.18 0.00 0.00 UNDEFINED 141.00 0.26 304.00 141.00 84.80 0.13 -0.19 6,031,051.40 469,820.99 0.26 0.22 SR-Gyro-SS(1) 199.00 0.27 348.71 199.00 142.80 0.33 -0.32 6,031,051.60 469,820.86 0.35 0.42 SR-Gyro-SS(1) 232.00 0.49 322.56 232.00 175.80 0.52 -0.42 6,031,051.79 469,820.76 0.83 0.58 SR-Gyro-SS(1) 290.00 0.48 322.52 290.00 233.80 0.91 -0.72 6,031,052.18 469,820.46 0.02 1.00 SR-Gyro-SS(1) 323.00 0.93 308.43 322.99 266.79 1.19 -1.02 6,031,052.46 469,820.17 1.45 1.37 SR-Gyro-SS(1) 382.00 1.25 295.72 381.98 325.78 1.76 -1.97 6,031,053.04 469,819.22 0.68 2.47 SR-Gyro-SS(1) 1/31/2011 9:37:37AM Page 2 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 Database: .Pioneer 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 415.00 1.90 288.47 414.97 358.77 2.09 -2.81 6,031,053.38 469,818.38 2.06 3.37 SR-Gyro-SS(1) 472.00 2.17 284.07 471.93 415.73 2.66 -4.76 6,031,053.94 469,816.43 0.55 5.39 SR-Gyro-SS(1) 505.00 2.74 284.05 504.90 448.70 3.00 -6.13 6,031,054.29 469,815.06 1.73 6.79 SR-Gyro-SS(1) 568.00 3.14 281.82 567.82 511.62 3.72 -9.28 6,031,055.03 469,811.92 0.66 9.99 SR-Gyro-SS(1) 601.00 3.54 281.44 600.76 544.56 4.11 -11.16 6,031,055.42 469,810.04 1.21 11.89 SR-Gyro-SS(1) 662.00 3.66 281.14 661.64 605.44 4.86 -14.92 6,031,056.19 469,806.28 0.20 15.67 SR-Gyro-SS(1) 685.00 3.95 280.22 684.59 628.39 5.14 -16.42 6,031,056.47 469,804.79 1.29 17.17 SR-Gyro-SS(1) 758.00 4.41 281.46 757.40 701.20 6.14 -21.64 6,031,057.50 469,799.57 0.64 22.41 SR-Gyro-SS(1) 791.00 4.78 281.29 790.29 734.09 6.66 -24.23 6,031,058.03 469,796.98 1.12 25.02 SR-Gyro-SS(1) 853.00 5.29 282.35 852.05 795.85 7.78 -29.56 6,031,059.17 469,791.66 0.84 30.39 SR-Gyro-SS(1) 886.00 5.85 279.85 884.90 828.70 8.39 -32.70 6,031,059.79 469,788.52 1.85 33.55 SR-Gyro-SS(1) 948.00 6.88 279.90 946.51 890.31 9.57 -39.47 6,031,061.00 469,781.75 1.66 40.30 SR-Gyro-SS(1) 981.00 6.89 278.10 979.28 923.08 10.19 -43.38 6,031,061.64 469,777.85 0.65 44.17 SR-Gyro-SS(1) 1,027.53 6.83 276.30 1,025.47 969.27 10.89 -48.89 6,031,062.35 469,772.34 0.48 49.57 MWD+IFR2+MS+sag(2) 1,123.00 9.55 277.06 1,119.96 1,063.76 12.48 -62.40 6,031,064.01 469,758.84 2.85 62.76 SR-Gyro-SS(3) 1,174.43 9.71 277.20 1,170.67 1,114.47 13.55 -70.93 6,031,065.11 469,750.31 0.31 71.12 MWD+IFR2+MS+sag(4) 1,218.54 9.91 278.29 1,214.13 1,157.93 14.57 -78.38 6,031,066.15 469,742.87 0.62 78.45 MWD+IFR2+MS+sag(4) 1,314.10 9.75 271.65 1,308.29 1,252.09 15.98 -94.61 6,031,067.64 469,726.65 1.20 94.12 MWD+IFR2+MS+sag(4) 1,409.32 10.15 272.52 1,402.08 1,345.88 16.59 -111.05 6,031,068.30 469,710.21 0.45 109.70 MWD+IFR2+MS+sag(4) 1,504.37 10.95 274.95 1,495.52 1,439.32 17.73 -128.41 6,031,069.52 469,692.86 0.96 126.34 MWD+IFR2+MS+sag(4) 1,599.91 12.48 272.29 1,589.07 1,532.87 18.93 -147.77 6,031,070.80 469,673.51 1.70 144.86 MWD+IFR2+MS+sag(4) 1,631.69 12.76 273.11 1,620.08 1,563.88 19.26 -154.70 6,031,071.15 469,666.57 1.05 151.46 MWD+IFR2+MS+sag(4) 1,725.28 14.37 274.13 1,711.06 1,654.86 20.65 -176.61 6,031,072.64 469,644.68 1.74 172.44 MWD+IFR2+MS+sag(4) 1,821.10 13.44 273.34 1,804.07 1,747.87 22.16 -199.58 6,031,074.24 469,621.71 0.99 194.45 MWD+IFR2+MS+sag(4) 1,915.58 15.28 274.70 1,895.59 1,839.39 23.82 -222.95 6,031,075.99 469,598.35 1.98 216.89 MWD+IFR2+MS+sag(4) 2,011.74 15.85 275.48 1,988.23 1,932.03 26.11 -248.65 6,031,078.39 469,572.66 0.63 241.73 MWD+IFR2+MS+sag(4) 2,107.39 14.66 274.53 2,080.51 2,024.31 28.31 -273.72 6,031,080.69 469,547.60 1.27 265.95 MWD+IFR2+MS+sag(4) 2,202.94 13.62 277.80 2,173.16 2,116.96 30.80 -296.92 6,031,083.27 469,524.41 1.37 288.52 MWD+IFR2+MS+sag(4) 2,241.41 13.96 276.43 2,210.52 2,154.32 31.93 -306.02 6,031,084.44 469,515.32 1.23 297.43 MWD+IFR2+MS+sag(4) 2,298.61 14.97 276.21 2,265.91 2,209.71 33.50 -320.22 6,031,086.07 469,501.13 1.77 311.26 MWD+IFR2+MS+sag(4) 2,333.40 15.89 274.27 2,299.44 2,243.24 34.34 -329.44 6,031,086.95 469,491.92 3.03 320.18 MWD+IFR2+MS+sag(4) 2,393.28 16.92 271.13 2,356.89 2,300.69 35.12 -346.33 6,031,087.80 469,475.03 2.27 336.24 MWD+IFR2+MS+sag(4) 2,488.03 20.47 266.74 2,446.63 2,390.43 34.45 -376.67 6,031,087.25 469,444.70 4.03 364.37 MWD+IFR2+MS+sag(4) 2,583.22 24.38 267.73 2,534.60 2,478.40 32.73 -412.93 6,031,085.67 469,408.43 4.13 397.66 MWD+IFR2+MS+sag(4) 2,678.36 29.60 267.12 2,619.35 2,563.15 30.77 -456.05 6,031,083.89 469,365.31 5.49 437.27 MWD+IFR2+MS+sag(4) 2,773.39 32.86 268.44 2,700.60 2,644.40 28.89 -505.27 6,031,082.21 469,316.08 3.51 482.62 MWD+IFR2+MS+sag(4) 2,868.92 36.48 268.01 2,779.16 2,722.96 27.20 -559.58 6,031,080.73 469,261.77 3.80 532.79 MWD+IFR2+MS+sag(4) 2,963.62 38.66 267.56 2,854.21 2,798.01 24.96 -617.27 6,031,078.73 469,204.08 2.32 585.94 MWD+IFR2+MS+sag(4) 3,059.68 38.65 266.41 2,929.23 2,873.03 21.80 -677.19 6,031,075.82 469,144.15 0.75 640.83 MWD+IFR2+MS+sag(4) 3,155.09 41.44 265.51 3,002.26 2,946.06 17.46 -738.41 6,031,071.73 469,082.92 2.99 696.53 MWD+IFR2+MS+sag(4) 1/31/2011 9:37:37AM Page 3 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 3,249.55 42.15 264.91 3,072.68 3,016.48 12.20 -801.15 6,031,066.73 469,020.17 0.86 753.31 MWD+IFR2+MS+sag(4) 3,344.92 46.28 265.36 3,141.02 3,084.82 6.58 -867.40 6,031,061.37 468,953.90 4.34 813.25 MWD+IFR2+MS+sag(4) 3,439.63 48.20 265.43 3,205.32 3,149.12 0.99 -936.71 6,031,056.07 466,884.58 2.03 876.07 MWD+IFR2+MS+sag(4) 3,534.85 49.89 264.83 3,267.73 3,211.53 -5.12 -1,008.36 6,031,050.25 468,812.91 1.84 940.88 MWD+IFR2+MS+sag(4) 3,566.42 50.37 265.46 3,287.97 3,231.77 -7.17 -1,032.50 6,031,048.30 468,788.76 2.16 962.73 MWD+IFR2+MS+sag(4) 3,630.15 49.94 264.80 3,328.80 3,272.60 -11.32 -1,081.25 6,031,044.34 468,740.00 1.04 1,006.83 MWD+IFR2+MS+sag(5) 3,728.64 48.98 264.86 3,392.82 3,336.62 -18.06 -1,155.80 6,031,037.90 468,665.44 0.98 1,074.13 MWD+IFR2+MS+sag(5) 3,823.03 48.55 265.70 3,455.04 3,398.84 -23.91 -1,226.54 6,031,032.35 468,594.68 0.81 1,138.19 MWD+IFR2+MS+sag(5) 3,918.36 47.71 266.13 3,518.66 3,462.46 -28.97 -1,297.34 6,031,027.57 468,523.86 0.94 1,202.59 MWD+IFR2+MS+sag(5) 4,013.58 47.75 266.18 3,582.71 3,526.51 -33.69 -1,367.65 6,031,023.14 468,453.55 0.06 1,266.64 MWD+IFR2+MS+sag(5) 4,108.84 51.32 267.02 3,644.52 3,588.32 -37.97 -1,439.98 6,031,019.15 468,381.20 3.81 1,332.74 MWD+IFR2+MS+sag(5) 4,203.49 54.06 266.88 3,701.89 3,645.69 -41.98 -1,515.15 6,031,015.45 468,306.03 2.90 1,401.59 MWD+IFR2+MS+sag(5) 4,300.86 56.97 265.70 3,757.01 3,700.81 -47.19 -1,595.23 6,031,010.56 468,225.93 3.15 1,474.61 MWD+IFR2+MS+sag(5) 4,398.80 58.70 262.86 3,809.16 3,752.96 -55.47 -1,677.71 6,031,002.62 468,143.43 3.02 1,548.78 MWD+IFR2+MS+sag(5) 4,493.85 61.31 259.87 3,856.68 3,800.48 -67.85 -1,759.07 6,030,990.57 468,062.03 3.87 1,620.44 MWD+IFR2+MS+sag(5) 4,584.47 65.00 259.37 3,897.60 3,841.40 -82.42 -1,838.58 6,030,976.32 467,982.46 4.10 1,689.61 MWD+IFR2+MS+sag(5) 4,684.58 67.49 257.58 3,937.92 3,881.72 -100.74 -1,928.35 6,030,958.37 467,892.63 2.98 1,767.03 MWD+IFR2+MS+sag(5) 4,779.26 68.84 257.43 3,973.14 3,916.94 -119.76 -2,014.15 6,030,939.70 467,806.76 1.43 1,840.50 MWD+IFR2+MS+sag(5) 4,871.89 70.51 256.93 4,005.31 3,949.11 -139.03 -2,098.85 6,030,920.77 467,722.00 1.87 1,912.84 MWD+IFR2+MS+sag(5) 4,965.11 71.34 257.43 4,035.78 3,979.58 -158.58 -2,184.75 6,030,901.58 467,636.02 1.02 1,986.21 MWD+IFR2+MS+sag(5) 5,063.57 71.46 258.28 4,067.18 4,010.98 -178.21 -2,275.98 6,030,882.32 467,544.73 0.83 2,064.53 MWD+IFR2+MS+sag(5) 5,159.38 71.34 258.20 4,097.74 4,041.54 -196.72 -2,364.88 6,030,864.17 467,455.76 0.15 2,141.07 MWD+IFR2+MS+sag(5) 5,254.53 71.20 258.00 4,128.29 4,072.09 -215.30 -2,453.05 6,030,845.95 467,367.52 0.25 2,216.91 MWD+IFR2+MS+sag(5) 5,345.36 70.63 257.39 4,157.99 4,101.79 -233.59 -2,536.92 6,030,828.00 467,283.59 0.89 2,288.82 MWD+IFR2+MS+sag(5) 5,441.12 71.23 257.83 4,189.28 4,133.08 -253.01 -2,625.31 6,030,808.94 467,195.13 0.76 2,364.57 MWD+IFR2+MS+sag(5) 5,536.74 71.07 258.19 4,220.17 4,163.97 -271.81 -2,713.83 6,030,790.51 467,106.54 0.39 2,440.65 MWD+IFR2+MS+sag(5) 5,631.50 70.36 258.20 4,251.47 4,195.27 -290.11 -2,801.38 6,030,772.57 467,018.93 0.75 2,516.00 MWD+IFR2+MS+sag(5) 5,727.44 70.95 258.18 4,283.25 4,227.05 -308.63 -2,889.99 6,030,754.40 466,930.25 0.62 2,592.26 MWD+IFR2+MS+sag(5) 5,824.68 70.61 258.07 4,315.26 4,259.06 -327.53 -2,979.84 6,030,735.87 466,840.33 0.37 2,669.56 MWD+IFR2+MS+sag(5) 5,917.59 70.86 257.56 4,345.92 4,289.72 -346.04 -3,065.57 6,030,717.71 466,754.54 0.58 2,743.14 MWD+IFR2+MS+sag(5) 6,011.23 71.05 257.12 4,376.47 4,320.27 -365.44 -3,151.94 6,030,698.66 466,668.11 0.49 2,816.99 MWD+IFR2+MS+sag(5) 6,109.85 70.29 255.57 4,409.12 4,352.92 -387.41 -3,242.36 6,030,677.07 466,577.60 1.67 2,893.74 MWD+IFR2+MS+sag(5) 6,206.00 70.35 256.98 4,441.50 4,385.30 -408.89 -3,330.31 6,030,655.95 466,489.58 1.38 2,968.33 MWD+IFR2+MS+sag(5) 6,296.96 70.47 257.77 4,472.00 4,415.80 -427.62 -3,413.93 6,030,637.56 466,405.89 0.83 3,039.86 MWD+IFR2+MS+sag(5) 6,392.50 70.96 258.81 4,503.55 4,447.35 -445.92 -3,502.23 6,030,619.62 466,317.52 1.15 3,115.92 MWD+IFR2+MS+sag(5) 6,487.74 71.03 259.25 4,534.57 4,478.37 -463.05 -3,590.63 6,030,602.84 466,229.06 0.44 3,192.48 MWD+IFR2+MS+sag(5) 6,582.74 70.87 258.69 4,565.57 4,509.37 -480.23 -3,678.77 6,030,586.02 466,140.86 0.58 3,268.78 MWD+IFR2+MS+sag(5) 6,677.75 70.73 259.06 4,596.82 4,540.62 -497.54 -3,766.81 6,030,569.07 466,052.76 0.40 3,344.94 MWD+IFR2+MS+sag(5) 6,773.48 71.16 258.45 4,628.07 4,571.87 -515.19 -3,855.56 6,030,551.79 465,963.95 0.75 3,421.65 MWD+IFR2+MS+sag(5) 6,868.81 71.27 257.68 4,658.77 4,602.57 -533.85 -3,943.86 6,030,533.48 465,875.59 0.77 3,497.57 MWD+IFR2+MS+sag(5) 1/31/2011 9:37:37AM Page 4 COMPASS 2003.16 Build 42F • Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 6,964.81 70.80 259.14 4,689.97 4,633.77 -552.10 -4,032.79 6,030,515.61 465,786.59 1.52 3,574.24 MWD+IFR2+MS+sag(5) 7,058.66 71.73 258.75 4,720.12 4,663.92 -569.14 -4,120.02 6,030,498.92 465,699.30 1.07 3,649.74 MWD+IFR2+MS+sag(5) 7,155.94 70.48 258.65 4,751.62 4,695.42 -587.17 -4,210.27 6,030,481.25 465,608.99 1.29 3,727.72 MWD+IFR2+MS+sag(5) 7,249.11 70.27 258.33 4,782.91 4,726.71 -604.68 -4,296.26 6,030,464.09 465,522.93 0.39 3,801.89 MWD+IFR2+MS+sag(5) 7,345.08 71.16 258.01 4,814.61 4,758.41 -623.25 -4,384.92 6,030,445.88 465,434.21 0.98 3,878.19 MWD+IFR2+MS+sag(5) 7,441.17 70.89 257.84 4,845.85 4,789.65 -642.26 -4,473.78 6,030,427.24 465,345.28 0.33 3,954.51 MWD+IFR2+MS+sag(5) 7,536.09 69.56 258.34 4,877.96 4,821.76 -660.70 -4,561.18 6,030,409.16 465,257.82 1.49 4,029.68 MWD+IFR2+MS+sag(5) 7,626.41 69.56 260.20 4,909.51 4,853.31 -676.45 -4,644.33 6,030,393.74 465,174.61 1.93 4,101.82 MWD+IFR2+MS+sag(5) 7,726.42 69.36 260.00 4,944.60 4,888.40 -692.56 -4,736.58 6,030,378.02 465,082.30 0.27 4,182.35 MWD+IFR2+MS+sag(5) 7,820.69 69.02 260.88 4,978.09 4,921.89 -707.19 -4,823.48 6,030,363.74 464,995.36 0.94 4,258.40 MWD+IFR2+MS+sag(5) 7,915.20 69.21 260.17 5,011.78 4,955.58 -721.73 -4,910.57 6,030,349.56 464,908.21 0.73 4,334.66 MWD+IFR2+MS+sag(5) 8,011.00 69.69 260.57 5,045.41 4,989.21 -736.73 -4,999.01 6,030,334.91 464,819.72 0.64 4,412.02 MWD+IFR2+MS+sag(5) 8,106.40 69.26 260.81 5,078.86 5,022.66 -751.19 -5,087.18 6,030,320.82 484,731.51 0.51 4,489.31 MWD+IFR2+MS+sag(5) 8,201.28 69.17 260.04 5,112.53 5,056.33 -765.94 -5,174.65 6,030,306.42 464,643.99 0.76 4,565.85 MWD+IFR2+MS+sag(5) 8,296.82 69.86 258.87 5,145.97 5,089.77 -782.32 -5,262.63 6,030,290.40 464,555.95 1.36 4,642.29 MWD+IFR2+MS+sag(5) 8,392.12 69.57 258.47 5,179.00 5,122.80 -799.88 -5,350.28 6,030,273.19 464,468.24 0.50 4,718.00 MWD+IFR2+MS+sag(5) 8,438.00 69.60 258.48 5,195.01 5,138.81 -808.47 -5,392.41 6,030,264.77 464,426.07 0.07 4,754.33 MWD+IFR2+MS+sag(6) 8,529.05 72.36 255.25 5,224.69 5,168.49 -828.05 -5,476.21 6,030,245.54 464,342.20 4.52 4,825.73 MWD+IFR2+MS+sag(6) 8,575.56 73.36 254.40 5,238.39 5,182.19 -839.68 -5,519.11 6,030,234.08 464,299.27 2.77 4,861.70 MWD+IFR2+MS+sag(6) 8,670.27 74.48 252.70 5,264.63 5,208.43 -865.46 -5,606.38 6,030,208.67 464,211.90 2.09 4,934.14 MWD+IFR2+MS+sag(6) 8,718.63 74.39 251.47 5,277.60 5,221.40 -879.79 -5,650.71 6,030,194.52 464,167.52 2.46 4,970.50 MWD+IFR2+MS+sag(6) 8,785.71 74.04 252.09 5,295.85 5,239.65 -899.97 -5,712.02 6,030,174.59 464,106.13 1.03 5,020.66 MWD+IFR2+MS+sag(6) 8,881.94 73.38 251.52 5,322.84 5,266.64 -928.81 -5,799.77 6,030,146.10 464,018.28 0.89 5,092.45 MWD+IFR2+MS+sag(6) 8,977.86 73.11 252.53 5,350.50 5,294.30 -957.15 -5,887.13 6,030,118.12 463,930.81 1.05 5,164.07 MWD+IFR2+MS+sag(6) 9,072.22 72.75 254.47 5,378.20 5,322.00 -982.77 -5,973.61 6,030,092.85 463,844.23 2.00 5,235.83 MWD+IFR2+MS+sag(6) 9,168.00 72.53 256.55 5,406.78 5,350.58 -1,005.65 -6,062.12 6,030,070.34 463,755.64 2.09 5,310.45 MWD+IFR2+MS+sag(6) 9,262.77 72.47 260.99 5,435.29 5,379.09 -1,023.24 -6,150.74 6,030,053.11 463,666.95 4.47 5,387.06 MWD+IFR2+MS+sag(6) 9,357.47 72.46 264.53 5,463.83 5,407.63 -1,034.62 -6,240.31 6,030,042.09 463,577.35 3.56 5,466.75 MWD+IFR2+MS+sag(6) 9,452.53 71.85 267.34 5,492.97 5,436.77 -1,041.04 -6,330.55 6,030,036.04 463,487.09 2.89 5,548.84 MWD+IFR2+MS+sag(6) 9,547.64 72.27 271.43 5,522.27 5,466.07 -1,042.01 -6,421.01 6,030,035.44 463,396.64 4.11 5,633.07 MWD+IFR2+MS+sag(6) 9,642.41 72.06 275.01 5,551.31 5,495.11 -1,036.94 -6,511.07 6,030,040.87 463,306.61 3.60 5,719.06 MWD+IFR2+MS+sag(6) 9,737.67 71.99 278.14 5,580.71 5,524.51 -1,026.57 -6,601.07 6,030,051.61 463,216.66 3.13 5,806.88 MWD+IFR2+MS+sag(6) 9,833.18 71.37 281.53 5,610.74 5,554.54 -1,011.09 -6,690.39 6,030,067.45 463,127.42 3.43 5,895.88 MWD+IFR2+MS+sag(6) 9,929.57 71.41 286.08 5,641.51 5,585.31 -989.30 -6,779.07 6,030,089.60 463,038.83 4.47 5,986.53 MWD+IFR2+MS+sag(6) 10,024.64 71.38 289.64 5,671.85 5,615.65 -961.67 -6,864.82 6,030,117.57 462,953.21 3.55 6,076.49 MWD+IFR2+MS+sag(6) 10,118.68 72.08 292.42 5,701.34 5,645.14 -929.62 -6,948.16 6,030,149.95 462,870.01 2.90 6,165.78 MWD+IFR2+MS+sag(6) 10,214.27 72.08 296.36 5,730.76 5,674.56 -892.07 -7,030.97 6,030,187.83 462,787.35 3.92 6,256.53 MWD+IFR2+MS+sag(6) 10,309.31 71.94 299.25 5,760.12 5,703.92 -849.92 -7,110.92 6,030,230.31 462,707.59 2.90 6,346.24 MWD+IFR2+MS+sag(6) 10,404.13 72.22 300.94 5,789.30 5,733.10 -804.68 -7,188.97 6,030,275.86 462,629.73 1.72 6,435.27 MWD+IFR2+MS+sag(6) 11 10,498.75 73.56 303.93 5,817.14 5,760.94 -756.17 -7,265.28 6,030,324.67 462,553.62 3.34 6,523.82 MWD+IFR2+MS+sag(6) 1/31/2011 9:37:37AM Page 5 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+ 13.5(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 Database: .Pioneer 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 10,593.70 74.26 308.42 5,843.47 5,787.27 -702.34 -7,338.90 6,030,378.80 462,480.23 4.60 6,611.75 MWD+IFR2+MS+sag(6) 10,689.51 74.46 309.71 5,869.30 5,813.10 -644.19 -7,410.53 6,030,437.23 462,408.84 1.31 6,699.36 MWD+IFR2+MS+sag(6) 10,784.19 74.92 311.89 5,894.30 5,838.10 -584.53 -7,479.65 6,030,497.17 462,339.97 2.27 6,785.16 MWD+IFR2+MS+sag(6) 10,879.86 74.40 314.18 5,919.61 5,863.41 -521.57 -7,547.09 6,030,560.39 462,272.80 2.37 6,870.55 MWD+IFR2+MS+sag(6) 10,975.10 74.72 315.49 5,944.97 5,888.77 -456.84 -7,612.19 6,030,625.38 462,207.97 1.37 6,954.38 MWD+IFR2+MS+sag(6) 11,070.33 75.73 317.97 5,969.26 5,913.06 -389.80 -7,675.29 6,030,692.67 462,145.14 2.73 7,037.18 MWD+IFR2+MS+sag(6) 11,166.35 75.55 321.26 5,993.08 5,936.88 -318.96 -7,735.55 6,030,763.75 462,085.18 3.32 7,118.66 MWD+IFR2+MS+sag(6) 11,261.96 75.75 324.90 6,016.78 5,960.58 -244.92 -7,791.18 6,030,838.01 462,029.85 3.69 7,196.95 MWD+IFR2+MS+sag(6) 11,357.50 76.88 328.38 6,039.39 5,983.19 -167.40 -7,842.21 6,030,915.73 461,979.14 3.73 7,272.17 MWD+IFR2+MS+sag(6) 11,451.93 77.90 332.01 6,060.02 6,003.82 -87.45 -7,888.00 6,030,995.85 461,933.68 3.90 7,343.36 MWD+IFR2+MS+sag(6) 11,547.13 79.28 336.17 6,078.86 6,022.66 -3.53 -7,928.76 6,031,079.93 461,893.27 4.52 7,411.25 MWD+IFR2+MS+sag(6) 11,642.52 79.79 339.06 6,096.19 6,039.99 83.20 -7,964.48 6,031,166.79 461,857.91 3.03 7,475.42 MWD+IFR2+MS+sag(6) 11,736.96 79.85 338.89 6,112.88 6,056.68 169.96 -7,997.83 6,031,253.68 461,824.91 0.19 7,537.40 MWD+IFR2+MS+sag(6) 11,831.99 79.89 339.14 6,129.59 6,073.39 257.31 -8,031.33 6,031,341.15 461,791.77 0.26 7,599.72 MWD+IFR2+MS+sag(6) 11,927.00 79.58 341.03 6,146.52 6,090.32 345.20 -8,063.17 6,031,429.17 461,760.29 1.98 7,660.69 MWD+IFR2+MS+sag(6) 12,022.53 80.09 342.27 6,163.38 6,107.18 434.45 -8,092.78 6,031,518.52 461,731.05 1.38 7,720.04 MWD+IFR2+MS+sag(6) 12,067.94 80.08 343.26 6,171.20 6,115.00 477.17 -8,106.03 6,031,561.30 461,717.97 2.15 7,747.59 MWD+IFR2+MS+sag(6) 12,090.00 80.21 343.64 6,174.98 6,118.78 498.01 -8,112.22 6,031,582.15 461,711.87 1.81 7,760.78 MWD+IFR2+MS+sag(6) 12,122.46 80.82 341.19 6,180.33 6,124.13 528.52 -8,121.89 6,031,612.71 461,702.32 7.68 7,780.65 MWD+IFR2+MS+sag(7) 12,148.55 81.79 338.20 6,184.27 6,128.07 552.71 -8,130.84 6,031,636.92 461,693.47 11.92 7,797.60 MWD+IFR2+MS+sag(7) 12,196.49 83.40 336.52 6,190.45 6,134.25 596.58 -8,149.14 6,031,680.87 461,675.35 4.83 7,830.28 MWD+IFR2+MS+sag(7) 12,245.45 84.40 336.18 6,195.65 6,139.45 641.17 -8,168.67 6,031,725.53 461,656.00 2.16 7,864.37 MWD+IFR2+MS+sag(7) 12,289.71 84.07 336.40 6,200.10 6,143.90 681.49 -8,186.38 6,031,765.92 461,638.46 0.89 7,895.23 MWD+IFR2+MS+sag(7) 12,386.42 84.01 338.03 6,210.14 6,153.94 770.17 -8,223.63 6,031,854.74 461,601.58 1.68 7,961.53 MWD+IFR2+MS+sag(7) 12,483.58 83.89 342.52 6,220.39 6,164.19 861.10 -8,256.23 6,031,945.79 461,569.35 4.60 8,024.29 MWD+IFR2+MS+sag(7) 12,532.01 87.52 342.90 6,224.01 6,167.81 907.20 -8,270.58 6,031,991.95 461,555.19 7.54 8,054.07 MWD+IFR2+MS+sag(7) 12,579.25 88.92 342.40 6,225.48 6,169.28 952.27 -8,284.66 6,032,037.07 461,541.29 3.15 8,083.23 MWD+IFR2+MS+sag(7) 12,676.17 91.88 340.53 6,224.80 6,168.60 1,044.15 -8,315.46 6,032,129.06 461,510.86 3.61 8,144.63 MWD+IFR2+MS+sag(7) 12,771.79 93.54 338.11 6,220.28 6,164.08 1,133.49 -8,349.19 6,032,218.53 461,477.50 3.07 8,207.88 MWD+IFR2+MS+sag(7) 12,850.00 93.34 336.38 6,215.59 6,159.39 1,205.48 -8,379.38 6,032,290.64 461,447.60 2.22 8,261.66 MWD+IFR2+MS+sag(8) 12,867.91 92.47 337.25 6,214.68 6,158.48 1,221.93 -8,386.43 6,032,307.11 461,440.63 6.87 8,274.08 MWD+IFR2+MS+sag(8) 12,965.10 91.18 329.71 6,211.58 6,155.38 1,308.78 -8,429.77 6,032,394.13 461,397.64 7.87 8,345.43 MWD+IFR2+MS+sag(8) 13,061.01 90.94 326.12 6,209.81 6,153.61 1,390.01 -8,480.70 6,032,475.56 461,347.05 3.75 8,421.87 MWD+IFR2+MS+sag(8) 13,156.84 91.87 325.44 6,207.46 6,151.26 1,469.23 -8,534.57 6,032,554.98 461,293.50 1.20 8,500.36 MWD+IFR2+MS+sag(8) 13,250.00 89.65 323.82 6,206.22 6,150.02 1,545.18 -8,588.49 6,032,631.15 461,239.90 2.95 8,577.72 MWD+IFR2+MS+sag(9) 13,256.15 89.44 322.68 6,206.27 6,150.07 1,550.11 -8,592.17 6,032,636.09 461,236.24 18.85 8,582.91 MWD+IFR2+MS+sag(9) 13,350.96 87.11 323.73 6,209.12 6,152.92 1,625.99 -8,648.93 6,032,712.19 461,179.80 2.70 8,662.91 MWD+IFR2+MS+sag(9) 13,448.22 88.80 323.22 6,212.60 6,156.40 1,704.09 -8,706.77 6,032,790.52 461,122.28 1.81 8,744.71 MWD+IFR2+MS+sag(9) 13,544.65 85.56 323.73 6,217.34 6,161.14 1,781.48 -8,764.09 6,032,868.13 461,065.28 3.40 8,825.76 MWD+IFR2+MS+sag(9) 13,640.89 86.33 323.44 6,224.14 6,167.94 1,858.73 -8,821.08 6,032,945.61 461,008.61 0.85 8,906.46 MWD+IFR2+MS+sag(9) 1/31/2011 9:37:37AM Page 6 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 Database: .Pioneer 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) (°1100') (ft) Survey Tool Name 13,737.31 86.69 321.32 6,230.01 6,173.81 1,934.96 -8,879.82 6,033,022.07 460,950.18 2.23 8,988.43 MWD+IFR2+MS+sag(9) 13,833.69 90.05 320.88 6,232.76 6,176.56 2,009.93 -8,940.31 6,033,097.27 460,890.00 3.52 9,071.59 MWD+IFR2+MS+sag(9) 13,930.46 89.29 322.09 6,233.31 6,177.11 2,085.64 -9,000.57 6,033,173.22 460,830.06 1.48 9,154.80 MWD+IFR2+MS+sag(9) 14,026.99 90.03 322.46 6,233.89 6,177.69 2,161.99 -9,059.63 6,033,249.80 460,771.31 0.86 9,237.12 MWD+IFR2+MS+sag(9) 14,122.85 88.73 323.92 6,234.92 6,178.72 2,238.73 -9,117.06 6,033,326.76 460,714.20 2.04 9,318.05 MWD+IFR2+MS+sag(9) 14,218.75 89.04 322.55 6,236.79 6,180.59 2,315.54 -9,174.45 6,033,403.80 460,657.13 1.46 9,398.96 MWD+IFR2+MS+sag(9) 14,315.40 87.99 319.97 6,239.29 6,183.09 2,390.89 -9,234.90 6,033,479.39 460,596.99 2.88 9,482.23 MWD+IFR2+MS+sag(9) 14,411.26 90.35 321.18 6,240.68 6,184.48 2,464.92 -9,295.77 6,033,553.66 460,536.43 2.77 9,565.41 MWD+IFR2+MS+sag(9) 14,508.52 90.77 319.56 6,239.73 6,183.53 2,539.83 -9,357.80 6,033,628.81 460,474.71 1.72 9,649.98 MWD+IFR2+MS+sag(9) 14,605.16 90.15 315.20 6,238.96 6,182.76 2,610.92 -9,423.22 6,033,700.16 460,409.59 4.56 9,736.38 MWD+IFR2+MS+sag(9) 14,701.30 92.33 310.59 6,236.87 6,180.67 2,676.32 -9,493.61 6,033,765.84 460,339.47 5.30 9,825.40 MWD+IFR2+MS+sag(9) 14,796.99 88.40 308.16 6,236.26 6,180.06 2,737.01 -9,567.56 6,033,826.82 460,265.78 4.83 9,916.08 MWD+IFR2+MS+sag(9) 14,894.10 86.81 306.14 6,240.32 6,184.12 2,795.60 -9,644.89 6,033,885.72 460,188.70 2.65 10,009.16 MWD+IFR2+MS+sag(9) 14,990.37 88.93 305.66 6,243.90 6,187.70 2,852.01 -9,722.81 6,033,942.43 460,111.01 2.26 10,102.04 MWD+IFR2+MS+sag(9) 15,086.83 91.28 305.32 6,243.72 6,187.52 2,908.00 -9,801.34 6,033,998.74 460,032.71 2.46 10,195.33 MWD+IFR2+MS+sag(9) 15,184.57 91.27 302.39 6,241.55 6,185.35 2,962.43 -9,882.48 6,034,053.50 459,951.80 3.00 10,290.51 MWD+IFR2+MS+sag(9) 15,281.09 87.66 298.31 6,242.45 6,186.25 3,011.18 -9,965.74 6,034,102.58 459,868.75 5.64 10,385.65 MWD+IFR2+MS+sag(9) 15,377.11 88.49 301.47 6,245.68 6,189.48 3,059.00 -10,048.93 6,034,150.73 459,785.77 3.40 10,480.39 MWD+IFR2+MS+sag(9) 15,473.69 86.31 301.13 6,250.06 6,193.86 3,109.12 -10,131.36 6,034,201.18 459,703.54 2.28 10,575.25 MWD+IFR2+MS+sag(9) 15,570.81 89.74 305.23 6,253.41 6,197.21 3,162.22 -10,212.57 6,034,254.61 459,622.56 5.50 10,670.01 MWD+IFR2+MS+sag(9) 15,666.83 94.08 309.64 6,250.20 6,194.00 3,220.53 -10,288.74 6,034,313.21 459,546.64 6.44 10,761.92 MWD+IFR2+MS+sag(9) 15,763.17 91.99 307.54 6,245.10 6,188.90 3,280.53 -10,363.93 6,034,373.51 459,471.70 3.07 10,853.51 MWD+IFR2+MS+sag(9) 15,859.61 94.19 307.64 6,239.91 6,183.71 3,339.27 -10,440.23 6,034,432.55 459,395.65 2.28 10,945.69 MWD+IFR2+MS+sag(9) 15,955.19 92.62 307.55 6,234.23 6,178.03 3,397.47 -10,515.82 6,034,491.06 459,320.30 1.65 11,037.02 MWD+IFR2+MS+sag(9) 16,051.26 91.38 306.13 6,230.88 6,174.68 3,455.04 -10,592.66 6,034,548.93 459,243.70 1.96 11,129.29 MWD+IFR2+MS+sag(9) 16,148.23 90.46 306.50 6,229.32 6,173.12 3,512.46 -10,670.79 6,034,606.66 459,165.82 1.02 11,222.71 MWO+IFR2+MS+sag(9) 16,244.54 88.91 306.71 6,229.85 6,173.65 3,569.88 -10,748.10 6,034,664.39 459,088.75 1.62 11,315.37 MWD+IFR2+MS+sag(9) 16,340.48 88.98 307.43 6,231.61 6,175.41 3,627.70 -10,824.63 6,034,722.52 459,012.46 0.75 11,407.44 MWD+IFR2+MS+sag(9) 16,437.36 89.48 307.73 6,232.92 6,176.72 3,686.78 -10,901.40 6,034,781.90 458,935.93 0.60 11,500.19 MWD+IFR2+MS+sag(9) 16,534.58 90.16 307.48 6,233.22 6,177.02 3,746.11 -10,978.42 6,034,841.53 458,859.16 0.75 11,593.25 MWD+IFR2+MS+sag(9) 16,630.89 92.33 310.64 6,231.13 6,174.93 3,806.77 -11,053.18 6,034,902.49 458,784.66 3.98 11,684.67 MWD+IFR2+MS+sag(9) 16,689.00 92.33 310.64 6,228.77 6,172.57 3,844.58 -11,097.23 6,034,940.48 458,740.76 0.00 11,739.28 PROJECTED to TD 1/31/2011 9:37:37AM Page 7 COMPASS 2003.16 Build 42F SME [1 [F /1-- LASEA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Brandon Peltier Drilling Engineer Pioneer Natural Resources Alaska, Inc. 1 �f,1 700 G Street, Suite 600 r� b O Anchorage, AK 99501 v� Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-18 Sundry Number: 312-186 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, Cathy P oe ter Chair DATED G-- DATED this 4'1 day of May, 2012. Encl. R , •04' AvRECEIVED STATE OF ALASKA .1 5'�� ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 1 8,5Z12 APPLICATION FOR %SUNDRY APPROVALS r� `� �z 1 1( 2 20 MC 25.280 AOGCC 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing Q Time Ep ❑ Extension Operations Shutdown❑ Re-enter Susp.Well 111 Stimulate 111 Alter Casing 111 Other: Change Tubing/�nh ESP 0 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Pioneer Natural Resourcs Alaska, Inc. Development 0 . Exploratory ❑ 210-142 3.Address: 700 G Street,Suite 600 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99501 50-703-20624-00-00 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 ❑� ODSN-18• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036/ADL 355037 Oooguruk-Nuiqsut 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): 16,689' 6229' 16,399' 6232' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3557' 11-3/4" 3600' 3309' 5830 psi 3180 psi Drilling Liner 5504' 9-5/8" 3320'-8824' 3124'-5329' 5750 psi 3090 psi Tie-back 8270' 7" 8308' 5149' 7240 psi 5410 psi Intermediate 3801' 7" 8289'-12,090' 5143'-6175' 7240 psi 5410 psi Production Liner 4485' 4-1/2" 11,915'-16,400' 6144'-6232' 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 2-7/8",6.5# L-80, IBT-M 10,986' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): See Attachment, pg.3 See Attachment, pg.3 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑., Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 7/15/2012 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, 343-2116 Title Drilling Engineer Signat a Phone ((�� Date 5/16/2012 Prepared By:Kathy Campoamor,343-2183 .3-! 3 21ICo COMMISSION USE ONLY 1 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �zJ I Z'' I?tP Plug Integrity ❑ BOP Test 27 Mechanical Integrity Test II ❑ Location Clearance Other: 1- 3500 paw OOP ;--S Subsequent Form Required: /O—i/ APPROVED BY Approved by: r// •, COMMISSIONER THE COMMISSION Date: s, 2,4 _1 Z_ Form 10 403 'evised 1/2010 24 S•LZ•/L OR I G I N DMS MAY 24 2012, �"; mit in up ate z- I ' Pioneer Natural kesources Alaska Inc. ODSN-18 Page 2 Form 10-403, Application For Sundry Approvals Present Well Condition - Box #11 Perforation Depth Attachment 24. Open to production or injection 4-1/2", 12.6#, L-80 Hyd 521 Uncemented Liner Perforated Pups w/ 6-1/2" Holes @ depths listed: MD TVD 12,302' - 12,306' 6201' - 6202' 12,506' - 12,511' 6222' - 6222' 12,628' - 12,632' 6225' - 6225' 13,005' - 13,009' 6211' - 6211' 13,168' - 13,173' 6207' - 6207' 13,535' - 13,540' 6217' - 6217' 13,734' - 13,739' 6230' - 6230' 13,934' - 13,939' 6233' - 6233' 14,138' - 14,143' 6235' - 6235' 14,300' - 14,304' 6239' - 6239' 14,463' - 14,468' 6242' - 6242' 14,840' - 14,844' 6238' - 6238' 15,043' - 15,048' 6244' - 6244' 15,247' - 15,252' 6242' - 6242' 15,448' - 15,453' 6249' - 6249' 15,648' - 15,653' 6251' - 6251' 15,867' - 15,872' 6239' - 6239' 16,029' - 16,034' 6232' - 6231' 16,234' - 16,239' 6230' - 6230' Pioneer Natural Resources Alaska Inc. ODSN-18 Page 3 AOGCC Form 10-403, Application For Sundry Approvals Present Well Condition Summary Attachment, Box #11 Packers and SSSV (type, measured and true vertical depth) sssV TRMAXXX-5E SSSV 2068' MD /2043' TVD Packers Hydro II Packer w/ Gas Vent Valve 2570' MD / 2522' TVD 7" x 9-5/8" Liner Top Packer 8309' MD / 5150' TVD Arrow Pak Retrievable Packer 11,872' MD / 6137' TVD • 4-1/2" x 7" Liner Top Packer 11,931' MD / 6147' TVD ODSN-18 Proposed Rig Work-over Summary Well Background and Operational Summary: ODSN-18 was drilled and completed in January 2011. The lateral was fracture stimulated in• February and a flow-back followed. Post flow-back, coil tubing conducted a partial lateral clean- out. After the coil tubing clean-out, the drilling rig moved onto the well to finish the lateral clean- out and to recomplete to an ESP completion. However, lost circulation hampered the rig's attempt at a lateral clean-out and only a partial clean-out was made. The rig installed a formation saver valve (FSV) above the 4.5" liner top and then ran an ESP completion on 2-7/8" tubing. The ESP was started a day after the rig moved off and immediately failed. The ESP failure mode indicates solids plugging, but electrical continuity to the motor may also be compromised. - The well was placed on gas lift after the ESP failed and has remained on gas lift to date. • The scope of this work-over covers the following: • Pull the existing ESP completion • Pull the formation saver valve and clean-out to the 7"x4-1/2" liner top . • Install 3-1/2" tubing Well Information: o Estimated Shut-in BHP: 2200psi (6.8ppg EMW @ 6232' TVD) o MASP (based on 0.1 psi/ft gradient): 1577psi o Estimated BHT: 155 F Pre Rig: 1. Perform pre-rig check-list tasks (grease valves and test voids). 2. Shut off gas lift support approximately 1 week prior to MIRU of Nabors 19AC. 3. Add a second swab valve for e-line and slick-line work. o Set and pull BPV as needed for this work 4. Fluid pack IA and tubing with kill weight fluid (expecting to use 8.6 Seawater) o Open PW and vent gas from below packer into IA. Bleed IA and tubing as necessary. o Note: bull-heading is not an option due to the Formation Saver Valve (FSV) o Contingency option: RU E/L and tube punch 10' of the 3.5", 9.3#tubing using 4 SPF tubing punches just below the production packer at 2570' MDrkb. 5. Verify ScSSSV actuation, close and verify, monitor control line pressure. PT ScSSSV from below to 500 psi. 6. Rig up slick-line to pull the LGLV from the GLM at 2463'. 7. Freeze protect TxIA to 2000' with diesel. 8. MIT-TxIA to 2000 psi 9. Monitor WHP and IAP via operator's daily reading schedule until rig moves on location, Prep surface equipment for rig move. Page 1 of 3 PIONEER NATURAL RESOURCES ALASKA Nabors 19AC Rig Operation: 1. MIRU Nabors 19AC. 2. Ensure that the ScSSSV is open. 3. Monitor TxIAxOA pressures, ensure static conditions 4. Install a BPV into the tubing hanger profile. 5. ND swab valves and NU BOP a. Barriers are (a minimum of 2): i. Tubing side 1. BPV in the tubing hanger 2. Close the ScSSSV ii. Annulus 1. 2 independent seals in the tubing hanger (tested during MITIA and pre-rig) 6. 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. 7. Pull BPV from tubing hanger. a. If trapped pressure is observed below BPV, circulate KWF 2x tubing volume down tubing 8. Pull the tubing hanger and then pull to release the 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 the tubing above the packer, pull the tubing, and then spear and pull the packer with 4" drill pipe. c. Circulate out diesel freeze protect after releasing packer. 9. Pull 2-7/8" completion string out of the hole filling hole as needed. t �P) a. Joint with FOSV should be in the mouse hole as a contingency. 10. PU 4" DP as needed for clean-out runs. 11. Make clean-out run down to FSV 12. MU FSV Arrow Packer retrieval tool, RIH on 4" DP and retrieve FSV. 13. Make clean-out run to top of 4.5" liner with polish mills. Circulate the well clean as needed. 14. PU & RIH 3.5", 9.3 ppf, L-80, TC-Il tubing consisting of: a. Seal Assembly with mule-shoe and locator b. X nipple c. (3) GLM per gas lift design d. TRSSV 15. Space out tubing and then land Tubing Hanger. RILDS for Tubing Hanger. Asr. a. After landing, test both the upper and lower Tubing Hanger body seals to 5000psi. 16. Test the IA to 2000 psi 17. Install BPV with blanking plug and test from above 18. ND BOPE a. Barriers are: iii. Tubing side 1. BPV in the tubing hanger Page 2 of 3 PIONEER NATURAL RESOURCES ALASKA 2. Closed ScSSSV and KWF iv. Annulus 1. Wellhead and tubing hanger with 2 independent seals 19. NU Vetco Swab valve and cap a. Test tree to 5000 psi. Post Rig: 1. Pull BPV w/ blanking plug. 2. MIRU HES Slick-line a. Pull dummy valve from upper GLM b. Freeze protect TxIA c. Install gas lift valves per completion design 3. Conduct coil tubing lateral clean-out as needed. Page 3 of 3 PIONEER NATURAL RESOURCES ALASKA PIONEERCurrent Schematic -State Well Name: ODSN-18/ODSN-18L1 I : kL RESOURCES HORIZONTAL-Sidetrack 5,6/2/2011 4:38:19 PM Well Attributes Vertical schematic(actual) API/U WI Field Name Well Status Total Depth(ftKB) 50-703-20624-00-00 000GURUK DRILLED 16,689.0 13-21—•. Casing Strings Conductor,158.OftKB C Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connedion Wt/Len(b/ft) Conductor 16 14.670 47.7 158.0 158.0 H40 Welded 109.00 Casing Components J p1-1l Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Com 1-1 Casing Joints 47.7 47.7 16 14.670 ® Surface,3,600.0ftKB 555 Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connedion Wt/Len(b/ft) 13-7 = e Surface 11 3/4 10.772 38.6 3,600.0 3,309.3 L-80 HYD 521 60.00 Ili Casing Components 13-111 I Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Com 3-15 2-5 Tam-Port Collar 537.1' 537.0 11 3/4' 10.772 m 2-10 Surface Shoe 3,598.2 3,308.2 11 3/4 10.772 13-19 - 7"Tie Back,8,307.9ftKB Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connedion Wt/Len(b/ft) 1 I 7"Tie Back 7 6.276 37.8 8,307.9 L-80 Buttress 26.00 2-10 Thread 13-231 mu Casing Components 3 9 Top(TVD) Item#_ Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 3-12 3-9 Weatherford SHR Hold 8,281.8' 7 6.276 012 /6-1 Down Sub 66=3 3-12 7"PBR Tie Back Seals 8,288.6 7.49 6.250 f" 1 6-4 9-5/8"Drilling Liner,8,824.0ftKB Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept.., Grade Top Connedion Wt/Len(b/ft) 13-271 4 9-5/8"Drilling 9 5/8 8.835 3,319.7 8,824.0 5,329.1 L-80 HYD 521 40.00 MI Liner 13-31 - 7"Stuck Liner#1,11,202.0ftKB 3-35Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connedion Wt/Len(b/ft) 3-371 #1 Stuck Liner 7 6.276 8,475.3 11,202.0 6,048.7 L-80 HYD 511 26.00 329 2-1 Casing Components 2 33Top(TVD) \ Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 2-4 5-12 7"Liner Shoe 11,200.0 6,048.2 7 6.276 27 . -� 7"Drilling Liner,12,090.OftKB Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connedion Wt/Len(b/ft)' 12 10 A /7-11 7"Drilling Liner 7 6.276 8,288.6 12,090.0 6,174.6 L-80 Buttress 26.00 -7 2 Thread 7-4 Casing Components Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn a .6-11 6-1 WTF PBR Tie Back Sleeve 8,288.6 8 1/4 7.500 MI -7-7 —, -77=9 6-3 WTF 7"x 9 5/8"TSP5H1 8,309.5 7 6.276 iMlb—7-111 Liner Top Packer 7-14 6-4 WTF 7"x 9 5/8"PHR Rot. 8,315.3 7 6.276 /7-17 Liner Hanger MID p 7-19 6-1 1 7"Liner Shoe 12,087.9 6,174.2 7 7-21 Lower Lateral 4 1/2"Production Liner,16,400.0ftKB imp ""�723 Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connedion Wt/Len(b/ft) IMP Lower Lateral 4 1/2 3.958 11,915.5 16,400.0 6,232.5 L-80 Hydril 521 12.60 13111* 7-25 4 1/2" 121113, ,7-27 Production BID 7-29 Liner ®.---7-31 Casing Components 17-341 Item# Item Des Top(ftKB) ToD) (ftKB) OD(in) ID(in) Corn 'g- ® 7-1 Tie Back Sleeve 11,915.5 6 ,-�739 -iii TIEIEI ® "i . iCil . 7-48 r-1111110® _Jr1111:,=® Page 1/3 Report Printed: 6/2/2011 PIONEERCurrent Schematic -State Well Name: ODSN-18/ODSN-18L1 NATURAL RESOURCES HORIZONTAL-Sidetrack 5,6/2/2011 4:38:36 PM Casing Components Vertical schematic(actual) Top(ND) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 13-2 a 7-2 NTH Packer 11,930.9 6.276 3.958 ] i', 7-4 PHR Hanger 11,934.2 6.276 3.958 1 7-7 Ported Sub 12,301.6 4 1/2 3.958 7-9 Ported Sub 12,506.1 4 1/2 3.958 7-11 Ported Sub 12,627.8 4 1/2 3.958 J k1-1 I7-14 Resman Tracer Sub#3 12,795.4 4 1/2 3.958 Mil 7-17 Ported Sub 13,004.7 4 1/2 3.958 7-19 Ported Sub 13,168.2 6,207.1 4 1/2 3.958 I3-71 7-21 Ported Sub 13,535.2 6,216.7 4 1/2 3.958 7-23 Ported Sub 13,734.4 6,229.9 4 1/2 3.958 13-111 s -e 7-25 Ported Sub 13,934.1 6,233.4 4 1/2 3.958 EA 7-27 Ported Sub 14,138.0 6,235.3 4 1/2 3.958 3-151--CEI C 7-29 Ported Sub 14,299.6 6,238.8 4 1/2 3.958 13-19 =. _. 7-31 Ported Sub 14,463.1 6,240.3 4 1/2 3.958 7-34 Resman Tracer Sub#2 14,708.7 6,236.6 4 1/2 3.958 I 7-37 Ported Sub 14,839.7 6,237.7 4 1/2 3.958 2-10 7-39 Ported Sub 15,043.1 6,244.3 4 1/2 3.958 I3-231 4 7-41 Ported Sub 15,247.2 6,241.5 4 1/2 3.958 LJ r3-91 7-43 Ported Sub 15,448.2 6,248.6 4 1/2 3.958 / 3-121 6-1 7-45 Ported Sub 15,648.4 6,251.4 4 1/2 3.958 6_3 7-48 Resman Tracer Sub#1 15,814.7 6,242.8 4 1/2 3.958 1 ! 6-4 7-51 Ported Sub 15,867.2 6,239.4 4 1/2 3.958 r 7-53 Ported Sub 16,029.0 6,231.5 4 1/2 3.958 13-271 4 E 7-55 Ported Sub 16,234.4 6,229.7 4 1/2 3.958 CA 7-57 Eccentric Shoe 16,398.7 6,232.5 4 1/2 3.958 13-311--f r Tubing Strings 3-35 Tubing Description String M... ID(in) Top(ftKB) Set Depth(f...Set Dept...Wt(Ib/ft) Grade Top Thread 3-37� WFT Formation Saver 5.645 2.992 11,871.6 11,918.0 3-1/2" 3-39\ 4 I Valve Assy EUE 2-1\ Tubing Components 2-3\ Item# Item Des To fEB Top(TVD) 2 44 ■sT��� p( ) (ftKB) OD(in) ID(in) Corn 2-1 WFT Arrow Pak Ret. 11,871.6 5.945 3.500 Packer 2 8--+c' 2-3 Tubing Dump Valve 11,881.0 4 1/2 3.000 2-10 X7_1 7.2 2-4 Formation Saver Valve 11,881.8 5.645 2.992 7-4 2-8 No Go Sub/Crossover 11,910.1 5.8 3.000 2-10 Ratcheting Muleshoe 11,915.7 5.2 3.937 Tubing Description String M... ID(in) Top(ftKB) Set Depth(f...Set Dept...Wt(lb/ft) Grade Top Thread I .6-111 ESP Completion 2 7/8 2.441 0.2 10,986.0 6.50 L-80 IBT-M 1110) -7-7 Tubing Components TopD) -7 9 Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Com 7-111 3-2 Vetco Gray Tubing hanger 34.5 10 4.250 . , -7-14 13/16 MEP /7-19 7-17 3-7 TRMAXX-5E SSSV 2,068.3 4 3/4 2.312 IMPp 7-19 3-11 GLM#3 w/1.5"DCR 2,463.7 5 1/2 2.365 1.5"DCR Shear Valve ,,a 7-21 Shear Valve Replaced with LGLV ® i 7-23 3-15 "X"Nipple#2 2,516.2 3.53 2.313 riallb .7-25 3-19 WFT Hydrow II Packer w/ 2,570.2 6.002 2.359 7-27 Gas Vent Valve MI -7-29 7-31 3-23 GLM#2-1 1/2"w/DV 4,919.1 5 1/2 2.365 LGLV installed mop- installed • 7-341 3-27 GLM#1 -1 1/2"w/DV 8,383.7 5 1/2 2.365 0.25"OV installed I ;;,,;,ill ® installed MEI 7 39 3-31 "X"Nipple#1 w/RHC-M 8,467.2 3.53 2.313 ,- ® ta:' MD _7-45 7-48 Imo® Page 2/3 Report Printed: 6/2/2011 PIONEERCurrent Schematic - State Well Name: ODSN-18/ODSN-18L1 NATURAL RESOURCES HORIZONTAL-Sidetrack 5,6/2/2011 4:38:49 PM Tubing Components Vertical schematic actual Top)TVD) ( ) Item# Item Des Top(itl(B) (ftKB) OD(in) ID(in) Corn 13-21 •� 1.13-35 Auto Diverter Valve 10,903.6 4 1/2 0.000 1 Li c d 3-37 Discharge Gauge 10,909.6 4 1/2 0.000 3-39 Baker ESP-Pump/Motor 10,914.9 5 0.000 assembly(P11 207 stage) i J k i-1 Elii 13-7 • a • 13-111 z= a III 13-151 13-19 1.11 I 2-10 3-23 3-9 r / 3-121 il 1� ' 327 INa • 13-31 is ■ 3-35 1 3-37\ W 33-39mi 21V 2-3\ 7 2-4 T8--- FL-- 12-10 -7=1 7-2 ..wrtr 7-4 1 di .6 11 ® -7-7 ® -7-9 Ku"—7-11 -7-14 77-17 IMP 7-19 map oaf 7-21 7-23 IMP Bab .7-25 ' -7-27 ® -7-29 tom—7-31 • 17-341 miol,iii Mil a=117 39 a=17131 r _7-43 MEI . 7-48 la lgal ilo® MU Page 3/3 Report Printed: 6/2/2011 ODSN 3 RWO Completion - . 3posed Well Head: 9-5/8",5K,VetcoGray Tree: 4-1/2",5K, Horizontal Casing I Item# Item MD(ft) TVD(ft) OA 16"Conductor 158 158 B 11-3/4"60#L-80 Hydril 521, 10.772"ID 3,600 3,309 O ' ` C 9-5/8"40#L-80 Hydril 521,8.835"ID* 8,824 5,329 D 7"26#L-80 BTC-M,6.276"ID,Tieback 8,308 5,150 -ii" -iiE 7"26#L-80 Hydril 511,6.276"ID** 12,090 6,175 OF 4-1/2"12.6#Hydril 521 3.958"ID 16,679 6,229 2 G 3-1/2"9.3#IBT-M 11,940 6,206 *Planned TOC @ 7764'MD **Planned TOC @ 10,603'MD D Upper Completion Item# Item MDrkb(ft) TVDrkb(ft) 1 VetcoGray Tubing Hanger 34 34 2 3-1/2"ScSSSV @ 2000'MD/2000'TVD 2,024 2,000 3 GLM#1 tbd 4 GLM#2 tbd O 5 GLM#3 tbd O J 6 3-1/2"X Nipple tbd 7 3-1/2"Seal Assembly w/Muleshoe 11,925 6,277 End of Assembly 11,940 6,281 Ail 9 WFT PBR Tie Back Sleeve 15ft 11,925 6,277 10 WFT"NTH"Liner Top Pkr 11,940 6,281 11 WFT"PHR"Rotating Hyd Set Liner Hanger 11,942 6,281 O 12 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,300 6,201 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,500 6,222 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,650 6,225 13a Resman Tracer Pup 12,800 6,219 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,000 6,211 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,150 6,208 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,550 6,218 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,750 6,231 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,950 6,234 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,150 6,236 OJ 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,300 6,239 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,450 6,240 13b Resman Tracer Pup 14,700 6,237 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,850 6,238 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,050 6,244 IO• 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,250 6,242 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,450 6,240 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,650 6,251 13c Resman Tracer Pup 15,800 6,244 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,850 6,241 4-1/2"12.60#L-80 Hydril Pupjt Oft(Ported w/6 1/2 holes) 16,050 6,231 4-1/2"12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,250 6,230 14 Float Shoe(PLUGGED) 16,400 6,233 End of Assembly 16,402 6,233 10 © TD 16,689 6,229 11 O 12 00 . „ 00 . � 00 c � 00 00 O 00 y ` 00 N � 00 Na, 00 00 13 00 ce 00 ce 00 ce 00 00 . 16689'MDrkb/6229'TVDrkb Date: Revision By: Comments PIONEER 4/23/13 BJP RWO Proposed Completion ODSN-18 RWO Completion - NATURAL RESOURCES AIASKA Well Schematic , STATE OF ALASKA RECEIVED ALASKA AND GAS CONSERVATION COMMISSIC SUN 1 0 2.011 REPORT OF SUNDRY WELL OPERATIONS rj 1.Operations Abandon ❑ Repair Well Q Plug Perforations ❑ Stimulate ❑ V"am't} i r *�`han a ub�in u�E'SFr" Performed: Alter Casing ❑ Pull Tubing0 Perforate New Pool ❑ Waiver ❑ Time Extension[ t7nP.-!'tgie Change Approved Program ❑ Operat.Shutdown❑ Perforate ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Pioneer Natural Resources Alaska Inc Name: Development ❑v Exploratory ❑ ' 210-142 3.Address: 700 G Street,Suite 600 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99501 50-703-20624-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 355036/ADL 355037 ^'ODSN-18 1 9.Field/Pool(s): f, Oooguruk-Nuiqsut Oil Pool 10.Present Well Condition Summary: Total Depth measured 16,689 feet Plugs measured N/A feet true vertical 6229 feet Junk measured N/A feet Effective Depth measured 16,399 feet Packer measured See Attachment,pg 3 feet true vertical 6232 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3557' 11-3/4" 3600' 3309' 5830 psi 3180 psi Drilling Liner 5504 9-5/8" 3320'-8824' 3124'-5329' 5750 psi 3090 psi Tie back 8270' 7" 8308' 5149' 7240 psi 5410 psi Intermediate 3801' 7" 8289'-12,090' 5143'-6175' 7240 psi 5410 psi Liner 4485' 4-1/2" 11,915'-16,400' 6144'-6232' 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) 2-7/8",6.5# L-80, IBT-M 10,986'MD 5948'TVD Packers and SSSV(type,measured and true vertical depth) See Attachment,pg 3 11.Stimulation or cement squeeze summary: RECE" c Intervals treated(measured): - JUN 14 Treatment descriptions including volumes used and final pressure: AAA) 12. Representative Daily Average Productio or Injection Data ` "�+ t Oil-Bbl Gas-Mcf Water-Bbl c Casing Pressure Tubing Pressure Prior to well operation: 187 36 0 767 149 Subsequent to operation: 162 49 247 938 271 13.Attachments: 14.Well Class after work: ,, Copies of Logs and Surveys Run Exploratory❑ Development❑� Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15.Well Status after work: -r Oil Q Gas ❑ WDSPL❑ GSTOR El WINJ ❑ WAG ❑ GINJ ❑ SUSP El SPLUG El 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: 311-092 Contact Tim Crumrine,343-2184 Prepared By:Kathy Campoamor,343-2183 Printed Name Tim Crumrine Title Completions Engineer Signature a %j au�i �.% ic (l/12 (1—uini,//,.& Phone 343-2184 Date 6/10/2011 RBDMS MAY 13 2011 J �"I 5� G.z,"."Form 10-404 Revised 10/2010Submit Original Only Pioneer Natural Resources Alaska Inc. ODSN-18 Page 2 AOGCC Form 10-404, Report of Sundry Well Operations Present Well Condition - Box #10 Perforation Depth attachment 10. Open to production or injection 4-1/2", 12.6#, L-80 Hyd 521 Uncemented Liner III'I Perforated Pups w/ 6-1/2„ Holes @ depths listed: MD TVD 12,302' - 12,306' 6201' - 6202' 12,506' - 12,511' 6222' - 6222' 12,628' - 12,632' 6225' - 6225' 13,005' - 13,009' 6211' - 6211' 13,168' - 13,173' 6207' - 6207' 13,535' - 13,540' 6217' - 6217' 13,734' - 13,739' 6230' - 6230' 13,934' - 13,939' 6233' - 6233' 14,138' - 14,143' 6235' - 6235' 14,300' - 14,304' 6239' - 6239' 14,463' - 14,468' 6242' - 6242' 14,840' - 14,844' 6238' - 6238' 15,043' - 15,048' 6244' - 6244' 15,247' - 15,252' 6242' - 6242' 15,448' - 15,453' 6249' - 6249' 15,648' - 15,653' 6251' - 6251' 15,867' - 15,872' 6239' - 6239' 16,029' - 16,034' 6232' - 6231' 16,234' - 16,239' 6230' - 6230' Pioneer Naturae Resources Alaska Inc. ODSN-18 Page 3 AOGCC Form 10-404, Report of Sundry Well Operations Present Well Condition Summary, Box #10 Present Well Condition Summary attachment: Packers and SSSV (type, measured and true vertical depth) sssV TRMAXXX-5E SSSV 2068' MD /2043' TVD Packers Hydro II Packer w/ Gas Vent Valve 2570' MD / 2522' TVD 7" x 9-5/8" Liner Top Packer 8309' MD / 5150' TVD Arrow Pak Retrievable Packer 11,912' MD / 6144' TVD 4-1/2" x 7" Liner Top Packer 11,931' MD / 6147' TVD Or •ations Summary Report - State `Nell Name: ODSN-18/ODSN-18L1 P I 0 N E E R NATURAI RFSOURCFS Well Name: Contractor: Rig Number: Job Category: Start Date: End Date: Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 4/28/2011 4/29/2011 0.0 Lay down 4"DP from derrick. Prep for rig move and move Nabors 19AC from south well row to north well row to ODSN-18. NOTE:RIG ACCEPTED AT 00:00 HRS ON 4-28-11 4/29/2011 4/30/2011 0.0 Moving Nabors 19AC from south well row around the corner to the north well row to ODSN-18. 4/30/2011 5/1/2011 0.0 10.20 Spot rig,and pits on ODSN-18,level same,and RU same.RU circulation manifold while taking on 10.2 ppg brine to rig pits.Pump 157 bbls down IA--SITP=500 psi.Bleed tubing down to 200 psi-Well was U-Tubing to Flow Back Tank. Pump 131 bbls down IA-93 bbls returned to flow back tanks-Return flow out tubing stopped.Monitor well for 15 minutes-static. Lubricate 50 bbls 10.2 ppg brine into tubing-open up to flow back tank to bleed back-tubing static. Install BPV in tubing hanger and ND production tree.NU BOP and drilling riser. RU test equip-PU 4.5" test joint,and test BOPE w/4.5"test joint to 250 psi low and 3500 psi high.Test upper and lower n IBOP valves to 250 psi low,3500 psi high.Test upper variable rams w/4.5"test jt.to 250 low, YO 3500 high-#1 choke vavle would not test.Trouble shoot#1 choke vavle and grease same.Test #1 choke valve-good test. Right to witness waived by AOGCC Rep.Chuck Scheve at 15:00 hrs on 4/30/2011. 5/1/2011 5/2/2011 0.0 10.20 Test BOPE w/4.5"test joint to 250 psi low and 3500 psi high.Test BOPE W/2-7/8"test joint to 250 psi low and 3500 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 3500 psi high.Test upper and lower IBOP valves to 250 psi low,3500 psi high.Test 14 choke man.valves to 250 psi low,3500 high. Initial sys.pressure =3000 psi.After closure=2100.200 psi obtained in 22 seconds.Full pr ssur-in 86 ec All tests charted and all tests held for 5 min.Right to witness waived by AOGCC Rep.Chuck Scheve at 15:00 hrs on 4/30/2011. RD testing equipment and pull BPV from tubing hanger- tubing on a vacuum.Fill tubing with 30 bbls 10.2 ppg birne. Tubing on a vacuum,IA=50 psi. Close annular and unseat tubing hanger.Bleed off IA thru choke and gas buster. Pump 20 bbls 10.2 ppg brine down IA-went on vacuum.Open annular-well static,and pull hanger to rig floor. Cut penetrations from hanger and splice control line and Tec wire.LD landing joint and tubing hanger.POOH laving down 4.5"frac string f/11,881't/9.913'.Install floor safety valve and pump 30 bbls 10.2 ppg brine down tubing.Break out top drive and seen gas bubbling to surface-close safety vavle.RU lines to reverse circulate and take returns to the flow back tanks.Close Annular and reverse circulate through kill line while taking returns to flow back tanks.Reverse 213 bbls of 10.2 brine into IA taking 127 bbls to flow back tank.Shut down pumps and monitor well for 30 min-static. RD reverse circulating lines.POOOH laying down 4.5"frac string(/9,913'1/6,785'. 5/2/2011 5/3/2011 0.0 10.20 POOH laying down 4.5"frac string f/6,785'U4,178'. RU slick line unit and lubricator. Fish for IBP stiffening ring. Run 1-RIH with rope spear to 4,100'wlm-no fish. Run 2-RIH with 3 prong wire grab to 4,125'wlm-no fish. RD slick line unit and lubricator.POOH laying down 4.5"frac string f14,178'U surface.RD tubing equipment,and RU 4"DP handling equipment. Install wear bushing.TIH picking up 60 joints 4"DP from pipe shed f/surface 1/1,925'. POOH racking back 20 stands of 4"DP in derrick f/1,925'U surface. Prep rig floor while verifying OD's, ID's,and lengths on BHA tools. 5/3/2011 5/4/2011 0.0 10.20 TIH picking up BHI Vax tool BHA with casing scraper I magnet assembly f/surface 1/135'.TIH picking up 4"DP from pipe shed f/135'1/4,433'-tagged up with 25K.Wash with Vax tool ff4,433' 1/4,571'.POOH f/4,571'1/4,089'.Wash in the hole f/4,089'1/5,053'.TIH f/5,053'1/5,439'-multiple tight spots.Wash with Vax tool(/5,439'1/7,755'. 5/4/2011 5/5/2011 0.0 10.20 Wash with Vax tool f/7,775't/11,914'.Circulate bottms up 2x.Cut and slip drilling line.Circulate hole clean with 4 bottoms up.POOH f/11,605'U9,967'. 5/5/2011 5/6/2011 11,914.0 10.20 POOH 89,967'U surface w/Baker Vax tool BHA.LD BHA.Function blind rams.PU Baker hydrostatic bailer and 17 joints of 2-7/8"6.5#L-80 tubing. RIH on 4"DP t/12,314'.Observe bailer open.Observe pipe fill through bailer w/99 bbls fluid.Observe well for 15 min.POOH f/12,314' 1/7,791'. Page 1/2 Report Printed: 6/10/2011 PI O N E E R ations Summary Report - State Well Name: ODSN-18/ODSN-18L1 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 5/6/2011 5/7/2011 13,035.0 10.20 Continue to POOH w/Baker hydrostatic bailer f/7,791't/589'.Clean sand from 4 stands of 4"DP. LD pump out sub,main bailer valve and upper drain valve. RIH w/4 stands of 4"DP 0943'.RU and reverse circulate sand out of 2-7/8"tubing and 4"DP.POOH f/943't/589'standing back 4" DP.RU 2-7/8"equipment.Stand back 2-7/8"tubing U198'.LD remaider of BHA and inspect same for re-run.Service rig.PU hydrostatic bailer BHA t/1,151'.RIH on 4"DP t/2,501'. -AOGCC was notified of upcoming BOP test at 18:00 hrs on 5/06/11.AOGCC Rep. Bob Noble returned call and requested 24 hr.update. 5/7/2011 5/8/2011 13,035.0 10.20 Continue RIH w/hydrostatic bailer run#2 f12,501'013,035'.POOH above 4-1/2"liner. Fill DP w/ 35 bbls 10.2 ppg brine.Monitor well.POOH wet t/10,212'.Shear pump out sub and continue POOH 01,344'.Drain sand from 2 stands 4"DP by breaking singles. LD bailer assembly and drain valve.RIH w/4 stands DP and 2-7/8"tubing 01,537'.RU and reverse circulate DP/tubing volume 6x.RD circulating equipment. **AOGCC was notified of upcoming BOP test at 18:00 hrs on 5/06/11 and updated on 5/07/11. AOGCC Rep.Bob Noble waived right to witness test at 14:10 hrs.on 5/07/11. 5/8/2011 5/9/2011 0.0 10.20 Continue RD reverse circ equip. Install mousehole.Stand back 4 stds 4"DP. LD 36 jts 2-7/8" tubing and bailer jewelry. Pull wear ring.Flush stack. Install test plug.RU to test BOPE. , Test BOPE per AOGCC Sundry Approval: ��11 -Test BOPE w/4"test joint to 250 psi low and 3500 psi high. -Test BOPE w/2-7/8"test joint to 250 psi low and 3500 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 3500 psi high. -Test upper and lower IBOP valves to 250 psi low,3500 psi high. -Test 14 choke man.valves to 250 psi low,3500 high. -Initial sys.pressure=3000 psi.After closure=2100 psi. -200 psi obtained in 24 seconds. Full pressure in 88 sec. -All tests charted and all tests held for 5 min. -Right to witness waived by AOGCC Rep.Bob Noble at 14:10 hrs on 5/07/2011. **NOTE**3 failures:Choke and Kill HCR's failed.Greased and retested-Good test.#1 choke manifold valve failed. Rebuild same and retest.Good test. Install wear ring. PU Weatherford seal stem,Formation Saver Valve(FSV)and Arrow Pak packer w/HST setting tool and RIH on 4"DP 011,914'.Drop setting ball.Set packer and release from same. 5/9/2011 5/10/2011 0.0 10.20 Close annular.Test packer and FSV to 500 psi f/5 charted min-Good test.Attempt to shear bypass w/4200 psi 3x.No success.Allow well to equalize(U-tubing).RU to reverse circulate. Reverse circulate 1-3/4"ball out of DP.POOH LDDP f/11,809'V surface.Function blind rams. Pull wear bushing.RU to run ESP completion.PU ESP motor/pump assembly to±93'.Splice ESP cable to motor lead. 5/10/2011 5/11/2011 0.0 10.20 Continue to splice motor lead&secure.Test communication w/ESP-Good. RIH w/2-7/8" completion 08,462'. PU Weatherford packer.Make ESP splice through packer. 5/11/2011 5/12/2011 0.0 10.20 MU ESP connection to packer-Perform conductivity test.Good test.Test top of G.V.V.to 3500 psi f/10 min.Good test.PU"X"nipple#2.RIH 08,923'. PU TRScSSSV. MU control line.Test to 5000 psi f/10 min.Continue to RIH w/2-7/8"ESP completion f/8,924'010,941'.MU Vetco hanger and orient same.Land hanger f/10,941'V10,985'.Test upper and lower hanger seals to 5000 psi ff 10 charted min.Good test.RU lines to tubing and IA.Pressure up to set packer.Test tubing to 3500 psi f/30 charted min.Good test.Bleed tubing to 1250 psi.Test IA to 2000 psi f/ 30 charted min.Good test.Bleed off.Install TWC.ND BOPE.NU Vetco Gray production tree. Test tree and voids to 5000 psi f/10 charted min.Good tests. RU lubricator and pull TWC.RD lubricator.RU slickline and lubricator.Test lubricator to 1500 psi. 5/12/2011 5/13/2011 0.0 10.20 RIH w/SB pulling assembly. Retrieve B&R assembly. RIH to pull dummy f/GLM#1. POOH. Miss run. RIH and pull dummy f/GLM#1. RIH to pull dummy f/GLM#2. RIH and pull DCR shear valve.RIH to set.25"S.O. Kicked out into GLM#3 at 2,473'.POOH.LD tools. RIH and set Live valve in GLM#3 at 2,473'.RIH and set live valve in GLM#2 at 4,928'. RIH and set S.O.V.in GLM#1 at 8,393'. RIH and pull RHC-M body f/X nipple at 8,468'. RD slickline.Secure well. Release rig at 24:00 hrs on 5/12/2011. 5/13/2011 5/14/2011 0.0 10.20 Page 2/2 Report Printed: 6/10/2011 %urrent Schematic - State 'ell Name: ODSN-18/ODSN-18L1 P I 0 N E E R NATURAL RESOURCES HORIZONTAL-Sidetrack 5,6/2/2011 4:38:19 PM Well Attributes Vertical schematic(actual) API/UWI Field Name Well Status Total Depth(ftKB) 50-703-20624-00-00 000GURUK DRILLED 16,689.0 3-2 Casing Strings Conductor,158.0ft .1 fij ii. Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(lb/ft) Conductor 16 14.670 47.7 158.0 158.0 H40 Welded 109.00 Casing Components J 1-1 Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 1-1 Casing Joints 47.7 47.7 16 14.670 ® Surface,3,600.0ftKB �.�,,� Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(Ib/ft) 13-71 Surface 11 3/4 10.772 38.6 3,600.0 3,309.3 L-80 HYD 521 60.00 Casing Components 13-111 Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Com 13-15 ., 2-5 Tam-Port Collar 537.1 537.0 11 3/4 10.772 2-10 Surface Shoe 3,598.2 3,308.2 11 3/4 10.772 3-191--+ 7"Tie Back,8,307.9ftKB Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(lb/ft) 1 7"Tie Back 7 6.276 37.8 8,307.9 L-80 Buttress 26.00 2-10 Thread Casing Components l3-23 -- Top (TVD) 3-9 Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Com y 3-12 3-9 Weatherford SHR Hold 8,281.8 7 6.276 ' 6-1 Down Sub P: :r6-3 3-12 7"PBR Tie Back Seals 8,288.6 7.49 6.250 Ea :r—'f 6-4 9-5/8"Drilling Liner,8,824.0ftKB IF Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(Ib/ft) 13-27) 9-5/8"Drilling 9 5/8 8.835 3,319.7 8,824.0 5,329.1 L-80 HYD 521 40.00 Liner 13-31 7"Stuck Liner#1,11,202.0ftKB 3-35Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(Ib/ft) 3-37 7"Stuck Liner 7 6.276 8,475.3 11,202.0 6,048.7 L-80 HYD 511 26.00 21 #1 2-1 Casing Components Top(TVD) 2-3'\ at Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 2-4 5-12 7"Liner Shoe 11,200.0 6,048.2 7 6.276 amt a- _ 7"Drilling Liner,12,090.0ftKB Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(lb/ft) 2-10 iirtr_ /77-11 7"Drilling Liner 7 6.276 8,288.6 12,090.0 6,174.6 L-80 Buttress 26.00 7_2 Thread 7-4 Casing Components Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn - a .6-11 6-1 WTF PBR Tie Back Sleeve 8,288.6 8 1/4 7.500' WS -7-7 NM _7-9 6-3 WTF 7"x 9 5/8"TSP5H1 8,309.5 7 6.276 7- 1 Liner Top Packer 7-14 6-4 WTF 7"x 9 5/8"PHR Rot. 8,315.3 7 6.276 7-17 Liner Hanger ® 6-11 7"Liner Shoe 12,087.9 6,174.2 7 ® 7-19 7-21 Lower Lateral 4 1/2"Production Liner,16,400.0ftKB ® IMP ,7-23 Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection WULenLe (Ib/ft) .7-25 Lower Lateral 4 1/2 3.958 11,915.5 16,400.0 6,232.5 L-80 Hydril 521 12.60 ® 4 1/2" ESIIP .7-27 Production ® -7-29 Liner mar--7-31 Casing Components • 17-341 Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn ,:,: ® 7-1 Tie Back Sleeve 11,915.5 6 7-39 11 1=11Il 7-41 lEI: 7-43 I_7-45 .• 7-48 MI —ill1M101® —0•11® :,er im0® Page 1/3 Report Printed: 6/2/2011 :urrent Schematic - State 'ell Name: ODSN-18/ODSN-18L1 P I O N E E R NATURAL RESOURCES HORIZONTAL-Sidetrack 5,6/2/2011 4:38:36 PM Casing Components Vertical schematic(actual) Item# Item Des TopTop(TVD) (ftKB) (ftKB) OD(in) ID(in) Com 7-2 7-2 NTH Packer 11,930.9 6.276 3.958 7-4 PHR Hanger 11,934.2 6.276 3.958 - 7-7 Ported Sub 12,301.6 4 1/2 3.958 -1 7-9 Ported Sub 12,506.1 4 1/2 3.958 J 7-11 Ported Sub 12,627.8 4 1/2 3.958 �1-1 7-14 Resman Tracer Sub#3 12,795.4 4 1/2 3.958 ® 7-17 Ported Sub 13,004.7 4 1/2 3.958 7-19 Ported Sub 13,168.2 6,207.1 4 1/2 3.958 3-7 ill 7-21 Ported Sub 13,535.2 6,216.7 4 1/2 3.958 • 7-23 Ported Sub 13,734.4 6,229.9 4 1/2 3.958 3-11 £ 7-25 Ported Sub 13,934.1 6,233.4 4 1/2 3.958 so 3 15 s. 7-27 Ported Sub 14,138.0 6,235.3 4 1/2 3.958 • 7-29 Ported Sub 14,299.6 6,238.8 4 1/2 3.958 I 13-191 s 7-31 Ported Sub 14,463.1 6,240.3 4 1/2 3.958 7-34 Resman Tracer Sub#2 14,708.7 6,236.6 4 1/2 3.958 I I 7-37 Ported Sub 14,839.7 6,237.7 4 1/2 3.958 2-10 7-39 Ported Sub 15,043.1 6,244.3 4 1/2 3.958 13-23I - 7-41 Ported Sub 15,247.2 6,241.5 4 1/2 3.958 at r 3-9 7-43 Ported Sub 15,448.2 6,248.6 4 1/2 3.958 / 3-12 7-45 Ported Sub 15,648.4 6,251.4 4 1/2 3.958 II 61 mot7 6 3 7-48 Resman Tracer Sub#1 15,814.7 6,242.8 4 1/2 3.958 o 6-4 7-51 Ported Sub 15,867.2 6,239.4 4 1/2 3.958 7-53 Ported Sub 16,029.0 6,231.5 4 1/2 3.958 so 13-271 a 7-55 Ported Sub 16,234.4 6,229.7 4 1/2 3.958 I 3-31 • 7-57 Eccentric Shoe 16,398.7 6,232.5 4 1/2 3.958 - Tubing Strings 3-35 ! Tubing Description String M... ID(in) Top(ftKB) Set Depth(f...Set Dept...Wt(Ib/ft) Grade Top Thread ® III WFT Formation Saver 5.645 2.992 11,871.6 11,918.0 3-1/2" 3-39 " Valve Assy EUE ® Tubing Components ® Top(TVD) BF Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Com 2-4 i 2-1 'WET Arrow Pak Ret. 11,871.6 ' 5.945' 3.500 1m Packer 2-8- 2-10 �7=1=1 2-3 Tubing Dump Valve 11,881.0 41/2 3.000 7-2 2-4 Formation Saver Valve 11,881.8 5.645 2.992 7-4 2-8 No Go Sub/Crossover 11,910.1 5.8 3.000 2-10 Ratcheting Muleshoe 11,915.7 5.2 3.937 Tubing Description String M... ID(in) Top(ftKB) Set Depth(f...Set Dept...Wt(Ib/ft) Grade Top Thread I • 6-11 ESP Completion 2 7/8 2.441 0.2 10,986.0 6.50 L-80 IBT-M ;K1, 7-7 Tubing Components SKIS 7-9 Top(T'/D) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Com EI: 7-11 3-2 Vetco Gray Tubing hanger 34.5 10 4.250 , 7-14 13/16 7-17 3-7 TRMAXX-5E SSSV 2,068.3 4 3/4 2.312 Me 7-19 3-11 GLM#3 w/1.5"DCR 2,463.7 5 1/2 2.365 !.5"DCR Shear Valve ® Shear Valve Replaced with LGLV is. ® 3-15 "X"Nipple#2 2,516.2 3.53 2.313 ow ® 3-19 WFT Hydrow II Packer w/ 2,570.2 6.002 2.359 ® Gas Vent Valve re 7-29 7-31 3-23 GLM#2-1 1/2"w/DV 4,919.1 5 1/2 2.365 LGLV installed o. installed • 17-34 3-27 GLM#1 -1 1/2"w/DV 8,383.7 5 1/2 2.365 0.25"OV installed a‘ ,15151 ,1 ® installed 7-39 3-31 "X"Nipple#1 w/RHC-M 8,467.2 3.53 2.313 7-41 1=117-41 7-43 ma 7-45 . 7-48 Mil m ItEE ig.0® EtEli�® :MME M® Page 2/3 Report Printed: 6/2/2011 PtO N E E R ;urrent Schematic - State -fell Name: ODSN-18/ODSN-18L1 NATURAL RESOURCES HORIZONTAL-Sidetrack 5,6/2/2011 4:38:49 PM Tubing Components Vertical schematic actual Top(TVD) ( ) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 13-2 3-35 Auto Diverter Valve 10,903.6 4 1/2 0.000 3-37 Discharge Gauge 10,909.6 4 1/2 0.000 3-39 Baker ESP-Pump/Motor 10,914.9 5 0.000 assembly(P11 207 stage) I J k1-1 * 12-5 3-7 s ■ 3-111lio4- (3-15 13-19 1i a 12-101 13-23 I� 3-9 3-12 11Ur , 6-1 ."6-3 6-4 13-271 101.11;.-,3-31 3-35 ®3-39 BM Eal 2-4 Kiii! 2-8 i 2-10 i7-1 i. II -7-2 r 7-4 I 6-11 .E; Ea M 7-9 7-11 7-14 7-17 m 7-19 f 7-21 ariR 111111 MI ME. M MEI T 7-29 • 7-31 17-341 �� in INEI FMO" 7-39 • 7-41 ��7-43 �i 7-45 7-48 miff 12111 EL.i® �® Page 3/3 Report Printed: 6/2/2011 uE �� O - SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 April 6, 2011 Mr. Rob Tirpack Drilling Superintendent Pioneer Natural Resources Alaska, Inc. 700 G Street , Suite 600 Anchorage, AK 99510 Subject: Notice of Violation Failure to Notify Commission of Surface Casing Cementing Issue Oooguruk Unit- ODSN-18 (PTD 210-142) Dear Mr. Tirpack: The Alaska Oil and Gas Conservation Commission (Commission) has reviewed the explanation from Pioneer Natural Resources Alaska, Inc. (Pioneer) regarding the failure to notify the Commission of excessive cement returns on ODSN-18 surface casing cementing operation. That explanation was in response to the Commission's notice of violation dated March 15, 2011. The Commission is satisfied with the corrective action summarized in Pioneer's response: 1) Developing a cement calculation spreadsheet to flag excessive cement returns. 2) The cementing contractor and Pioneer drilling engineer will conduct a post review of the cement job right after pumping is completed. The Commission has again reviewed the facts associated with the issuance of the March 15, 2011 notice of violation in light of information provided by Pioneer. Pioneer has recalculated cement returns assuming gauge hole and indicated that instead of-24% excess (i.e. un-cemented coverage) there is closer to -7% excess. Although this is better than originally thought, it is still negative and is most likely poor cement coverage since historically Oooguruk surface casing cement jobs average +30% to +70% excess due to washout of the wellbore. Pioneer stated that the shoe track drillout and Formation Integrity Test (FIT) went as planned which indicates that the most critical area of the surface casing(shoe area) appears to be well cemented. Careful calculations and review of cement jobs are critical to the successful construction of oil and gas wells. Attention to detail is vital to ensure that surface casing is cemented properly and provides an adequate barrier to the migration of fluids along the casing annulus. In this incident Pioneer was not calculating final cement placement in the wellbore and was not aware of the requirement to report excessive returns of cement in a surface casing cement operation to the f' Mr. Rob Tirpack April 6,2011 Page 2 of 2 Commission as required by 20 AAC 25.030 (d)(4). Simply having cement returns to the surface does not insure that the wellbore is properly cemented and excessive returns could indicate severe cement channeling which would compromise the annulus's integrity. Pioneers recently implemented "Surface Cementing" spreadsheet will calculate the percentage of cement coverage in the wellbore and have a trigger to notify the Commission if cement placement falls below 100% of gauge hole volume which is indicative of excessive cement returns. The cementing contractor and Pioneer's drilling engineer will independently calculate hole volume vs. returned cement. Immediately following the cementing job they will conduct a post job analysis to review the data and report to the Commission if excessive cement returns are indicated. The Commission considers this matter closed with the implementation of Pioneer's corrective action. Sincerely, Daniel T. Seamount, Jr. 404/. o a Chair 'ommissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails,OR 30 days if the Commission otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the Commission,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails,OR 30 days if the Commission otherwise distributes,the order or decision on reconsideration. As provided in AS 31.05.080(b),"[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. Fic atugn SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Joe Delmonico Drilling Engineer Pioneer Natural Resources Alaska, Inc. t4'9— 700 G Street, Suite 600 110 1 Anchorage, AK 99501 Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-18 Sundry Number: 311-092 Dear Mr. Delmonico: 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, -0/ Daniel T. Seamount, Jr. t 5 Chair DATED this J day of April, 2011. Encl. 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 March 24, 2011 State of Alaska RECEIVE` Alaska Oil and Gas Conservation Commission 333 West 7th Ave, Suite #100 MAR 4 Anchorage, AK 99501 O &Cas Cans.Commission RE: Application for Sundry to Modify Completion, ODSN-18 ttndiata90 Pioneer Natural Resources Alaska is requesting Sundry approval for the workover of the ODSN-18 production well. Please see the attached Form 10-403 and proposed rig workover plan. The well's upper completion is currently a 4-1/2" fracture stimulation string, producing with gas lift. The proposed workover would replace the 4-1/2" string with a 2-7/8" Electric Submersible Pump (ESP) completion and Formation Saver Valve assembly (FSV). Please see the attached proposed completion diagram and operations summary for further detail. Sincere) , / //iv- • oe Delmonico Jr. Drilling Engineer Attachments: Form 10-403 Supporting Sundry information cc: ODSN-18 Well File STATE OF ALASKA it-. 11 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well 0- Change Approved Program 0 Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing 0- Time Extension ❑ Operations Shutdown 0 Re-enter Susp.Well 0 Stimulate 0 After Casing❑ Other: Change Tubing/Run ESP 0- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Pioneer Natural Resourcs Alaska, Inc. Development 0- Exploratory 0 210-142 3.Address: 700 G Street,Suite 600 Stratigraphic 0 Service 0 6.API Number: Anchorage,AK 99501 50-703-20624-00-00 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 ODSN-18 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 3550367 ADL 355037- Oooguruk-Nuiqsut- 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): 16,689' - 6229'- 16,399' 6232' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3557' 11-3/4" 3600' 3309' 5830 psi 3180 psi Drilling Liner 5504' 9-5/8" 3320'-8824' 3124'-5329' 5750 psi 3090 psi Tie-back 8270' 7" 8308' 5149' 7240 psi 5410 psi Intermediate 3801' 7" 8289'- 12,090' 5143'-6175' 7240 psi 5410 psi Production Liner 4485' 4-1/2" 11,915'-16,400' 6144'-6232' 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 4-1/2", 12.6# L-80, HYD 521 11,916' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ScSSSV;7"x 9-5/8"Liner Top Packer;4-1/2"x 7"Liner Top Packer 2004'MD/1981'TVD;8309'MD/5150'TVD; 11,931'MD/6147'TVD 12.Attachments: Description Summary of Proposal Q 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: Commencing Operations: 4/14/2011 Oil 0- Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG ❑ Abandoned 0 Commission Representative: GSTOR 0 SPLUG ❑ 17.I hereby certify that tl e foregoing is true and correct to the best of my knowledge. Contact Joe Delmonico,343-2182 Printed Name r,•- i e•,•�,,•, ;<-2182/907-980-7690 Title Drilling Engineer Signature j Phone Date 3/24/2011 Prepared By:Kathy Campoamor,343-2183 7 r COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1 ‘ Lf L Plug Integrity 0 BOP Test Xi Mechanical Integrity Test ❑ Location Clearance ❑ 3R-EcCE1 Other: -4 3SGb p.c.: /30P %-5 f VEL 1f- zs ) psi, A-r,,b,.....- ;754 (w.t't..) UA!-1f6 2 4 ag A,L3tka OP a G g(;pnc !', T, Subsequent Form Required: An • O'f c ?;_aa • ' APPROVED BY Approved by: Ilk��/ COMMISSIONER THE COMMISSION Date: 44 ii 1 \ 'PR04 (33i ri Form 10-403 Revised 1 i . O R I G I N A L -�.A€� Submit,17[..470 / �Duplicate Pioneer Natural Resources Alaska Inc. ODSN-18 Page 2 Form 10-403, Application For Sundry Approvals Present Well Condition - Box #11 Perforation Depth Attachment 24. Open to production or injection 4-1/2", 12.6#, L-80 Hyd 521 Uncemented Liner Perforated Pups w/ 6-1/2" Holes CO depths listed: MD TVD 12,302' - 12,306' 6201' - 6202' 12,506' - 12,511' 6222' - 6222' 12,628' - 12,632' 6225' - 6225' 13,005' - 13,009' 6211' - 6211' 13,168' - 13,173' 6207' - 6207' 13,535' - 13,540' 6217' - 6217' 13,734' - 13,739' 6230' - 6230' 13,934' - 13,939' 6233' - 6233' 14,138' - 14,143' 6235' - 6235' 14,300' - 14,304' 6239' - 6239' 14,463' - 14,468' 6242' - 6242' 14,840' - 14,844' 6238' - 6238' 15,043' - 15,048' 6244' - 6244' 15,247' - 15,252' 6242' - 6242' 15,448' - 15,453' 6249' - 6249' 15,648' - 15,653' 6251' - 6251' 15,867' - 15,872' 6239' - 6239' 16,029' - 16,034' 6232' - 6231' 16,234' - 16,239' 6230' - 6230' ODSN-18 Proposed Rid Workover Operations Summary Pre Rig: Slick Line Operations 1. MASP = 1630 psi ✓ 2. SI ODSN-18 1 - 3 days prior to MIRU. 3. MIRU slick line. • 4. Close WRScSSSV. NU lubricator. • 5. RIH and remove the WRScSSSV. 6. RIH and w/XXN plug. SJl' e 737<'.40 7. RIH and retrieve LGLV from GLM #3. C. 7177' Mo 8. Circulate kill weight fluid through GLM#3. 9. RIH and set a dummy GLV in GLM #3. , 10. Attempt to test IA to 2500 psi for 30 min. Record and chart test, monitor until pressure stabilizes. in. L" i 11. Retrieve XXN plug. V 12. RDMO. Set BPV. ND Otis Connection and NU injection valve. Remove BPV. 13. Monitor tubing pressure and IA pressure via operator's daily reading schedule until rig moves on location, prep surface equipment for rig move. Pre Rig: Coil Tubing Operations 1. MIRU coil tubing and RIH with 4.5" inflatable retrievable bridge plug and set below the 4- 1/2"x 7" liner/hanger/packer assembly in the 4.5" liner. ✓ 2. Pressure test bridge plug to 2500 psi for 5 min. 3. RDMO. MIRU Nabors 19AC: 1. Install a BPV into the tubing hanger profile. ---‘" (45 B ire a. Barriers are (a minimum of 2): i. Tubing side 1. Kill weight fluid down to GLM#3. 2. Tested IRBP. 3. BPV in the tubing hanger. ii. Annulus 1. Kill weight fluid to the tested liner hanger packer. 2. Tested seals stabbed into polished bore. 3. Tubing hanger pack offs. 2. ND tree and NU BOP's. Install test dart and 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. 3. Pull to release seals from seal bore. '' Page 1 of 2 PIONEER MA U'iAL HESUUHGES ALJ',S A 4. Pull 4-1/2"frac completion string out of the hole filling hole matching pipe displacement. 5. Have FOSV on rig floor. 6. PU 12,000' 4" DP. 7. RIH and retrieve IRBP. 8. PU FSV assembly and RIH on 4" DP. Test IA to stabilized pressure from IA test in step 10 from slick line operations for 5 min to ensure packer is set. 9. Release from FSV. Close rams and PT the FSV to pressure from.,Apacker test in previous step for 5 min. POOH LD Dp. y F Samar Yu-/✓--• 10. PU & RIH 2-7/8", 6.5 ppf, L-80, IBT-M tubing consisting of: a. ESP w/ADV b. X nipple w/ RHCM plug body c. Dummied 2 7/8" GLM 5� d. 7" x 2-7/8" Packer with GW. e. X nipple above packer f. Dummied 2 7/8" GLM g. TRScSSSV. 11. PU LJ w/ production tubing hanger. 12. Land tubing hanger. RILDS for tubing hanger. Test both the upper and lower tubing hanger body seals to 5000psi. Set BPV. 13. ND BOPE. 14. NU Production ESP tree and body test to 5000 psi. V 15. Run ball and rod. Set packer. Test annulus and tubing to 2500psi, 30 min tests. Post Rig: 1. MIRU HES slick line 2. Retrieve ball/rod assembly from RHC-M plug body. 3. RIH pull dummy from lowest GLM. Run LGLV with 0.25" orifice back in mandrel. 4. RIH w/ 2-7/8" GS to X nipple, retrieve RHC-M plug body. 5. Rig down slick line. 6. Function Test TRScSSSV. Page 2 of 2 P10NEER NATURAL RESOURCES ALASKA ODSN- — Current Status 03/: '11 Well Head: 9-5/8", 5K,VetcoGray Tree: 4-1/2",5K, Horizontal 4-1/2"XXO Safety Valve Landing Nipple w/isolation sleeve @ �- 16"Conductor 2,004'MD/1981'TVD �� 158'MD/158'TVD GLM#1 Brou-1A GLM 4-1/2"x J, 1"w/Dummy GLV @ 2,216' MD/2186'TVD Top of Intermediate 1 Liner @ 3,321'MD/3,124'TVD Surface Casing 11-3/4",60#L-80 BTC, 10.625"ID GLM#2 Brou-1A GLM 4-1/2"x 3,600'MD/3,309'TVD 1"w/Dummy GLV@4,369' MD/3,794'TVD _J Top of Intermediate 1 Cement Squeeze Job GLM#3 Brou-1A GLM 4-1/2"x 14 bbls cement 1"w/'/4'SO Valve @ 7,277' 0 1 MD/4,792'TVD J' Intermediate 2 Tie Back 7",26#L-80 BTC-M,6.276"ID 4 1/2"XN Nipple,3.725"ID8,309'MD/5,150'TVD Nogo @ 7,375'MD/4,824' -- .fir M TVDIZ r Top of Intermediate 2 Liner @ 8,309'MD/5150'TVD Intermediate 1 liner Window f 9-5/8",40#L-80 Hydril 521,8.835"ID Bottom of Window @ 8,455'MD/ 5,201'TVD rDc m cm 0 n N O 0 - Frac String 4-1/2"ROC Gauge and Carrier t...........„ 4-W 12.6#L-80 Hydril 521 @ 11,812'MD/6,159'TVD 11,916'MD/6,145 TVD Intermediate 2 Liner 7",26#L-80 BTC-M,6.276"ID 12,090'MD/6,174'TVD b.)'kl0 0 0 0 S " �� 00 c 00 c 00 ��� 00 c, 00 c, 00 c, ~ m 00 00 . 00 C ~ 00 C ~ 00 C 00 00 0 Lateral Liner 4-'/2'12.6#L-80 Hydril 521 16,400'MD/6,232'TVD Note:All depths in rkb Date: Revision By: Comments PIONEER 01-11-2011 TWC Revised for Frac Completion 01-12-2011 TWC Corrected Numbering/Lettering NA IURkRESOUROESAIASO. 1-18-2011 Alex Vaughan As Built 1-25-2011 JAD Fracture Stimulation 3-10-2011 JAD Current Status r ODSN-18 Proposed ESP Completion Casing Item# Item MD(ft) TVD(ft) J 0A 16" Conductor 158 158 O B C 11-3/4"60#L-80 Hydril 521, 10.772" ID 3,600 3309 9-5/8"40#L-80 Hydril 521, 8.835" ID* 8,455 5201 D 7"26#L-80 BTC-M,6.276" ID, Tieback 8,309 5150 ��Q E 7"26#L-80 Hydril 511, 6.276" ID** 12,090 6174 F 4-1/2" 12.6#Hydril 521 3.958" ID 16,400 6232 G 2-7/8"6.5#L-80 IBT-M 10,975 5944 O Upper Completion 2 '' ' ` - a Drkb(ft) TVDrkb(ft) 1 VetcoGray Tubing Hanger 34 34 $O 2 2-7/8" HES Wellstar TRSV w/2.313 Packing Bore 2,020 2,000 2,414 GLM#1 -Vanoil 2-7/8"x 1-1/2"w/ 1-1/2" DV installed 3 (2 joints above top X nipple) 2,454 4 2-7/8"X Nipple 2.313" I.D. (1 joint from packer) 2,518 2,475 5 WFT 7"x " Vve Packer(max.TVD 2500') 2,550 2,500 6 GLM#2 Vanoil 2-7/8"x 1-1/2"w/ 1-1/2" DV installed 8,400 5,182 7"x 9 5/8"Hold 2W-778.,7x" -7/8"X Nipple2-7/8,2.313Gas" I.Dent.Valw/"RHC M" Plug installed down sub @ 7 (2 joints below mandrel) 8,464 5,203 8,281'MD 8 Automatic Divert Valve(ADV) 10,904 5,926 9 ESP(Pump, Motor,and Jewelry) 10,914 5,929 6 End of Assembly 10,975 5,944 7"x9-5/8"LHP and seal bore w/ O OD TBSS @ 8,288' MD 10 WFT7"x 3-1/2" Retrievable Packer 11,850 6,132 11 WFT 3-1/2"Pressure Activated Sleeve 11,875 6,137 II OC 12 WFT 3-1/2" Formation Saver Valve F51/ 11,900 6,142 13 1 jt 3.5"TC-II and WLEG 11,910 6,143 --- 8�j End of Assembly 11,945 6,150 �/ Lower Completion Item# Item MD(ft) TVD(ft) C9 14 WFT PBR Tie Back Sleeve 155 11,915 6,144 15 WFT"NTH" Liner Top Pkr 11,930 6,147 0 16 WFT"PHR" Rotating Hyd Set Liner Hanger 11,934 6,148 17 Resman Tracer Pup(heel location) 12,975 6,211 CO .._7_ O O O ® 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes), 18 spaced every 200'. -CO 19 Resman Tracer Pup(midlateral location) 14,708 6,237 14 20 Resman Tracer Pup(toe location) 15,814 6,243 21 Liner Shoe(PLUGGED)w/4-1/2" Hydril 521 16,398 6,232 .: 15 End of Assembly 16,400 6,232 O 1 ODSN-18 00 00 00 Pij 00 00 00 TD: 16400' 17 00 00 18 00 19 00 00 00 20 21 MD/6,232' h 00 00 O- 00 00 00 00 O TVD ResMan Produced Oil&Water Markers Date: Revision By: Comments ODSN-18 PIONEER 3/10/2011 JAD Proposed ESP Completion Proposed NATURAL RESOURCES ALASKA Completion Design ) - PIONEER NATURAL RESOURCES ALASKA Letter of Transmittal Date: March 28, 2011 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Christine Shartzer 700 G Street, Suite 600 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps X Report X Other— Logs ❑ Agreement DETAIL QTY DESCRIPTION ODSN-18, ODSN-18 PB1, ODSN-18 PB2, ODSN-18 PB3, ODSN-18 PB4, ODSN-18 PB5 ODSN-18 50-703-20624-00-00 O D S N-18 P B 1 50-703-20624-70-00 ODSN-18PB2 50-703-20624-71-00 ODSN-18PB3 50-703-20624-72-00 ODSN-18PB4 50-703-20624-73-00 ODSN-18PB5 50-703-20624-74-00 1 set of Logs and Report Detail on following page We request that all data be treated as confidential inforrRprIVEIVIC Received by: Date: MAR 5 '' L. Alaska Oil Wirtu. C rnni. ior1 Please sign and return one copy to Pioneer Natural ResotActigNii46., ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 907-343-2190 fax 907-343-2128 phone Ofo —(149- abse-(l March 28,2011 QTY DESCRIPTION 1 Report Surface Data Logging End of Well Report ODSN-18 50-703-20624-00-00 24 Well Logs Engineering Log (1:600), Gas Ratio Log (1:600), Formation Evaluation Log (1:600, 1:240) O DS N-18 P B 1 50-703-20624-70-00 Engineering Log (1:600), Gas Ratio Log (1:600), Formation Evaluation Log (1:600, 1:240) ODSN-18PB2 50-703-20624-71-00 Engineering Log (1:600), Gas Ratio Log (1:600), Formation Evaluation Log (1:600, 1:240) ODSN-18PB3 50-703-20624-72-00 Engineering Log (1:600), Gas Ratio Log (1:600), Formation Evaluation Log (1:600, 1:240) ODSN-18PB4 50-703-20624-73-00 Engineering Log (1:600), Gas Ratio Log (1:600), Formation Evaluation Log (1:600, 1:240) ODSN-18PB5 50-703-20624-74-00 Engineering Log (1:600), Gas Ratio Log (1:600), Formation Evaluation Log (1:600, 1:240) • Page 2 PIONEER fry NATURAL RESOURCES Pioneer Natural Resources Alaska 700 G Street Suite 600 Anchorage, AK 99501 Oooguruk Island ODSN-18 Sales Order: 7726019 Surface Cementing Post Job Report For: Alex Vaughan Date: Thursday, October 28, 2010 Notice: Although the information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise. The application, therefore, by the user of this report or any part thereof,is solely at the user's own risk. HALLIBURTON HALLIBURTON PIONEER NATURAL RESOURCES USA INC ODSN-18 ODSN-18 Surface Casing Table of Contents 1.0 Executive Summary 3 2.0 Well Conditions 5 3.0 Fluid Summary 5 4.0 Calculations 6 5.0 Design 8 5.1 Customer Information 8 6.0 Job 9 6.1 Stage Summary-Volume and Density—CMT Unit 9 6.2 Stage Summary-Pump Pressure 9 6.3 Stage Summary-Pump Rate 9 6.4 Shutdown Summary 10 6.5 Job Event Log—CMT Unit 10 6.6 Job Event Log—Rig Floor Data 11 7.0 Attachments 12 7.1 Pioneer ODSN-18-Surface Casing(graph) 12 7.2 Pioneer Oooguruk Island-ODSN-18 Surface Casing Floor Data(graph) 13 7.3 Pioneer Oooguruk Island-ODSN-18 Surface Casing Floor Data-Events(graph) 14 7.4 Pioneer Oooguruk Island-ODSN-18 Surface Casing Displacement(graph) 15 7.5 Pioneer Oooguruk Island-ODSN-18 Surface Casing Displacement 2nd Half(graph) 16 2 Created:March 15,2011 at 11:08 AM OptiCem v6.4.1 (OC v6.4.1) HALLIBURTON PIONEER NATURAL RESOURCES USA INC ODSN-18 ODSN-18 Surface Casing 1.0 EXECUTIVE SUMMARY Alex Vaughan Pioneer Natural Resources Alaska Anchorage,AK Dear Mr.Vaughan, Executive Summary The 11-3/4" surface casing on ODSN-18 was successfully cement on 10/28/2010. A total of 433.6 bbls of cement was pumped (337.7 bbls of Type L Permafrost and 95.8 bbls of Premium Cement plus additives). Calculated displacement was 396 bbls. The top plug bumped at 400.6 bbls. The pressure increased but did not hold after landing. An additional 8 bbls were pumped. The floats were checked and held pressure. 1.6 bbls of cement slurry remained in the shoe joint. A total of 200 bbls of cement returns were noted on surface-this equates to obtaining 21.2 bbls of cement slurry early as calculated from gauge hole volumes for an effective OH diameter of 14.28" indicating that some channeling occurred. The casing was successfully tested to 3,500 psi for 30 minutes. During drill out,hard cement was noted on the float collar and 3'above the float shoe.A 14.7 ppg EMW LOT was achieved after drill out. Detailed Job Summary Halliburton appreciates the opportunity to perform the cement job. A pre job safety meeting was held where details of the job were discussed, potential safety hazards were reviewed, and environmental compliance procedures were outlined. 3,600' of 11-3/4" 60#/ft casing was successfully cemented inside a 14 1/2" hole from TD to surface in a planned single stage job. The well was conditioned and circulated after casing was run. 9.6 ppg mud was circulated at 11 bpm. Full returns were indicated throughout circulation of the well. A total of 20 bbls of water were pumped and lines were tested to 4,000 psi before dropping the 15`bottom plug. 60 bbls of 10 ppg Dual Spacer, 345.9 bbls (457 sacks) of Type "L" Permafrost mixed at 10.7 ppg on the surface (yielding 337.8 bbls downhole at 10.9 ppg). The 2"d bottom plug was dropped and 95.8 bbls (452 sacks) of Premium cement with 2%calcium chloride mixed at 15.9 ppg were pumped. Halliburton dropped the top plug and launched with 20.6 bbls of seawater before turning over to the rig for displacement. Calculated displacement was 396.2 bbls. Positive indications were noted at calculated volumes when each bottom plug landed and sheared. The rig pumped 3,770 strokes or 380 bbls(0.1008 bbl/stroke @ 96%eff.)for a total of 400.6 bbls displacement when the top plug landed. Pump pressure increased 275 psi and the pressure broke back. The rig pumped an additional 80 strokes or 8 bbls and shut down.The calculated shoe volume is 9.6 bbls leaving 1.8 bbls of cement in the shoe.The pressure was bled back to check the floats.The floats held.A total of 200 bbls of good cement returns were noted on surface as reported by the Cementer and Rig's afternoon report. (Note: the initial morning report stated 231 bbls of cement returns) The casing was tested to 3,500 psi and held for 30 minutes. A cleanout BHA was run and the rig tagged cement on top of the float collar at 3,514'. The rig drilled hard cement, the black top plug, two red bottom plugs, and float collar. Contaminated cement and mud was drilled below the float collar down to 3' above the float shoe when the cement drilled hard.The rig drilled out the float shoe and 20'of new hole and performed a LOT to 14.7 ppg EMW. Planned cement volumes were based on 75% excess + 50 bbls within the permafrost and 30% excess below the permafrost interval with the base of the permafrost at 1,681'.Tail slurry was calculated for 945' fill with 30%excess and an 85' shoe joint. A total of 433.6 bbls of cement were pumped(337.8 bbl lead downhole plus 95.8 bbls tail). The shoe joint capacity is 9.6 bbls and the 158' of 11-3/4" surface casing by 16" conductor annular capacity with 3 Created:March 15,2011 at 11:08 AM OptiCem v6.4.1 (OC v6.4.1) HALLI B U RTO N PIONEER NATURAL RESOURCES USA INC ODSN-18 ODSN-18 Surface Casing 0%excess is 11.9 bbls.The amount of cement that was placed in the open hole between the base of conductor and TD of surface casing is 220.1 bbls calculated as follows: 433.6 bbls cement pumped less 200 bbls good cement returned to surface less 9.6 bbls shoe capacity plus 8 bbls pumped after the top plug landed less 11.9 bbls within the conductor by casing annulus leaving 220.1 bbls in the open hole.The 220.1 bbls of cement volume that was placed over 3,442' of open hole calculates to an average hole diameter of 14.28"hole.The gauge hole volume of the open hole portion is calculated at 241.3 bbls. Based on these calculations the cement returns to surface arrive 21.2 bbls early from calculated annular gauge hole volume indicating that cement channeling did occur. Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions provider for future projects. Respectfully, Phillip Clingman 4 Created:March 15,2011 at 11:08 AM OptiCem v6.4.1(OC v6.4.1) HALLI B U R TC1 N PIONEER NATURAL RESOURCES USA INC ODSN-18 ODSN-18 Surface Casing 2.0 WELL CONDITIONS Surface Casing Size&Wt. 11-3/4"60#/ft Casing Depth 3,600' Conductor Casing Size&Wt. 16" 109#/ft Conductor Casing Depth 158' Hole Size 14-1/2" Mud 9.6 ppg WBM Base of Permafrost 1,681' Planned Volume Excess 75%Permafrost+50bbl/30%Below 3.0 FLUID SUMMARY Preflush • 20 bbls Water Spacer 60 bbls Dual Spacer 10 ppg Lead Slurry 345.9 bbls(457 sacks)Type"L"Permafrost cement mixed at 10.7 ppg yielding 4.25 cuft/sk on surface(337.7 bbls, 10.9 ppg yielding 4.15 cuft/sk downhole) Tail Slurry 95.8 bbls(452 sacks)Premium cement with 2%calcium chloride mixed at 15.9 ppg yielding 1.19 cuft/sk Displacement 20 bbls Seawater 388 bbls Seawater(Rig)(380 bbls to land top plug+8 bbls) 5 Created:March 15,2011 at 11:08 AM OptiCem v6.4.1 (OC v6.4.1) Page 1 of% Schwartz, Guy L (DOA) From: Johnson, Vern [Vern.Johnson@pxd.com] Sent: Wednesday, March 16, 2011 12:10 PM To: Schwartz, Guy L(DOA) Cc: Tirpack, Robert; Delmonico, Joe; Vaughan, Alex Subject: ODSN-18 Surface Cement Operations Clarification Attachments: ODSN-18 Surface Cementing PJR .pdf Pro Z /6— 15/z Guy, See the attached detailed report from Halliburton regarding the surface cement job on ODSN-18. One clarification from what was reported in the completion report submitted for ODSN-18 is that the volume of cement returned to surface was 200 bbl of cement vs 231 bbl of cement as reported on the morning report. By gauge hole calculations, this indicates cement returned 21.2 bbl early . This indicates that some of the cement had channeled or we had under gauge hole. We had good returns to surface,floats held, 3 ft of hard cement were drilled above the float shoe, solid casing test to 3500 psi and leak off test to 14.1 ppge (a normal LOT for this area). This all indicated a good cement shoe, and good cement near surface. Because of the indications of a successful cement job, it was not identified by field or town personnel that there was a significant problem with the cement job that needed to be discussed with the AOGCC. This gap in our post cement job evaluation has been discussed with town and field engineers, as well as service company personnel to ensure that we are evaluating our cement jobs immediately after pumping them to identify any potential issues. Failure to engage the AOGCC in discussion of the cement job early was a failure of the team, and procedures have been put in place to prevent this from re-occurring. This was a relatively long surface hole, relative to most wells at Oooguruk and we are looking at ways to mitigate cement channeling in the surface hole. Please call me if you have any questions or want to discuss further. Vern Johnson Drilling Manager Pioneer Natural Resources Alaska 907-343-2111 office 907-575-9430 cell Statement of Confidentiality: 3/23/2011 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, March 14, 2011 11:48 AM To: 'Vaughan, Alex' Cc: Johnson, Vern Subject: RE: ODSN-18 (PTD 210-142) Surface Cement Issue Alex, As follow-up to our phone conversation regarding the Surface casing cementing in ODSN-18 I look forward to the full written report from the vendor and Pioneer. In hindsight Pioneer should have notified the Commission once it was realized that excessive cement was circulated to the surface as per 20 AAC 25.030 (d)(4) which reads.... " Surface casing must be cemented by filling the annular space with cement from the shoe to the surface;however, if cement does not circulate to surface, or an excessive quantity of cement is circulated to the surface, or if FIT test shows an inadequate cement job, The Commission must be notified before Drilling ahead. " It is likely severe channeling occurred based on the data and most likely a cement bond log would have been required to verify cement coverage and placement. This is a rare event but I want to reiterate the regulations are very clear about notification. In the future it is expected that a prompt notification will occur if a similar event happens again. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L (DOA) Sent: Wednesday, March 09, 2011 4:23 PM To: 'Vaughan, Alex' Subject: ODSN-18 (PTD 210-142) Alex, Can you send me the full cementing report for the surface casing job on ODSN-18 done on 10-28-2010??? The return cement volumes on the daily drilling report don't make sense to me... if they are correct it would mean the cement was over-displaced. The report also mentions the plug failed after bumping... can you elaborate. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 3/14/2011 PIONEER NATURAL RESOURCES ALASKA Letter of Transmittal Date: February 16, 2011 _ FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Christine Shartzer 700 G Street, Suite 600 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps ❑ Report X Other— Logs and CD ❑ Agreement DETAIL QTY DESCRIPTION ODSN-18, ODSN-18 PB1, ODSN-18 PB2, ODSN-18 PB3, ODSN-18 PB4, ODSN-18 PB5 ODSN-18 50-703-20624-00-00 ODSN-18PB 1 50-703-20624-70-00 ODSN-18PB2 50-703-20624-71-00 ODSN-18PB3 50-703-20624-72-00 ODSN-18PB4 50-703-20624-73-00 ODSN-18PB5 50-703-20624-74-00 1 set of Logs and CDs Detail on following page ��EEC( We request that all data be treated as confidential information ggili D �7 FEB 1 8 2011 Received by: - D / •Commission Anson Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 907-343-2190 fax 907-343-2128 phone aro - iyg ao9-4a, f February 16, 2011 QTY DESCRIPTION 1 CD LWD Final Processed Data (digital graphic logs, digital data) 24 Well Logs ODSN-18 50-703-20624-00-00 ABG DGR EWR-Phase 4 CTN ALD ROP Horizontal Presentation (1:600, 1:240) MD and TVD logs ODSN-18PB 1 50-703-20624-70-00 ABG DGR EWR-Phase 4 ROP (1:600, 1:240) MD and TVD logs ODSN-18PB2 50-703-20624-71-00 ABG DGR EWR-Phase 4 CTN ALD ROP Horizontal Presentation (1:600, 1:240) MD ABG DGR EWR-Phase 4 CTN ALD Invert Section (1:600, 1:240) TVD ODSN-18PB3 50-703-20624-72-00 ABG DGR EWR-Phase 4 CTN ALD ROP Horizontal Presentation (1:600, 1:240) MD ABG DGR EWR-Phase 4 CTN ALD Invert Section (1:600, 1:240) TVD ODSN-18PB4 50-703-20624-73-00 ABG DGR EWR-Phase 4 CTN ALD ROP Horizontal Presentation (1:600, 1:240) MD ABG DGR EWR-Phase 4 CTN ALD Invert Section (1:600, 1:240) TVD ODSN-18PB5 50-703-20624-74-00 ABG DGR EWR-Phase 4 CTN ALD ROP Horizontal Presentation (1:600, 1:240) MD ABG DGR EWR-Phase 4 CTN ALD Invert Section (1:600, 1:240) TVD • Page 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIOIN WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil Q • Gas ❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development Q - Exploratory❑ GINJ ❑ WINJ❑ WAG❑ WDSPL 0 No.of Completions: _Onej Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Suer, /"-nr ;IFI Permit to Drill Number: ••t� (1• Pioneer Natural Resources Alaska, Inc. Aband.: 1/i1ft017 210-142 • 1 3.Address: 700 G Street,Suite 600 6.Date Spudded: 13.API Number: Anchorage,AK 99501 10/25/2010 • 50-703-20624-00-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 2935'FSL,1177'FEL,Sec. 11,T13N,R7E,UM . 1/10/2011 ODSN-18 • Top of Productive Horizon: 8.KB(ft above MSL): 56.2'. 15.Field/Pool(s): 3241'FSL,3948'FEL,Sec. 10,T13N,R7E,UM GL(ft above MSL): 13.5' . Total Depth: 9.Plug Back Depth(MD+TVD): 000guruk-Nuiqsut Oil Pool 1491'FSL, 1712'FEL,Sec.4,T13N,R7E,UM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 469821.18 • y-6031051.27 • Zone-ASP 4 . 16,689'MD/6229'TVD. ADL 355036/ADL 355037 TPI: x- 461771.74 y-6031394.59 Zone-4s1.4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x- 458739.49 y- 6034940.40 Zone-Asp 4 2004'MD/1981'TVD 417497 18.Directional Survey: Yes U No U 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) 843'MD/842'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,DIR,SGRC,ACAL,ABG/ABI, EWR,GABI,PWD,DGR,RES,ALD,CTN N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 109# H-40 Surface 158' Surface 158' 24" Driven L-80 HYD 11-3/4" 60# 521 Surface 3600' , Surface 3309' 14-1/2" 457 sx PF'L';404 sx Class'G' � 5 .; 1*torr 9-5/8" 40# HYD 521 3320' �,,. 8824' / 3123' 5307' 11-3/4' 165 sx Class'G' ~� Y� 7" 26# L-80 Surface 8308' Surface 5150' //yy ' Tie-back 341-rt BTC-M �- IIQ _ 7" 26# L-80 8289' 12,090' 5143' 6175' 8-1/2" 162 sx Class'G' Z Ik�pf4 HYD 511 4-1/2" 12.6# HY 2 1 11,915' 16,400' 6144' 6232' 6-1/8" Uncemented 24.Open to production or injection? YesU Noll 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) XN Nipple Pkr 0 7375'MD/ 4-1/2", 12.60#, 4824'TVD;Liner Top Pkr L 80,HYD 521 11,916' 8309'MD/5150'TVD;NTH Pkr®11,931'MD/6147 See Attachment, Pg.3 TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 3320' 9-5/8'liner lap squeeze w/140 sx Class'G' 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 1/25/2011 Gas Lift Date of Test: Hours Tested: Production for •Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 1/25/2011 23.3 Test Period �} 380 207.5 13.6 3" 546 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 241 1126 24-Hour Rate -0 391 • 213.7 14 25 • 28. CORE DATA Conventional Core(s)Acquired? Yes 0 No 0 Sidewall Cores Acquired? Yes❑ No Q - 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. .' viE:iluti ( NEC WSW !LINone ' A q FEB 15 2011 U-1,1,1.;-1) :: RSDMS FEB 16 2011 r(:;":.... 06&Gas Cone Commission c0 �`'1, towage 42> 3.,1.i( Form 10-407 Revised 1212009 CONTINUED ON REVERSE 3.//./( Submit original only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? U Yes ± No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top 838' 837' and submit detailed test information per 20 AAC 25.071. Permafrost- Base 1681' 1668' Top West Sak 2331' 2297' Top Torok 7910' • 5010' None Top HRZ 10,310' ' 5760' Top Kuparuk C 11,323' 6031' Top Nuiqsut 12,056' 6169' Formation at total depth: 16,689' 6229' 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..- Title: Operations Drilling Engineer Signatur.• —..../s//1/111M Phone: 343-2186 Date: 2/14/2011 Well Name:ODSN-18 C '- mit No.:210-142 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 PI 0 N E E R current Schematic - State Well Name: ODSN-18 NATURAL RESOURCES HORIZONTAL-Sidetrack 5,2/14/2011 3:14:19 PM Well Attributes Vertical schematic(actual) API/UWI Field Name Well Status Total Depth(ftKB) 50-703-20624-00-00 000GURUK DRILLED 16,689.0 Casing Strings q 11 ii 158.0ftKB l' 'i Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(Ib/ft) 16 L Conductor 16 14.670 47.7 158.0 158.0 H40 Welded 109.00 Casing Components Top(TVD) Item# Item Des • Top(ftKB) (ftKB) OD(in) ID(in) Com 1-1;Conductor] 1-1 Casing Joints 47.7 47.7 16 14.67 0 Surface,3,600.0ftKB Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(Ib/ft) Surface 11 3/4 10.772 38.6 3,600.0 3,309.3 L-80 HYD 521 60.00 1-9;Tubing) 1- Casing Components p ) Item# Item Des Top(ftKB) To (TVD (ftKB) I OD(in) ID(in) Com 1-14;Tubing 2-5 Tam-Port Collar 537.1 537.0 11 3/4 10.77 2 2-10 Surface Shoe 3,598.2 3,308.2 11 3/4 10.77 2 7RIM= "Tie Back,8,307.9ftKB 1-18;Tubing Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(lb/ft) 7"Tie Back 7 6.276 37.8 8,307.9 L-80 Buttress 26.00 II 1 Thread 11-22;Tubing Casing Components Top(TVD) 11-26;Tubin tem# item Des Top(ftKB) (ftKB) OD(in) ID(in) Com g - 3-9•7"Tie Back 3-12'7"Tie Back 3-9 Weatherford SHR Hold 8,281.8 7 6.276 114 16-1;7"Drilling Liner Down Sub I �� 16-3;7"Drilling Liner '6-4;7"Drilling Liner 3-12 7"PBR Tie Back Seals 8,288.6 7.49 6.250 r. 7-1,Lower Lateral4 9-5/8"Drilling Liner,8,824.OftKB 11/2"Production Liner 7-2;Lower Lateral 4 Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(Ib/ft) 1/2"Production Liner 9-5/8"Drilling 9 5/8 8.835 3,319.7 8,824.0 5,329.1 L-80 HYD 521 40.00 7-4;Lower Lateral 4 Liner 1/2"Production Liner 7"Stuck Liner#1,11,202.OftKB T, 6-11;7"Drilling Liner Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(lb/ft) i —+ I7-7;Lower Lateral 4 L 1/2"Production Liner 7"Stuck Liner 7 6.276 8,475.3 11,202.0 6,048.7 L-80 HYD 511 26.00 7-9;Lower Lateral 4 #1 1/2"Production Liner -- 7-11;Lower Lateral 4 Casing Components 1/2"Production Liner Top(ND) 7-14;Lower Lateral 4 Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 1/2"Production Liner 5-12 7"Liner Shoe 11,200.0 6,048.2 7 6.276 "3 I. 7-17;Lower Lateral 4IIMI - -.- - :Gtr 1/2"Production Liner 7"Drilling Liner,12,090.0ftKB IIMI7-19;Lower Lateral 4 Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(lb/ft) inf. 1/2"Production Liner 7"Drilling Liner 7 6.276 8,288.6 12,090.0 6,174.6 L-80 Buttress 26.00 7-21;Lower Lateral 4 Thread 1/2"Production Liner 7-23;Lower Lateral 4 Casing Components MP' 1/2"Production Liner Top(ND) 7-25;Lower Lateral 4 Item#I Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn I 11/2"Production Liner 6-1 WTF PBR Tie Back Sleeve 8,288.6 8 1/4 7.500 .:GE' 7-27;Lower Lateral 4 1/2"Production Liner 'U`I7-29; Lower Lateral4 1/2"Production Liner6-3 WTF 7"x 9 5/8"TSP5H1 8,309.5 7 6.276 7-31;Lower Lateral 4 Liner Top Packer Ini 1/2"Production Liner 6-4 WTF 7"x 9 5/8"PHR Rot. 8,315.3 7 6.276 „G7-34;Lower Lateral 4 Liner Hanger 1/2"Production Liner iir 7-37;Lower Lateral 4 6-11 7"Liner Shoe 12,087.9 6,174.2 7 1/2"Production Liner • 7-39;Lower Lateral 4 Lower Lateral 4 1/2"Production Liner,16,400.0ftKB 1/2"Production Liner Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(lb/ft) "GGt' 7-41;Lower Lateral 4 Lower Lateral 4 1/2 3.958 11,915.5 16,400.0 6,232.5 L-80 Hydril 521 12.60 1/2"Production Liner 4 1/2" 111 7-43;Lower Lateral 4 1/2"Production Liner Production P, 7-45;Lower Lateral 4 Liner ; 1/2"Production Liner i Casing Components .:fir 7-48;Lower Lateral 4 1/2"Production Liner Top(ND) 7-51;Lower Lateral 4 Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn • 1/2"Production Liner 7-1 Tie Back Sleeve 11,915.5 6 +ter 7-53;Lower Lateral 4 7-2 NTH Packer 11,930.9 6.276 3.958 1/2"Production Liner oil-' 7-55;Lower Lateral 4 7-4 PHR Hanger 11,934.2 6.276 3.958 iiIr 1/2"Production Liner 7-7 Ported Sub 12,301.6 4 1/2 3.958 7-57;Lower Lateral 4 1/2"Production Liner Page 1/2 Report Printed: 2/14/2011 PIONEER current Schematic - State Well Name: ODSN-18 NATURAL RESOURCES HORIZONTAL-Sidetrack 5,2/14/2011 3:14:19 PM Casing Components Vertical schematic(actual) Item# Item Des TopTop(TVD) (ftKB) (ftKB) OD(in) ID(in) Corn it 7-9 Ported Sub 12,506.1 4 1/2 3.958 y 7-11 Ported Sub 12,627.8 4 1/2 3.958 Sµ!! 7-14 Resman Tracer Sub#3 12,795.4 4 1/2 3.958 7-17 Ported Sub 13,004.7 4 1/2 3.958 7-19 Ported Sub 13,168.2 6,207.1 4 1/2 3.958 [-H1-1;Conductor) 7-21 Ported Sub 13,535.2 6,216.7 4 1/2 3.958 7-23 Ported Sub 13,734.4 6,229.9 4 1/2 3.958 7-25 Ported Sub 13,934.1 6,233.4 4 1/2 3.958 7-27 Ported Sub 14,138.0 6,235.3 4 1/2 3.958 • 7-29 Ported Sub 14,299.6 6,238.8 4 1/2 3.958 11-9;Tubing' I- 7-31 Ported Sub 14,463.1 6,240.3 4 1/2 3.958 7-34 Resman Tracer Sub#2 14,708.7 6,236.6 4 1/2 3.958 11-14;Tubing 7-37 Ported Sub 14,839.7 6,237.7 4 1/2 3.958 7-39 Ported Sub 15,043.1 6,244.3 4 1/2 3.958 • 7-41 Ported Sub 15,247.2 6,241.5 4 1/2 3.958 7-43 Ported Sub 15,448.2 6,248.6 4 1/2 3.958 I 7-45 Ported Sub 15,648.4 6,251.4 4 1/2 3.958 11-18;Tubing 7-48 Resman Tracer Sub#1 15,814.7 6,242.8 4 1/2 3.958 7-51 Ported Sub 15,867.2 6,239.4 4 1/2 3.958 11-22;Tubing i 7-53 Ported Sub 16,029.0 6,231.5 4 1/2 3.958 7-55 Ported Sub 16,234.4 6,229.7 4 1/2 3.958 1-26;Tubing * 3-9;7"Tie Back 7-57 Eccentric Shoe 16,398.7 6,232.5 4 1/2 3.958 3-12;7"Tie Back I b.6-1;7"Drilling Liner Tubing Strings 6-3;7"Drilling Liner Tubing Description String M... ID(in) Top(ftKB) Set Depth(f...Set Dept...Wt(lb/ft) Grade Top Thread I' p6-4;7"Drilling Liner_ Tubing 4 1/2 3.958 34.1 11,916.0 12.60 L-80 HYD 521 r 7-1;Lower Lateral 4 1/2"Production Liner Tubing Components r 7-2;Lower Lateral 4 Top(TVD) • 1/2"Production Liner Item 4 Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 7-4;Lower Lateral 4 1-9 XXO SVLN 3.813 Pkr Bore 2,004.2 1,981.0 4 1/2 3.958 1/2"Production Liner 6-11;7"Drilling Liner I 7-7;Lower Lateral 4 1-14 GLM Assembly#1 2,215.6 2,185.5 4 1/2 3.958 it . '1/2"Production Liner 7-9;Lower Lateral 1-18 GLM Assembly#2 4,368.7 3,793.3 4 1/2 3.958. 1/2"Production Liner 1-22 GLM Assembly#3 7,277.0 4,792.2 4 1/2 3.958 7-11;Lower Lateral 4 1/2"Production Liner 1-26 XN Nipple 3.813 Pkr Bore 7,375.5 4,824.4 4 1/2 3.958 7-14;Lower Lateral `'`t 1-30 ROC Gauge and Carrier 11,811.9 6,159.5 4 1/2 3.958 1/2"Production Liner7-17;Lower Lateral 4 1-35 4 seal stack 11,911.0 4 1/2 3.958 1/2"Production Liner OM 7-19;Lower Lateral4 1-36 WFT Ratcheting Mule Shoe 11,913.8 4 1/2 3.958 •iEEt 11/2"Production Liner 7-21;Lower Lateral 4 11/2"Production Liner 7-23;Lower Lateral 4 . ; 1/2"Production Liner 7-25;Lower Lateral 4 MP 1/2"Production Liner !a a? f 7-27;Lower Lateral 4 • 1/2"Production Liner 'aw 7-29;Lower Lateral 4 1/2"Production Liner 7-31;Lower Lateral 4 M,. 1/2"Production Liner in, 7-34;Lower Lateral 4 1/2"Production Liner 7-37;Lower Lateral 4 1/2"Production Liner • 7-39;Lower Lateral 4 1/2"Production Liner l' t' 7-41;Lower Lateral 4 1/2"Production Liner 0.111.ifft' 7-43;Lower Lateral 4 M. 1/2"Production Liner l int' 7-45;Lower Lateral 4 1/2"Production Liner MEI r7-48;Lower Lateral 4 / 1/2"Production Liner • 7-51;Lower Lateral 4 1/2"Production Liner 7-53;Lower Lateral 4 r 1/2"Production Liner / 7-55;Lower Lateral 4 ,�3 m/1/2"Production Liner ru7-57;Lower Lateral 4 p /1/2"Production Liner Page 2/2 Report Printed: 2/14/2011 Pioneer Natural Resources Alaska Inc. ODSN-18 Page 3 Form 10-407, Well Completion or Recompletion Report and Log Attachment Box #24 24. Open to production or injection 4-1/2", 12.6#, L-80 Hyd 521 Uncemented Liner Perforated Pups w/ 6-1/2" Holes @ depths listed: MD TVD 12,302' - 12,306' 6201' - 6202' 12,506' - 12,511' 6222' - 6222' 12,628' - 12,632' 6225' - 6225' 13,005' - 13,009' 6211' - 6211' 13,168' - 13,173' 6207' - 6207' 13,535' - 13,540' 6217' - 6217' 13,734' - 13,739' 6230' - 6230' 13,934' - 13,939' 6233' - 6233' 14,138' - 14,143' 6235' - 6235' 14,300' - 14,304' 6239' - 6239' 14,463' - 14,468' 6242' - 6242' 14,840' - 14,844' 6238' - 6238' 15,043' - 15,048' 6244' - 6244' 15,247' - 15,252' 6242' - 6242' 15,448' - 15,453' 6249' - 6249' 15,648' - 15,653' 6251' - 6251' 15,867' - 15,872' 6239' - 6239' 16,029' - 16,034' 6232' - 6231' 16,234' - 16,239' 6230' - 6230' PIONEER C ations Summary Report - State NATURA1 RFSOU_RCFS Well Name: ODSN-18 Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: DEVELOPMENT DRILL Start Date: 10/24/2010 End Date: Start Depth Foot/Meters Dena Lest Start Date End Date (ftita) (ft) Mud(lbigal) Sunimaly 10/24/2010 10/25/2010 0.0 8.80 Skid rig from ODSN-17 to ODSN-18,move subs and pits and level same.RU Nabors 19AC on ODSN-18.Rig accepted ODSN-18 on 10/24/10 @ 00:00 hrs. NU starting head and drilling riser. RU Gyro survey shieves and tools.PU mud motor and adjust same. MU bit,motor and stabilzer, fill all lines and hole-check all lines and stack for leaks. 10/25/2010 10/26/2010 158.0 1,108.00 9.10 Ream out conductor f/66't/158.Drill 14-1/2"new hole f/158"t/223'.PU and MU directional BHA and TIH with same.Directional drill 14-1/2"hole f/223't/1,266'. 10/26/2010 10/27/2010 1,266.0 1,270.00 9.2Q Directional drill 14-1/2"hole f/1,266'1/1,648.PU and MU EM repeater sub into string.RD Gyro survey equipment.Directional drill 14-1/2"hole f/1,648't/2,441'.Pump 60 bbls hi-vis weighted sweep and circulate hole clean with same.POOH f/2,441'1/141'.TIH f/141'112,441'.Directional drill 14/1-2"hole f/2,441'112,536'. 10/27/2010 10/28/2010 2,636.0 1,079.00 9.30 nitfizaidnell dri1L14-1/2"heft ft2.536"1/3,583'.Directional drill 14-1/2"hole f/3,583't/3,615'.Pump 60 bbls hi-vis weighted sweep and circulate hole clean with same.POOH f/3,615'1/1,964'.TIH f/1,964'113,615'.Pump 60 bbls hi-vis weighted sweep and circulate out same while conditioning mud to run casing.POOH f/3,615't/surface. 10/28/2010 10/29/2010 3,615.0 9.60 RU 11-3/4"casing equipment and fill up tool. 13IH with 11-3/4'60#L-80 HYD 521 casing f/ surface 1/3,600'. RD fill-up tool,casing tongs and scaffolding.RU cement head and lines. Circulate hole clean for cement job.Swap over to Halliburton,pump 20 bbls seawater,release 1st bottom plug and kick out w/last 2 bbls,test lines to 4000 psi. Load top plug,pump 60 bbls 16-k" 10.0 ppg spacer,pump 337.6 bbls(457 sx)Lead Cement at 10.7 ppg(type Permafrost"L"w/ yield of 4.15).Drop 2nd bottom plug.Pump 96 bbls(404 sx)Tail Cement at 15.8 ppg(Premium "G"w/yield of 1.19). Release top plug-kick out w/20 bbls seawater.Displace w/388 bbls 9.6 \% ppg spud mud using rig pumps 10 bpm, 1600 psi,had to slow rate to 4 bpm when cement returns got to surface.Bumped plug at 3 bpm with 800 psi and pressured up to 1200 psi when plug failed.?31 bbls cement returned to surface.Cement in place at 19:00 hrs.Check floats- holding.RD cement head and lines.Flush cement from flow line,riser,and drip pan. ND drilling riser. 10/29/2010 10/30/2010 3,615.0 9.60 ND drilling riser and spacer$00018;NI)drilling .' drilling and BOP equipment,Prep rig floor to pick up DP from pipe Shed.TIH ft Stafa ,C0 ,'!4,-1''OiCking up 5"DP from pipe Shed and rack back same in derrick,Test BOPE oar AOSCC&PXQ miles and regulations.Teat BOPE w/5"test joint to 250 psi low/4600 pal high.Test annular w15'test joint to 250pa1 low 12500 psi high.Test all floor valves to,250 psi low/4500 psi high.Test choke manifold to 250 psi low/ 4500 psi high.Closure pressure 2,950;2,025 after closure,200 psi=22 sec,full pressure 1:50. All tests charted and all test held for 5 min.Test witnessed by AOGCC Rep.Lou Grimaldi.Close blind rams and test casing to 3500 psi held 30 min on chart-good test.TIH f/surface t/3,340' picking up 5"DP from pipe shed.Circulate 1.5 times DP capacity.POOH f/3,340't/surface and LD mule shoe. Wae, 10/30/2010 10/31/2010 3,615.0 20.00 9.80 MU clean out BHA#2.TIH f/529'1/3,385'picking up 5"DP from pipe shed.Circulate 1.5 times DP capacity. POOH f/3,385'1/1,766'.TIH f/1,766'113,385'picking up 5"DP from pipe shed.Wash f/3,385'113,514'-tagged cement plugs.Drilling cement and float equipment f/3 514't/3_615'. Directional drilling f/3,615'113,635'.Perform leak off test at 3,600'md/3,309'tvd with 9.6 peg mud to 880ysi for EMW of 14.7 ppq.Displace well from 9.6 ppg spud mud to 9.8 ppg LSND.POOH f/3,635'U surface.PU directional BHA#3 f/surface 1178'. 10/31/2010 11/1/2010 3,635.0 1,646.00 9.70 PU directional BHA#3 t/618'and shallow pulse test same-good test.TIH f/618113,567'. Wash and ream f/3,567'113,635'.Directional drillino f/3836't13:700'.Drop 1-5/8"ball and pump ball on seat and sheer ball seat to engage under reamer cutters-did not see ball seat sheer. Raise pump rate to 700 gpm to fully expand cutter blades and pull 10k against the casing shoe to ensure cutters engaged.Turn pumps off and pull reamer back into casing shoe to ensure cutters relaxed.Seen increase in torque and 230 psi decrease in pump pressure to ensure blades are open.Directional drilling f/3,700't/5,280'. . 11/1/2010 11/2/2010 5,280.0 1,020.00 10.00 Directional drill 11-3/4"new hole f15,280'116,300'. 11/2/2010 11/3/2010 6,300.0 1,360.00 10.00 Directional drill 11-3/4"new hole f/6,300'1/6,327'.Rack back 1 std f/6,327'1/6,232'. Reciprocate pipe f/6,232't/6,177'while clearing debris from GEHO pump. Wash and ream f/6,232'1/6,327'. Directional drill 11-3/4"new hole f/6,327'1/7,660. Page 1/10 Report Printed: 2/14/2011 P I 0 N E E R C 'ations Summary Report - State NATURAL RFSOURCFS Start Depth Foot/Meters Dens Last Start Date End Date (RKB) (ft) Mud(W/gal) Summary 11/3/2010 11/4/2010 7,660.0 1,479.00 9.85 Directional drill 11-3/4"new hole f/7,660't19,139'(10-5/8"Intermediate#1 TD). -Pump H.V.sweep around -Circulate hole clean 11/4/2010 11/5/2010 9,139.0 0.00 10.00 Circ hole clean at 9,139'(Int#1 TD).POOH on elevators f/9,139't/6,100'.Pump weighted sweeps and clean up hole f/6,100'.Backream out of hole f/6,100't/3,600'(inside 11-3/4'casing). Circ hole clean.POOH t/3,167'.Circ hole clean.RIH t/3,567'.Drop 2"deactivation ball. Qgactivate Rhi[u�Rgamerw/1500psi shear Drop 2-3/4"drift.POOH t/3,282'.CBU 2x due to overpull.POOH t/2,140'.Pump weighted sweep and CBU 2-1/2 times.POOH to BHA.CBU 2x. LD BHA. 11/5/2010 11/6/2010 9,139.0 0.00 9.80 Continue LD BHA#3.PU 8"DC's from shed to±270'.Circ pipe vol+. POOH stand back DC's. Install test plug._Change bottom rams to 9-5/8".Test bottom 9-5/8"rams to 250 psi low/4500 psi high for 5 charted min each test.Function test other BOPE per AOGCC weekly requirements. Pull test plug.RU to run 9-5/8"drilling liner.Ran 9-5/8"40#L-80 Hyd.521 casing f/surface t/4,322'. NOTE:AOGCC was notified of upcoming BOP test at 20:00 hrs on 11/04/10.AOGCC Rep.John Crisp waived right to witness test at 05:30 on 11/05/10. 11/6/2010 11/7/2010 9,139.0 0.00 9.85 RIH w!9-5/8"liner f/4,322't/5,661'.RD casing equip.RU and run liner on 5"DP t/8,524'.Tight at 8,524'.Work liner down w/2 to 2-1/2 turns rotation t/8,824'.Stacking weight at 8,824'.Break circulation and drop liner setting ball. Establish circulation with 1/2 bpm and increase pump rate to 4 bpm. Pump down w/4 bpm,940 psi.Observe ball on seat but no shear with leak by- '•i � attempt to shear LC seat with 10.5 bpm and 3500 psi with no success Prepare and pump 87.6 bbls lead Class'0'lead 12.5 ppg cement followed by 50.3 bbls tail cement.Observed cement 511. Gat' returns at surface.w/80 bbls displacement which indicated liner compromised and leak by at liner top or below.Decision to circulate cement out of hole. 11/7/2010 11/8/2010 9,139.0 0.00 9.80 Continue to displace cement out of well and pump total calculated strokes to bump plug. Attempt to set liner top packer. PU to up wt.+ 12'to expose setting"dogs".Slack off and attempt to set down weight. Pipe sat down at original depth. PU to up wt.+15'and attempt to set down w/no success. Rotate down w/10 rpm-Torqued up and stalled w/10k torque. PU and observe overpull to 325k. Appeared to have screwed into connection.Set down to 70k. Attempt to release f/liner w/right hand rotation. Stalled out w/15k torque. Break circ.w/6 bpm, 1400 psi in attempt to bump plug. Pumped 4500 stks w/no bump. Attempt to release from hanger w/ R.H.rotation-no success.PU to 195k and pipe pulled free. Up wt at 170k. POOH 10 stds.Slip &Cut Drilling line.POOH and LD liner hanger and 4 jts of 9-5/8"casing-pin galled with signs of wash. Change lower rams to 2 7/8"x 5"vbr. Test same to 250 psi low/4500 high f/5 charted same. PU Cleanout BHA. RIH t12,893'. 11/8/2010 11/9/2010 9,139.0 0.00 9.80 Continue RIH w/clean out BHA t/3,274'.Enter 9-5/8"liner top at±3,321 and-no issues.RIH and take weig-fir at 3,460'.Pushing plug down w/10-25k wt to 3,495'.Stacked out.Break circ and continue wash down pushing plug t/4,135'.Stop RIH&CBU circ out cement contaminated mud. RIH on elevators f/4,135'and tag landing collar at 8,700'.Clean out landing collar,float collar (8,739')and shoe(8,824').Wash down t/8,830'. LD clean out BHA.MU HES FASdrill squeeze packer and RIH t/1,145'md. 11/9/2010 11/10/2010 9,139.0 0.00 9.80 Continue RIH w/Fasdrill plug t/8,800'.Set plug at 8,800'.Circulate through Fasdrill and up 9-5/8" x 11-3/4"annulus staging pumps slowly to 5 bpm.RU and pump 22 bbls 15.8 ppq Class"G" cement around 9-5/8"x 11-3/4"annulus. Unsting and spot 3 bbls cement on top of plug(165 sx total).CBU.POOH.PU Fasdrill plug#2.RIH t/576'. 11/10/2010 11/11/2010 9,139.0 0.00 9.85 Continue RIH w/FASdrill packer#2 t/3,340'.Break circ w/4 bpm, 140 psi and wash past setting depth.Spot Fasdrill at 3,340'.Attempt to set plug w/25 turns right.No overpull observed. Attempt to set 2 more times w/no success.PU single and spot plug in next jt down at 3,372'. Attempt to set w/no success.Attempt to set plug at several intervals while working back up hole. No success.Pull Fasdrill out of 9-5/8"15'.Slack off in attempt to tag.No tag.Attempt same 1 more time.POOH.LD Fasdrill.PU spear to catch 9-5/8".RIH.Take weight at 545'.POOH.PU 10-5/8"bit&cleanout assembly.RIH and wash f/140't/3,310'.Tag top of liner to verify depth at 3,320'.CBU.POOH to BHA.Install TIW valve and monitor well while doing draw-works maintenance.Continue POOH&LD BHA.PU Spear to catch 9-5/8".RIH t/386'. Page 2/10 Report Printed: 2/14/2011 P I 0 N E E R C ations Summary Report - State NATURALRFSOIIRCFS Start Depth Foot/Meters Dens Last Start Date End Date (ftKS) (ft) Mud pblgai) Summary 11/11/2010 11/12/2010 9,139.0 0.00 9.90 RIH w/spear assembly to±3280'.Enter 9-5/8"at 3,320'&engage grapple.PU to 20K over, PU to 70K over(200K).Slackoff to 50K over. Put 1 Right hand turn in pipe&work torque down by working pipe 50K-95K over several times. Put 1 turn in(12K tq)and work torque down.Put 1/4 turn in and work down(total 2-1/4 turns).Release torque.Got 2 turns back.Pull to 300K(170K over).Release spear&POOH.PU FasDrill squeeze packer.RIH 113,340'(Top 9-5/8"at 3,320'). Spot Fasdrill at 3,340'on upstroke.Set packer.Sting into Fasdrill.Stack 28k down weight on plug.Test 9-5/8"casing between Fasdrill plugs at 3,340'&8,800'._Pressure to 3500 psi on chart. Initial pressure loss,250 psi in 5 min.Pressure up to 3500 psi.Pressure bled down to 2000 psi in 40 min.Pressure up to 3500 psi.Pressure bled to 1950 psi in 50 min.Unsting f/plug.PU 6'to 3,334'.RU cement lines/equipment. Pressure up in 1/2 bpm increments to establish injection rate.Pressure broke over at 890 psi. Inject to formation w/1-3 bpm,800-1020 psi. Pump 30 bbls 15.8 ppg Class"G"cement.Displace cement out of DP w/48 bbls 9.9 ppg LSND. POOH 5 stds. Squeeze cement into 9 5/8"x 11 3/4"annulus.Pump 12 bbls at 3 bpm.-ICP=1300 psi-FCP= 1100 psi.Pumped 1 bbl at 1/2 bpm, 1543 psi-Bled to 1487 psi.Bleed press.Open rams.Circ. w/8 bpm,600 psi.Close rams.Squeeze 2 bbls away at 1/2 bpm, 1525 psi. Bleed pressure-1 bbls back.Total of 14 bbls squeezed.9-5/8"x 11-3/4"annular volume=6.35 bbls.CBU w/8 bpm,300 psi.CIP @ 18:00 hrs. POOH f/2,855't/1,716'. NOTE:AOGCC was notified of upcoming BOP test at 09:00 hrs on 11/11/10.At 09:30 hrs, AOGCC Rep.Chuck Scheve waived witness of test. 11/12/2010 11/13/2010 9,139.0 9.95 `Slurry composition&weights for 9-5/8"x 11-3/4"liner lap 15.8 ppg Class'G'cement:Seawater; 5.12 GPS,Premium cement;94 lbs/sk,Calcium Chloride;2.00 BWOC,CFR-3;.20 BWOC,Add. Calcium chloride;1.00 BWOC;Add.CFR-3; .30 BWOC,HALAD; .50 BWOC. POOH w/Fasdrill stinger f/1,716'U surface.PU 10-5/8"clean out assembly.RIH to±3073'.WOC 1 hr.Wash down f/3,073'113,213'.Hard tag cement at 3,213'.Drill cement f/3,213't/3,31- 3' above 9-5/8"liner top).Circulate hole clean.Test 9-5/8'x 11-3/4"liner lap to 2500 psi for 30 charted min.Good test.POOH.LD BHA.ND BOPE and set back.ND spacer spool and drilling spool.NU multi-bowl.Test multibowl seals to 5000 psi for 10 min.Good test.NU BOP stack and MPD flange.Install test plug and RU to test BOPE. Test BOPE per AOGCC&PXD rules®ulations. "(r) Test blind rams to 250 psi low/4500 psi high for 5 charted min each test. .bp to witness test waived by AOGCC Rep.Chuck Scheve at 09:30 on 11/11/10. 11/13/2010 11/14/2010 9,139.0 9.95 Continue to test BOPE per AOGCC&PXD rules®ulations.Test BOPE w/5"&4"test joint to 250 psi low/4500 psi high.Test annular w/5"&4"test joint to 250psi 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.Accum test:Sys.press.2,750; 1950 after closure,200 psi=20 sec,full pressure 1: 53. All tests charted and all test held for 5 min. Encountered 3 failures:2 on lower kelly valve, 1 on upper kelly valve.All 3 failures were corrected and re-tests were good. Right to witness test waived by AOGCC Rep.Chuck Scheve at 09:30 on 11/11/10. PU clean out BHA.RIH and tag cement at 3317'.Drilling cement f/3,317'113,340'_9-5/8"liner top at 3,320'). Drilling FasDrill plug f/3,340't13,344'.Plug fell.Push plug to 3,359'.Circ hole clean. Continue RIH 116,214'. 11/14/2010 11/15/2010 9,139.0 20.00 10.00 Continue RIH w/8-1/2"clean out BHA f/6,214'118,744'.Tag cement at 8744'.Drill cement and tag FasDrill plug at 8,800'.Drill FasDrill and clean out to 9-5/8"shoe at 8,824'.Approx 2'of cement inside shoe.Wash&ream 118,850'.POOH to shoe.Circulate hole clean until MW in/out 10.0 ppg.Perform FIT to 14.0 ppg EMW.TVD at shoe=5,329'-MW=10.0 ppg-Press.applied =1110 psi.Wash&ream(/8,824'119,139'(10-5/8"TD).Drill 20'new hole 119,159'.Circ hole clean.Perform FIT to 14.0 ppg EMW.TVD at shoe=5,329'-MW= 10.0 ppg-Press.applied= 1110 psi.POOH.LD clean out BHA.PU BHA#13.RIH 115,025'. 11/15/2010 11/16/2010 9,159.0 755.00 10.10 Continue RIH f/5,025'118,929'. Drop reamer activation ball.Shear reamer seat w/1900 psi.Pull test reamer against 9-5/8"shoe w/10k over pull. Pull into shoe and remove trip nipple. Install RCD head.Wash&ream f/8,824't/9,159'. Directional drill f19,159'119,914'. 11/16/2010 11/17/2010 9,914.0 1,109.00 10.00 Directional drill f/9,914'U10,803'.Circulate hole clean.Directional drill f/10,803'1111,023'. 11/17/2010 11/18/2010 11,023.0 867.00 10.00 Directional drill(/11,023'U11,890'(Intermediate 2 TD).Circ H.V.weighted sweeps around x2. POOH backreaming f/11,890'U11,309'. Page 3/10 Report Printed: 2/14/2011 PIONEER C ations Summary Report - State NATU : SOURCES Start Depth Foot/Meters Dens Last Start Date _ End Date (ftKB) _ (ft) Mud(Ib/gap Summary _ 11/18/2010 11/19/2010 11,890.0 0.00 10.20 Back ream out of hole f/11,309'1/11,080'with multiple pack off events.Attempt to stage up pumps to 600 gpm with hole packed off at 11,080'.Wash in the hole f/11,080'1/11,890'. Establish circulation using step rate method,stage up pumps and rotary to circulate the hole clean with 40 bbl Hi-vis- weighted sweeps x2.Back ream out of hole f/11,890'1/11,245'with multiple pack off events.Close annular and trap annulus pressure,and change out RCD bearing due to leaking hyd seal on bearing.Back ream out of hole f/11,245'1/11,007'. 11/19/2010 11/20/2010 11,890.0 0.00 10.20 Back ream out of hole f/11,007'1/10,007'.Circulate the hole clean with a 45 bbl Hi-vis- weighted sweep.TIH f/10,007'1/8,769'.Slip and cut 58'of drill line.TIH f/8,769'1/10,803'.Ream in the hole f/10,803'1/11,435'with slow pumps and rotary. 11/20/2010 11/21/2010 11,890.0 0.00 12.80 TIH f/11,435'1/11,890'.Circulate the hole clean with a 45 bbl Hi-vis- weighted sweep. POOH (/11,890'U10,768'.TIH f/10,768'1/11,890'. Circulate the hole clean with a 45 bbl Hi-vis- weighted sweep.Circulate raising mud wt.from 10.2 ppg to 12.8 ppg.Remove RCD bearing and install trip nipple.Circulate raising mud wt.from 10.2 ppg to 12.8 ppg. POOH f/11,890'U553'on J� elevators.Function test BOP equipment as per AOGCC PTD.LD directional BHA. �(,d` 11/21/2010 11/22/2010 11,890.0 0.00 12.60 Plug in and download all LWD data.Finish laying down remainder of BHA.Pull wear ring and install test plug.Change out lower rams from VBR's to 7"casing rams and test same to 250 psi low/4500 psi high.Test held 5 min each and charted.RD testing equipment.RU 7"casing equipment and fill-up tool.Held PJSM with all personnel involved.RIH with 7"26#4-80 HYD 511, liner fl surface 1/3,177'.RD fill up tool and casing equipment.RU 5"handling tools.PU and MU PHR hydraulic setting hanger with liner top packer f/3,177'1/3,229'.TIN with 7"liner on 5"DP f/3,229'U8,652'.Circulate liner volume at 9-5/8"casing shoe.TIN with 7"liner on 5"DP f/8,652' U10,253'. 11/22/2010 11/23/2010 11,890.0 0.00 12.80 TIH with 7"liner on 5"DP f/10,253'1/10,820'. Establish circulation while reciprocating pipe and torque and slump.TIH with 7"liner on 5"DP f/10,820'011,202'.Rack back stand and attempt to free pipe-unsuccessful.Pick single from pipe shed and continue to torque and slump in attempt to free pipe while mixing black magic pill.Continue to attempt to free pipe while spotting black magic pill.Continue to torque and slump every 15 min in attempt to free pipe.Pump 1 bbl of black magic out of shoe every hour. 11/23/2010 11/24/2010 11,890.0 0.00 10.50 Continue to torque and slump in attempt to free pipe.Continue to attempt to free pipe while spotting black magic pill up the hole at the 9-5/8"casing shoe at 8,824'to 9,600'.Continue to torque and slump in attempt to free pipe while circulating and cutting back mud weight from 12.8 ppg to 10.5 ppg.Remove trip nipple and install RCD bearing. 11/24/2010 11/25/2010 11,890.0 0.00 10.50 Continue to torque and slump in attempt to free pipe.Remove RCD bearing and install trip nipple.Emergency release from liner hanger andpacker. Top of fish at 7,991'.RU cement lines and held PJSM.Pump 10 bbls seawater,test lines to 4000 psi. Pump 35 bbls Tail Cmt at 15.8 ppg(Premium"G"w/yield of 1.18,+.07%Halad-344,+.45%SCR-100,+.2%CFR-3,+.25 "ii lbs/sk Super CBL).Chase with 10 bbls seawater. Displace w/246 bbls 10.5 ppg mud using rig '7 pumps 5 bpm, 1,760 psi.Cement in place at 11:00 hrs. Lost 170 bbls while displacing cement. Monitor well--gained 16 bbls.PU f/7,991'07,931'to unsung from liner and CBU. Hole gave back 18 bbls while CBU. POOH(/7,931'1/7,741'. Pulled 2 stands with no fill. Monitor well for 1 hour with 9 bbls gained.Circulate 1.25x bottoms up at 7,741'. Hole gave back 2 bbls while circulating. Monitor well--Gained 1.5 bbls over 30 min period.POOH f/7,741'U surface. Monitor well every 10 stands--Static.Change out handling tools to 4". PU mechainical cutter BHA f/surface t/44'. 11/25/2010 11/26/2010 11,890.0 10.50 TIH f/44'1/9,078'.Cut T'liner at 9,078'with mechanical cutter.Circulate bottoms up at 9,078'. POOH f/9,078'U surface.TIH picking up casing spear BHA f/surface U331'.TIN f/331'U7,991'. Establish circulation,observe pack off enter liner top at 8,014',shut down pump and No-Go on liner top at 8,033'. Latch onto fish,bleed down jars and fully engage spear with 400k pull.Jar on fish with 150k overpull at 360k. 11/26/2010 11/27/2010 11,890.0 10.50 Continue to free stuck casing by jarring and attempting to circulate. Inspect derrick while pumping dry job and POOH f/8,033'U surface.TIH f/surface 08,941 with mechanical cutter.Cut 7"liner at 8,948'with mechanical cutter.POOH f/8,948'U surface.PU casing spear BHA and TIH f/surface 1/7,791'.Establish circulation,observe pack off enter liner top at 8,014',shut down pump,and No-Go on liner top at 8,033'. Latch onto fish,bleed down jars and fully engage spear with 300k pull. Page 4/10 Report Printed: 2/14/2011 P I 0 N E E R Q ations Summary Report - State NATURAI JRFSOUROFS Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(tb/gal) Summary 11/27/2010 11/28/2010 11,890.0 10.50 Reciprocate pipe in attempt to establish circulation-unsuccessful.Attempt to free stuck casing by jarring and pulling up to 515k-unsuccessful.Release grapple and pull±/7,941'.Service rig and top drive,inspect top drive and derrick. POOH f/7,941't/surface.Remove wear bushing and install test plug.Test BOPE per AOGCC rules and regulations.Test BOPE w/4"test joint to 250 psi low and 4500 psi high.Test annular w/4"test joint to 250psi low and 2500 psi high.Test all floor valves to 250 psi low and 4500 psi high.Test choke manifold to 250 psi low and 4500 psi n T high.Test lower 7"rams w/7"test joint to 250 psi low and 4500 psi high.Closure pressure 2950/ ` 1950 after closure,200 psi=24 sec,full pressure 1:53. All tests charted and all test held for 5 min.Test witness waived by AOGCC Rep.John Crisp at 18:10 hrs on 11/26/10. Remove test plug and install wear bushing.TIH picking up cutter assembly f/surface t/368'. 11/28/2010 11/29/2010 11,890.0 10.50 TIH with cutter assemb>y f/368't18 475'.;Cut 7" er.at,8 475 with mechanical cutter.POOH f/8,475'U surface and LD mechanical cutter.PU casing spear BHA,and TIH f/surface t17,991. Establish circulation,observe pack off enter liner top at 8,014',shut down pump and No-Go on liner top at 8,033'.Latch onto fish and fully engage spear with 300k pull.Circulate at 1/2 bpm at 950 psi with limited returns.Jar on pipe with 200k over pull and pipe Caine free.POOH f/8,029,' tf722'with fish. 11/29/2010 11/30/2010 11,890.0 10.55 POOH f/722't/485'with fish. Release spear, LD spear assembly and 7"casing hanger with packer.Clear all fishing tools from rig floor and RU 7"casing equipment to LD fish. POOH f/485' t/surface laying down fish.RD casing equipment.PU casing scraper BHA and TIH f/surface .. 1/3,200'.Wash and ream f/3.200't/3.340'.Tit-If/3,340'07,800'.Wash and ream f/7,800'08,475'. Pumped 2x 40 bbl hi-vis weighted sweep and CBU 3x. POOH f/8,475'±/1,080'. 11/30/2010 12/1/2010 11,890.0 10.50 POOH f/1,080'U surface.Remove wear bushing and install junk screen wear bushing.Function all rams on BOP stack and flush stack.Pull junk screen and install wear bushing.PU casing spear BHA and TIH f/surface 08,475'.Establish circulation and No-Go on top of fish at 8,475'. Latch onto fish and fully engage spear with 300k pull.Jar on pipe with 200k over pull. Inspect derrick and top drive after jarring prior to POOH.POOH f18,475'1/49'. 12/1/2010 12/2/2010 11,890.0 10.50 Continue LD spear assembly.RIH w/11 stds.4"DP.POOH LD same.Change lower rams to 2- 7/8"x 5"variables.Test lower rams to 250 psi low and 4500 psi high f/5 charted min.each test. PU EZDrill bridge plug and RIH.Set EZDriII at 8,460'.Test 9-5/8"x 11-3/4"casing to 1500 psi f/ 30 charted min.Good test.POOH,LD running tool.PU whipstock assembly and RIH 1/1,050'. C 12/2/2010 12/3/2010 8,438.0 35.00 10.10 Continue to RIH w/9-5/8"whipstock f/1,050't/8,409'.Break circulation and orient whipstock face__ to to 5T°leftTag bndge.plug at 8,460'..Set bottom trip anchor and shear mills off of slide.Mill window f/8,438't8 455 Drill open hole f/8,455'08 473'to-clear upper string mill off of slide__ T.O.W.at 8,438'(5,195'TVD).B.O.W.at 8,455'.Circulate hole clean wf H.V.sweeps.Perform FIT to 13.6 ppg EMW.TVD 5,195'.MW 10.1 ppg.950 psi applied=13.6 ppg EMW FIT Slip drilling line.Service rig.POOH f/8,400'07,997'. 76 +f/ 12/3/2010 12/4/2010 8,473.0 107.00 10.10 Continue POOH f/7,997't/surface.LD milling BHA and inspect mills. Flush iron cuttings f/BOP! stack. PU BHA#24. RIH to±8,400'.Orient motor to 57°left.Work through window f/8,438' 08,455'.Work down to open hole TD at 8,473'. Directional drilling(/8,473'08,580'. 12/4/2010 12/5/2010 8,580.0 177.00 10,05_Directional driiling_ff8 612't/8,757'.POOH above window.CBU.POOH.LD motor BHA.PU 75 its.5"DP f/pipe shed to±2,380'.Circ pipe volume.POOH stand back DP.Function test BOPE per AOGCC weekly requirements.PU RSS BHA t/536'. 12/5/2010 12/6/2010 8,757.0 653.00 10.05 Shallow pulse test MWD at 536'. RIH 04,344'. Break in Geo-Pilot and pulse test MWD. RIH 08,342'.Pull trip nipple. Install RCD head.Go through window f/8,438'08,455'.Continue RIH 200 ft/hr for mad pass t/8,723'.Drop reamer activation ball. Shear same.Wash&ream ff8,723' 08,757' lirectinnal drill ff8.757'1/9 410'. 12/6/2010 12/7/2010 9,410.0 1,058.00 10.05 Directional drilling f/9,410'010,468'. 12/7/2010 12/8/2010 10,468.0 1,264.00 10.10 Directional drilling f/10,468'011,481'.Circulate and condition mud.Directional drill f/11,481' t/11,732'. Page 5/10 Report Printed: 2/14/2011 P I 0 N E E R Q ations Summary Report - State 1AT IRAC RESOURCFS Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 12/8/2010 12/9/2010 11,732.0 368.00 10.20 Directional drill f/11,732't/12,100'(Int.2 TD).Deactivate Rhino reamer,circulate hole clean. • Ream 8-1/2"pilot hole w/Geo-Pilot.Circ H.V.sweep surface to surface.POOH f112,100' - y.v t/8,433'(above window).Slip&cut drilling line. RIH f/8,433'1111,008'. - i ° 12/9/2010 12/10/2010 12,100.0 13.10 Continue RIH t/12,100'.Pump H.V.sweep surface to surface.Continue to circ while preping pits and weighting up to 13.0 ppg LSND.Displce well w/13.0 ppg LSND mud.Pull RCD bearing. Install trip nipple.Pump out of hole 3 bbls per stand f/12,100,to window at 8,438'.Continue POOH on elevators f/8,438'11170'. NOTE:AOGCC was given±48 hrs notice of upcoming BOP test at 16:00 hrs on 12/9/2010. AOGCC Rep.Bob Noble waived witness of test at 18:00 hrs on 12/9/2010. o,' 12/10/2010 12/11/2010 12,100.0 13.00 Continue LD drilling BHA.Pull wear ring.Install Test plug.Change bottom rams to 7".Test bottom rams to 250 psi low/4500 high for 5 charted min each test.Pull test plug. Install wear ring.RU and run 7"26#L-80 liner 1112,090'.PU cement head.RU to circ. 12/11/2010 12/12/2010 12,100.0 10.20 Spot liner shoe at 12.090'.Break circ. Displace DP and liner w/10.2 ppg LSND mud.Drop hanger setting ball.Continue to displace well w/10.2 ppg LSND.Seat ball and observe shear w/ 3400 psi.PU to confirm running tool released.Line up cementers. ,Pt,twp?0._IDbls_seawater.Test lines to 4000 psi.Pump 40 bbls Dual Spacer at 12.5 ppg.Pump. 34 bbls Class"G"cement at 15.5 ppg w/1.18 yield. — /v� Additives: .07%HALAD 344-.4%SCR-100-.25#/sk Super CBL&.2%CFR-3. - it Drop top plug and kick out w/20 bbls seawater.Displace cement w/rig pumps.Bump plug w/ 3500 psi.Hold pressure f/10 charted min.Bleed pressure.Check floats.OK.Pull seals from liner top.Set liner top packer.CBtl..Test 9 5/8"xr 7".liner lap to 2500 psi for 30 charted minim test.7"liner top at 8,288'.Liner shoe at 12,090'.POOH LD DP and running tool.RU to test BOPE. Test BOPE per AOGCC Permit to drill.Test annular w/4"test joint to 250psi low/2500 psi high. Right to witness test waived by AOGCC Rep.Bob Noble at 18:00 hrs.on 12/09/10. 12/12/2010 12/13/2010 12,100.0 10.20 Cont test BOPE per AOGCC Permit to drill.Test BOPE w/4"test joint to 250 psi low/4500 psi high.Test annular w/4"test joint to 250psi 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.Test lower 7"rams w/7"test joint to 250 psi low/4500 psi high. Perform accumulator test.Closure pressure 2900; 1950 after closure,200 psi= 19 sec.Full pressure 1 min 28 sec.All tests charted and all test held for 5 min. Right to witness waived by AOGCC Rep.Bob Noble at 18:00 hrs on 12/09/10.RU and run 7" 7 26#L-80 BTC-M tieback string to top of 7"liner at 8,288'.Work seal assembly into SBR and Ef ' -bottom out locator sub on liner top at 8,288'.PU 10'.Close annular and pressure up on 9-5/8"x annulus to 2500 psi to verify seals hold-good test.LD 3 jts.7"casing.Space out w/pup its and hanger.Slack off and attempt to re-enter SBR w/seal assembly.No success. LD landing X“ joint and hanger.PU 1 jt 7"and attempt to work torque downhole and enter SBR-no success. 12/13/2010 12/14/2010 12,100.0 10.20 MU 4-1/2"IF x 7"BTC XO into Top Drive and casing.Rotate casing and enter SBR at 8288'. Push seals in w/75k down weight to±8294'. Pull out of SBR WI 50k overpull.Attempt to re-enter SBR w/no success.POOH LD 7"casing f/8,288'116,381'.Attempt to work through tight spot at 6,381'with no success.RIH w/7"casing f/6,381'118,145'.Work tight spot f/8,145'118,162'.RIH w/ 7"casing f/8,145'118,280'(8'above liner top).Mix 200 bbls 10.2 ppg MOBM for freeze protect fluid.Pump 163 bbls of MOBM down annulus to 2500'MD.Rotate 7"casing and enter SBR wl seals.Work seals down and bottom out locator sub on liner top at 8,288'.Bottom of seals at 8,307'.Pressure test 9-5/8"x 7"annulus to 2500 psi for 30 charted min-Good test.Pressure test 7"casing to 3500 psi f/30 charted min-Good test.Prep to ND BOPE and set emergency slips. 12/14/2010 12/15/2010 12,100.0 10.20 ND BOPE. PU BOPE.Set Vetco emergency slips on 7"casing with 160k string weight.Cut casing w/Wachs cutter. NU BOPE.Set 7"packoff and test to 5000 psi f/10 min.per Vetco Rep. Install mouse hole in rotary. LD 43 stds 5"DP f/derrick using mouse hole.Change lower rams to 2-7/8"x 5"variables.Change out Top Drive equip.from 4-1/2"IF to 4"XT 39. RU BOP test equip. Install test plug.Attempt to test annular w/4"test joint.Test failed.RD test equipment. ND MPD equipment inpreparation to change annular element. Page 6/10 Report Printed: 2/14/2011 PI 0 N E E R o ations Summary Report - State NATURAL R SOUR FS Start Depth Foot/Meters Dens Last Start Date End Date (ftKD) (ft)• ,Mud(lb/gal) Snit t 12/15/2010 12/16/2010 12,100.0 10.10 Nipple down MPD rotating head bowl.Change out element on annular preventer.Nipple up MPD rotating head bowl.Test MPD equipment to 250 psi low and 4500 psi high.Test annular to 250 psi low and 2500 psi high.Test upper and lower rams to 250 psi low and 4500 psi high.Tested both rams with 4"and 4.5"test joints. All tests held and charted 5 min each.Remove test plug and install wear bushing.PU BHA#26 f/surface t/244'.TIH f/244't18,242'.Wash and ream with mill assembly f18,242't/8,435'.Slip and cut drill line.Trip out of hole f18,435't/6,897'. 12/16/2010 12/17/2010 12,100.0 10.10 TIH*B9T to surface laying down BHA.PU clean out BHA 27 fl surface t/255'.TIH f/255' t/11,BOW-tagged cement stringers.Drill cement and floats qulpment f/11,800't/12,095'. 12/17/2010 12/18/2010 12,100.0 10.30 Clean out rathole f112,095'[/12,10 il 0 and drill 20'new hole f/12,100'[112,120'.Circulate and condition mud weight for F.I.T.Perform FIT. 12,090'and/6,174'tv_d with 10.3_ppg mud wt to 710 psi for EMW of 12.5 ppg-Good test.Trip out the hole f/12,09 't/surface.TIH picking up BHA#28.Upload MWD data and shallow pulse test same-Good test.TIH f/410'[112,070'. Remove trip nipple and install RCD head. 12/18/2010 12/19/2010 12,120.0 379.00 7.80 Held PJSM and displaced welt from 10.3 ppg WBM to 7.8 ppg MOBM while maintaining 9..6 ppg EMW with MPD equipment._Directional drill f/12,120't113,499'.Backream f/13,499't/12,93flo establish full circulation after pack off event.Circulate hole clean at 12,937'.TIH f/12,937' [113,405 Establish circulation at 13,323'with multiple pack off events and attempt to ream in the hole past 13,405'. 12/19/2010 12/20/2010 12,499.0 7.85 Attempt to ream in the hole past 13,405'with no success.PJSM with crews and transfer kill weight mud from RSC to rig pits and displace 7.8 ppg MOBM with 10.2 ppg MOBM.TIH f/13,380' [112,070'.Monitor well 10 min-static.Remove RCD bearing and install)trip nipple.TIH f/12,070' [1 surface-discovered part of the Geo-Pilot and the bit had twisted off and stayed in the hole. Service rig and top drive while function testing BOPE.RU 2-7/8"tubing handling equipment.RIH with 2-7/8"L-80 6.4#cement stinger f/surface t/1,517'.TIH with 2-7/8"cement stinger on 4"DP (/1,517'[/7,780'. 12/20/2010 12/21/2010 12,499.0 7.90 TIH with 2-7/8"cement stinger on 4H DP"f/7,780'[113,390'.Circulate and condition mud for cement job.Line up to cement pump and set balanced cement plug••1/13,390'[112,600'.Pump 16 bbls Dual spacer at 11.2 ppg-Test lines to 3000 psi.Pump 32 bbls Premium cement at 17.0 ppg w/1.01 yield.Chase with 3 bbls Dual spacer at 11.2 ppg.Displace cement w/115 bbls. (Additives:.59%HALAD 344-.55%SCR-100-.11#/sk Super CBL&.75%CFR-3,Surfactant B.5 gal/bbl) POOH f/13,390'[/12,600'.Drop DP wiper ball and circulate hole clean at 12,600'. Estimated cement returned to surface was 1-2 bbls.Line up to cement pump and set balanced • • f/12,600[/11,923'.Pump 16 bbls Dual spacer at 11.2 ppg-Test lines to 3000 psi. Pump 31.6 bbls Premium cement at 17.0 ppg w/1.01 yield.Chase with 3 bbls Dual spacer at 11.2 ppg.Displace cement w/108 bbls.(Additives:.59%HALAD 344-.55%SCR-100-.11#/sk Super CBL&.75%CFR-3,Surfactant B.5 gal/bbl.) POOH f/12,600'[/11,923'.Drop OP wiper ball and circulate hole clean at 11,923'.Estimated cement returned to surface was 4-5 bbls.Slip Wand cut 76'of drill line.POOH f/11'.,923't/1,517'.Test choke manifold to 250 psi low/4500 psi high while POOH.AOGCC rep Jeff Jones waived witness of test 18:00 hrs 12/20/10.RU 2-7/8" handling equipment and POOH laying down 2-7/8"cement stinger.RD 2-7/8"handling equipment. 12/21/2010 12/22/2010 12,090.0 77.00 7.80 RD 2-7/8"handling equipment. Pull wear bushing,install junk screen,flush stack with diverted flow tool and pull junk screen when finished. Install test plug and RU testing equipment.Test BOPE per AOGCC Permit to drill.Test BOPE w/4"and 4.5"test joint to 250 psi low and 4500 psi high.Test annular w/4"test joint to 250psi low and 2500 psi high.Test all floor valves to 250 psi low and 4500 psi high.Test upper and lower1130P valves to 250 psi low and 4500 high.Closure pressure 2950;2000 after closure,200 psi=19 sec. Full pressure 1 min.31 sec.All tests charted and all tests held for 5 min.RD testing equipment.Right to witness waived by AOGCC Rep.Jeff Jones at 18:00 hrs on 12/20/10.Choke manifold was tested on 12/20/10 while POOH. PU dirctional BHA#29 and TIH with same[/11,947'.Drilling cement(/11,947'[/12,090'.Directional drilling(/12,090'[/12,167'.Attempt to free stuck pipe with full circulation.Torque and slump pipe with 15k tq,and jar pipe in attempt to free same. Page 7/10 Report Printed: 2/14/2011 P I 0 N E E R o ations Summary Report - State NAT'URAI_RFSOURCFS Start Depth Foot/Meters Dens Last Start Date End Date (ftt<8) (ft) Mud(ib/ga1) Summary 12/22/2010 12/23/2010 12,167.0 10.10 Attempt to free stuck pipe with full circulation.Torque and slump pipe with 15k tq.Jar pipe at 50k down and 400k up.Pulled max pull at 90%tensile strength to 450k. Inspect derrick and top drive prior to jarring again.Attempt to jar pipe downward in attempt to free same. Rig up HES E-line unit,MU pack off on top of top drive goose neck and MU string shot tools. RIH with string shot f/ surface 1/12,030'wlm. Locate and correlate CCL log with DP tally.Work pipe and trap left hand torque in order to make back off.Trapped 17 left hand wraps at 6k torque.Attempt to fire string shot at 12,002'wlm-No indication of shot.Change out pack off element on top of top drive prior to pulling out the hole with E-line. 12/23/2010 12/24/2010 12,167.0 10.10 Change out pack off element on top of top drive and POOH f/11,950'wlm U surface.Held PJSM with crew prior to handling live string shot.Discovered that string shot had actually fired.RD pack off from top drive and replace cap for circulating.CBU and then spot 10 bbls sea water pill at the bit.Pump 20 bbl hi-vis spacer ahead and behind water pill.Spot 5 bbls in open hole and leave 5 bbls in the pipe.Jar pipe downward in attempt to free same.Pump 1 bbl of water out the bit every hour.Rig up HES E-line unit,MU pack off on top of top drive goose neck,and MU string shot tools.RIH f/surface 1/12,030'with assistance from rig pumps.Locate and correlate CCL log with DP tally.Work pipe and trap left hand torque in order to make back off.Fire string shot at 12,002'wlm-Shot fired.Connection did not break when shot fired.POOH with string shot f/12,002'wlm U surface.RD pack off from top drive and replace cap for circulating.Stage up left hand torque into pipe and make blind back off,Original PUW 205k,new PUW 195k after back off.CBU while rigging down E-line shieves. 12/24/2010 12/25/2010 12,167.0 10.20 CBU while rigging down E-line sheaves.POOH f/11,563'U surface-BHA plus 7 joints of DP left in hole after blind back off.Top of fish at 11,563'.Service rig and top drive. Inspect derrick, crown,and blocks-ok.Build cut lip screw in su6 from a X-O sub and stage same up to rig floor. TIH picking up fishing BHA from surface 1/362'.TIH f/362'1/11,251'-break,redope,and retorque every connection. 12/25/2010 12/26/2010 12,167.0 10.20 TIH f/11,251'1/11,563'-tagged top of fish at 11,563'.Cicrculate surface to surface adding 6% NXS lube to mud system.Screw into fish at 11,563'and torque up same to 9k torque.Circulate lubes around BHA and begin jarring in attempt to free stuck BHA.RU pump in sub with TIW,Lo Torque Valves,and tee to pump acid with cement pump.PJSM for pumping Mud Acid, tested lines to 3500 psi and pumped:18 bbls of mud acid and flush lines soda ash treatment.Spot mud acid treatment with rig pumps by displacing with 106 bbls.Displaced 6 bbls out of bit with 12 bbls left in drillstring.Pumped 3 bbls to flush spent acid after allowing mud acid to soak 45 minutes. Mowed Stage 2 acid to sit on formation while jarring up on pipe-BHA free.Pull BHA into r casing ff12,167'1/12,075'.Close Upper Pipe Rams and bullhead 56 bbls of OBM through kill line to bullhead the mud acid into the formation. Bleed off and check pressure—monitor well for flow back,static.Bled back total of 6 bbls.Circulate surface to surface monitoring returns for acid- No indications of acid returned to surface.POOH with fish f/12,075'1/8,139'. 12/26/2010 12/27/2010 12,167.0 0.00 10.10 POOH with fish(/8,139'to the fishing BHA at 966'.POOH laying down fishing BHA and fish f/966'U surface. Perform complete inspection of derrick,top drive,crown,and substructure due to jarring operations.PU directional motor BHA f/surface U 337'and shallow pulse test same- good test.TIH f/337'1/11,996'.Slip and cut 52'of drill line.Precautionary wash and ream (/11,996'1/12,167'-no tight hole issues observed. 12/27/2010 12/28/2010 12,167.0 10.30 Directional drill f/12,167'1/12,300'.Circulate 2x OH volume and POOH f/12,300'012,088'.CBU at 12,088'.POOH f/12,088'1/surface laying down BHA.Function test BOPE as per AOGCC permit to drill-good test.PU directional RSS BHA f/surface 1/377'and shallow pulse test same- good test.TIH f/377'1/3,269'.Pulse test LWD-good test.TIH f/3,269'1/4,041'. 12/28/2010 12/29/2010 12,300.0 0.00 7.90 TIH(/4,041'1/12,036'.Function test all BOPE as per AOGCC permit to drill-good test. Pulse test LWD and Geo-Pilot bearings-good test.Monitor well-static.Remove trip nipple and install RCD bearing.Pump 30 bbl hi-vis spacer and displace 10.2 ppg OBM with 7.8 ppg OBM.Take rotational surveys at various survey points as per directional driller for Cassandra survey corrections. 12/29/2010 12/30/2010 12,300.0 1,610.00 7.95 RIH 812,229'1/12,300`.Directior)ektilff/12,300'1/12.493'.Wash and ream to clean up dogleg f/12,448'1/12,482'.Continue drilling f/12,493'1/13,910'.Circulate to clean hole due to packing off issues. Page 8/10 Report Printed: 2/14/2011 P I 0 N E E R o ations Summary Report - State NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (EKE) (ft) Mud Qblgat) Summary 12/30/2010 12/31/2010 12,850.0 21.00 7.80 Drill f/13,910'1/13,920'. Packing off and torque up. Pull above trouble area 1/13,863'. POOH on elevators f/13,863'1/13,160'. Pump H V.sweep around. Pull 1 stand 1/13,080'.CBU x 3. POOH on elevators(/13,080'1112,036'(54'inside 7"shoe). RIH f/12,036'1)12,850'. Ream&trough f112,820'U12,850'.Time drill&sidetrack f/12,850'1112,871'. 12/31/2010 1/1/2011 12,871.0 961.00 7.90 Directional drill V12,871'03,832'.Circulate 3x open hole volume.POOH for short trip f/13,832' 1/12,778'.RIH 1/13,090'.Check shot survey shows entered old hole.POOH 1)12,820'.Wash& ream.Work back into new hole.Wash and ream new hole f/12,875'1/12,905'WI 200 fph,zero weight on bit. 1/1/2011 1/2/2011 13,832.0 0.00 7.85 Backream out of hole U12,804'. RIH(/12,804'1/13,097'.Change RCD bearing.Continue RIH 1/13,771'.Attempt to wash to bottom at 13,832'.Wash f/13,771'U13,817'.Packing off.POOH U13,445'.Circulate and condition hole.Lost detection on MWD tools.Wash&ream U13,650'. Pump H.V.nutplug sweep around.Obtained intermittent MWD signal.POOH 1/13,386'.Circulate and check surface equip. POOH f/13,386'to sump at 12,550'.Pump 50 bbls H.V. 10.1 ppg MOBM and spot 17 bbls in open hole.POOH f/12,550'1/12,036'(inside 7"shoe).Displace well to 10.1 ppg MOBM.Pull RCD head. Install trip nipple.Pump dry job. NOTE:Notified AOGCC of upcoming BOP test at 18:00 hrs on 1/1/11.AOGCC Rep Bob Noble waived right to witness at 18:15 hrs.on 1/1/11. 1/2/2011 1/3/2011 13,355.0 10.20 POOH f/12,036'U surface.LD BHA. Test BOPE per AOGCC Permit to drill: -Test BOPE w/4"and 4.5"test joint 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 upper and lower IBOP valves to 250 psi low/4500 high. -Test 14 choke man.valves to 250 psi low,4500 high while POH. -System pressure 3000,2000 after closure,200 psi achieved at 24 sec.Full pressure at 1 min.46 sec. -All tests charted and all tests held for 5 min. -Two failures:H2S gas&LEL gas alrms on rig floor.Both repaired and tested.Good test. -Rig down testing equipment. -Right to witness waived by AOGCC Rep.Bob Noble at 18:15 hrs on1/1/11.Install wear ring.PU BHA. 1/3/2011 1/4/2011 13,375.0 7.00 7.90 PU RSS BHA.RIH 1/12,037'.Cut&slip drilling line.Pull trip nipple. Install RCD head. RIH 1/13,375'.Displace well to 7.9 ppg MOBM.Cut trough V13,345'1/13,375'.Time drill&sidetrack f/13,375'1/13,382'. Sl I 1/4/2011 1/5/2011 13,382.0 873.00 7.85 Time drill&sidetrack f/13,382't/13 .97'.Directional drill V13,397'1/14,255'. 1/5/2011 1/6/2011 14,255.0 588.00 7.90 Directional drill f/14,255'1/14,843'.Circulate open hole volume 4x.POOH for short trip f/14,843' U13,465'.Encountered tight hole hole at 13,465'.Work pipe and pump lube.Work pipe free and backream f/13,465'1/13,387' Work on T.D.hydraulics. 1/6/2011 1/7/2011 13,220.0 48.00 7.85 Backream f/13,387'1/13,194'.Trough&sidetrack f/13,220'1/13,324'.Backream f/13,324' 1)13,238'.Trough&sidetrack V13,238'1/13,268'. 1/7/2011 1/8/2011 13,268.0 23.00 7.85 Trough&sidetrack f/13,238'1113,268'.Time drill&sidetrack f/13,268'1/13,291'. 1/8/2011 1/9/2011 13,291.0 904.00 7.95 Drill f/13,291'1/13,484'.Circulate 3x open hole volume.Pump 30 bbis lube pill and spot around BHA.Backream out 1/13,350'.Change RCD head.Wash&ream f/13,350'1/13,484'.Directional drill f/13,484'1/14,195'. 1/9/2011 1/10/2011 14,195.0 1,700.00 8.00 Directional drill f/14,195'U15,895'. NOTE: Function test BOPE per AOGCC weekly requirement. 1/10/2011 1/11/2011 15,895.0 794.00 8.00 Directional drill f/15,895'1116,606'.Circulate open hole clean.POOH U16,240'.Change RCD head.Repair MPD hydraulic pump.RIH 1/16,240'1/16,606'.Directional drill f/16,606'1/16,689'. • CBU. Page 9/10 Report Printed: 2/14/2011 P I 0 N E E R C ations Summary Report - State NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKE) (ft) Mud(Ib/gal) Summary 1/11/2011 1/12/2011 16,689.0 0.00 8.00 CBU 4x,standing back 1 stand every BU.POOH f/16,265't112,030'.Change washpipe packing. RIH f/12,030't/13,387'. Ream f/13,387't/13,484'.RIH to 6-1/8"TD at 16,689'.Circulate hole clean.Displace open hole to 6.8 ppg LVT.POOH f/16,689't/14,448'. 1/12/2011 1/13/2011 16,689.0 0.00 12.00 POOH f114,448't112,550'.Spot 30 bbl hi-vis pill f/12,550'V12,080',chase with 12.0 ppg MOBM. POOH f/12,550'V12,037'.Displace well from 8.0 ppg OBM to 12.0 ppg OBM. RCD element started leaking,shut annular preventer,remove RCD bearing,and install trip nipple.Open annular preventer,circulate and condition mud weight to 12.0 ppg.Slip and cut drill line,service rig and top drive.POOH f/12,037'V378'.LD directional BHA f/378'V surface.TIH picking up 4" HWDP singles from pipe shed V650'.Flush HWDP with 2x pipe capacity.Rack back 7 stands of HWDP in derrick.RU 4.5"handling equipment,held PJSM,and Baker-Lok shoe onto shoe joint. USN 1/13/2011 1/14/2011 16,689.0 0.00 11.00 RIH with 4.5"L-80 12.6#HYD 521 liner f/surface t14,461'.MU liner hanger,liner top packer,and PBR.PU bumper jars and Razor-back scraper assembly f/4,461't14,624'.TIH with 4.5"liner on 4"DP(/4,624'V12,044'.Circulate DP capacity at 12,044'and take PUW,SOW,and torque readings prior to entering open hole.TIH with 4.5"liner on 4"DP f/12,044'V16,399'.Drop 1-3/4" ball and pump down same to seat and set hanger.Stage pump psi in 500 psi increments to 2000 psi to set hanger.Slack off with 20k down to set hanger.Shear ball seat with 3200 psi to release running tool. PU 9'to expose packer setting dogs and set same with 75k.Test packer down annulus to 2200 psi;held and charted 30 min-Good test.Liner top at 11,914';liner shoe at 16,399'. Unsting from liner top packer and CBU at 11,880'. 1/14/2011 1/15/2011 16,689.0 0.00 10.20 Displace well from 12.0 ppg OBM to 10.0 ppg brine.Monitor well-flowing at 1 bbl every 8-10 min,CBU with 10.0 ppg brine-10 bbls OBM returned to surface at bottoms up indication of ballooning.Monitor well-flowing at 1 bbl every 8-10 min,raise brine weight to 10.2 ppg. Circulate surface to surface raising brine wt.to 10.2 ppg.Monitor well-flowing at 1 bbl every 20 minutes,decreasing to static condition.POOH f/11,880'V surface laying down scraper assembly and liner running tool.Remove wear bushing.RU 4-1/2"tubing running equipment,ROC gauge I -wire,and SSSV control line spools and sheaves.PJSM with crew,PU seal assembly and RIH with 4.5"L-80 12.6#Hyd 521 f/surface V138'. 1/15/2011 1/16/2011 16,689.0 0.00 10.20 Install ROC gauge into carrier,splice I-wire to ROC gauge and check communication-Good test. RIH with 4.5"L-80 12.6#Hyd 521 frac string f/138'V9,946'.Make up SSSV and control line, test control line to 5000 psi for 15 min-Good test.RIH with 4.5"L-80 12.6#Hyd 521 frac string (/9,946'011,883'.RIH(/11,883'V No-Go with 20k down at 11,914'.Close annular and test annulus to 500 psi-Good test. LD 3 joints of tubing,pick up space out pups,and tubing hanger. Make I-wire and SSSV control line penetrations thru hanger and splice same to monitor while landing. Land hanger at 11,914'with 20k down on No-Go.Verify same and lock down hanger. Maintained 5000 psi on SSSV control line while landing.Test upper and lower hanger seals to 5000 psi on chart for 10 min-Good test. 1/16/2011 1/17/2011 16,689.0 0.00 10.20 Attempt to test seals downannulus to 2200 psi-no success bleeding off 250 psi in 30 min. Inspect all possible leak paths.Change out test chart sensor.LD landing joint and install BPV in hanger.ND drilling riser from well head and PU same to inspect hanger.Test down annulus and discovered a leaking ferrel on the SSSV control line.Tightened same until it stopped leaking. Retest same with no success.Attempt to test seals down annulus to 2200 psi-no success bleeding off 250 psi in 30 min.Inspect all possible leak paths-no visible leaks.Trouble shoot all surface equipment.Inspect all surface equipment and fill tubing with water.Retest seals down annulus to 2200 psi-Good test to 2125 psi.Send test results to ODS senior drilling engineer for approval.Terminate I-wire and SSSV control lines at rig floor and RD spools for same.Nipple down BOP stack and set back same on stump. Make I-wire and SSSV control line penetrations thru well head and terminate same.Test SSSV control line to 5000 psi for 10 min-Good test. Install and NU production tree and test same.Test upper and lower void to 5000 psi on chart 15 • min-Good test.Test all tree valves to 5000 psi on chart for 15 min-Good test.LD 4"DP from derrick using the mouse hole. 1/17/2011 1/18/2011 16,689.0 0.00 10.20 LD 4"DP from derrick using the mouse hole. Prep rig for rig move to ODST-46i. RIG RELEASED FROM ODSN-18 @ 23:59 HRS ON 01/17/11. Page 10/10 Report Printed: 2/14/2011 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) • Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True . ' Wellbore: ODSN-18 Survey Calculation Method: Minimum Curvature , Design: ODSN-18 PN11 Database: .Pioneer 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 ODSN-18-Slot ODS-18 Well Position +N/-S 0.00 ft Northing: 6,031,051.27 ft • Latitude: 70°29'45.254 N +E/-W 0.00 ft Easting: 469,821.18 ft , Longitude: 150°14'48.375 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft Wellbore ODSN-18 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-18 PN11 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 13,156.84 Vertical Section: Depth From(TVD) +N/-5 +E/-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 290.79 Survey Program Date 1/27/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 141.00 981.00 ODSN-18 PB1 Gyro 1 (ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 10/25/2010 ' 1,027.53 1,027.53 ODSN-18 PB1 MWD 1 (ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/2/2010 1: 1,123.00 1,123.00 ODSN-18 PB1 Gyro 2(ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 11/2/2010 1: 1,174.43 3,566.42 ODSN-18 PB1 MWD 2(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/26/2010 3,630.15 8,392.12 ODSN-18 PB1 MWD 3(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/1/2010 1: 8,438.00 12,090.00 ODSN-18 PB2 MWD 4(ODSN-18 PB2) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/5/2010 1: 12,122.46 12,771.79 ODSN-18 PB3 MWD 5(ODSN-18 PB3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/22/2010 ' 12,850.00 13,156.84 ODSN-18 PB4 MWD 6(ODSN-18 PB4) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/30/2010 ' 13,250.00 16,630.89 ODSN-18 MWD 8(ODSN-18) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 1/6/2011 12: 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 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,051.27 469,821.18 0.00 0.00 UNDEFINED 141.00 0.26 304.00 141.00 84.80 0.13 -0.19 6,031,051.40 469,820.99 0.26 0.22 SR-Gyro-SS(1) 199.00 0.27 348.71 199.00 142.80 0.33 -0.32 6,031,051.60 469,820.86 0.35 0.42 SR-Gyro-SS(1) 232.00 0.49 322.56 232.00 175.80 0.52 -0.42 6,031,051.79 469,820.76 0.83 0.58 SR-Gyro-SS(1) 290.00 0.48 322.52 290.00 233.80 0.91 -0.72 6,031,052.18 469,820.46 0.02 1.00 SR-Gyro-SS(1) 323.00 0.93 308.43 322.99 266.79 1.19 -1.02 6,031,052.46 469,820.17 1.45 1.37 SR-Gyro-SS(1) 382.00 1.25 295.72 381.98 325.78 1.76 -1.97 6,031,053.04 469,819.22 0.68 2.47 SR-Gyro-SS(1) 1/31/2011 9:37:37AM Page 2 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 Database: .Pioneer 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) (°I100') (ft) Survey Tool Name 415.00 1.90 288.47 414.97 358.77 2.09 -2.81 6,031,053.38 469,818.38 2.06 3.37 SR-Gyro-SS(1) 472.00 2.17 284.07 471.93 415.73 2.66 -4.76 6,031,053.94 469,816.43 0.55 5.39 SR-Gyro-SS(1) 505.00 2.74 284.05 504.90 448.70 3.00 -6.13 6,031,054.29 469,815.06 1.73 6.79 SR-Gyro-SS(1) 568.00 3.14 281.82 567.82 511.62 3.72 -9.28 6,031,055.03 469,811.92 0.66 9.99 SR-Gyro-SS(1) 601.00 3.54 281.44 600.76 544.56 4.11 -11.16 6,031,055.42 469,810.04 1.21 11.89 SR-Gyro-SS(1) 662.00 3.66 281.14 661.64 605.44 4.86 -14.92 6,031,056.19 469,806.28 0.20 15.67 SR-Gyro-SS(1) 685.00 3.95 280.22 684.59 628.39 5.14 -16.42 6,031,056.47 469,804.79 1.29 17.17 SR-Gyro-SS(1) 758.00 4.41 281.46 757.40 701.20 6.14 -21.64 6,031,057.50 469,799.57 0.64 22.41 SR-Gyro-SS(1) 791.00 4.78 281.29 790.29 734.09 6.66 -24.23 6,031,058.03 469,796.98 1.12 25.02 SR-Gyro-SS(1) 853.00 5.29 282.35 852.05 795.85 7.78 -29.56 6,031,059.17 469,791.66 0.84 30.39 SR-Gyro-SS(1) 886.00 5.85 279.85 884.90 828.70 8.39 -32.70 6,031,059.79 469,788.52 1.85 33.55 SR-Gyro-SS(1) 948.00 6.88 279.90 946.51 890.31 9.57 -39.47 6,031,061.00 469,781.75 1.66 40.30 SR-Gyro-SS(1) 981.00 6.89 278.10 979.28 923.08 10.19 -43.38 6,031,061.64 469,777.85 0.65 44.17 SR-Gyro-SS(1) 1,027.53 6.83 276.30 1,025.47 969.27 10.89 -48.89 6,031,062.35 469,772.34 0.48 49.57 MWD+IFR2+MS+sag(2) 1,123.00 9.55 277.06 1,119.96 1,063.76 12.48 -62.40 6,031,064.01 469,758.84 2.85 62.76 SR-Gyro-SS(3) 1,174.43 9.71 277.20 1,170.67 1,114.47 13.55 -70.93 6,031,065.11 469,750.31 0.31 71.12 MWD+IFR2+MS+sag(4) 1,218.54 9.91 278.29 1,214.13 1,157.93 14.57 -78.38 6,031,066.15 469,742.87 0.62 78.45 MWD+IFR2+MS+sag(4) 1,314.10 9.75 271.65 1,308.29 1,252.09 15.98 -94.61 6,031,067.64 469,726.65 1.20 94.12 MWD+IFR2+MS+sag(4) 1,409.32 10.15 272.52 1,402.08 1,345.88 16.59 -111.05 6,031,068.30 469,710.21 0.45 109.70 MWD+IFR2+MS+sag(4) 1,504.37 10.95 274.95 1,495.52 1,439.32 17.73 -128.41 6,031,069.52 469,692.86 0.96 126.34 MWD+IFR2+MS+sag(4) 1,599.91 12.48 272.29 1,589.07 1,532.87 18.93 -147.77 6,031,070.80 469,673.51 1.70 144.86 MWD+IFR2+MS+sag(4) 1,631.69 12.76 273.11 1,620.08 1,563.88 19.26 -154.70 6,031,071.15 469,666.57 1.05 151.46 MWD+IFR2+MS+sag(4) 1,725.28 14.37 274.13 1,711.06 1,654.86 20.65 -176.61 6,031,072.64 469,644.68 1.74 172.44 MWD+IFR2+MS+sag(4) 1,821.10 13.44 273.34 1,804.07 1,747.87 22.16 -199.58 6,031,074.24 469,621.71 0.99 194.45 MWD+IFR2+MS+sag(4) 1,915.58 15.28 274.70 1,895.59 1,839.39 23.82 -222.95 6,031,075.99 469,598.35 1.98 216.89 MWD+IFR2+MS+sag(4) 2,011.74 15.85 275.48 1,988.23 1,932.03 26.11 -248.65 6,031,078.39 469,572.66 0.63 241.73 MWD+IFR2+MS+sag(4) 2,107.39 14.66 274.53 2,080.51 2,024.31 28.31 -273.72 6,031,080.69 469,547.60 1.27 265.95 MWD+IFR2+MS+sag(4) 2,202.94 13.62 277.80 2,173.16 2,116.96 30.80 -296.92 6,031,083.27 469,524.41 1.37 288.52 MWD+IFR2+MS+sag(4) 2,241.41 13.96 276.43 2,210.52 2,154.32 31.93 -306.02 6,031,084.44 469,515.32 1.23 297.43 MWD+IFR2+MS+sag(4) 2,298.61 14.97 276.21 2,265.91 2,209.71 33.50 -320.22 6,031,086.07 469,501.13 1.77 311.26 MWD+IFR2+MS+sag(4) 2,333.40 15.89 274.27 2,299.44 2,243.24 34.34 -329.44 6,031,086.95 469,491.92 3.03 320.18 MWD+IFR2+MS+sag(4) 2,393.28 16.92 271.13 2,356.89 2,300.69 35.12 -346.33 6,031,087.80 469,475.03 2.27 336.24 MWD+IFR2+MS+sag(4) 2,488.03 20.47 266.74 2,446.63 2,390.43 34.45 -376.67 6,031,087.25 469,444.70 4.03 364.37 MWD+IFR2+MS+sag(4) 2,583.22 24.38 267.73 2,534.60 2,478.40 32.73 -412.93 6,031,085.67 469,408.43 4.13 397.66 MWD+IFR2+MS+sag(4) 2,678.36 29.60 267.12 2,619.35 2,563.15 30.77 -456.05 6,031,083.89 469,365.31 5.49 437.27 MWD+IFR2+MS+sag(4) 2,773.39 32.86 268.44 2,700.60 2,644.40 28.89 -505.27 6,031,082.21 469,316.08 3.51 482.62 MWD+IFR2+MS+sag(4) 2,868.92 36.48 268.01 2,779.16 2,722.96 27.20 -559.58 6,031,080.73 469,261.77 3.80 532.79 MWD+IFR2+MS+sag(4) 2,963.62 38.66 267.56 2,854.21 2,798.01 24.96 -617.27 6,031,078.73 469,204.08 2.32 585.94 MWD+IFR2+MS+sag(4) 3,059.68 38.65 266.41 2,929.23 2,873.03 21.80 -677.19 6,031,075.82 469,144.15 0.75 640.83 MWD+IFR2+MS+sag(4) 3,155.09 41.44 265.51 3,002.26 2,946.06 17.46 -738.41 6,031,071.73 469,082.92 2.99 696.53 MWD+IFR2+MS+sag(4) 1/31/2011 9:37:37AM Page 3 COMPASS 2003.16 Build 42F • Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 Database: .Pioneer 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) (°I100') (ft) Survey Tool Name 3,249.55 42.15 264.91 3,072.68 3,016.48 12.20 -801.15 6,031,066.73 469,020.17 0.86 753.31 MWD+IFR2+MS+sag(4) 3,344.92 46.28 265.36 3,141.02 3,084.82 6.58 -867.40 6,031,061.37 468,953.90 4.34 813.25 MWD+IFR2+MS+sag(4) 3,439.63 48.20 265.43 3,205.32 3,149.12 0.99 -936.71 6,031,056.07 468,884.58 2.03 876.07 MWD+IFR2+MS+sag(4) 3,534.85 49.89 264.83 3,267.73 3,211.53 -5.12 -1,008.36 6,031,050.25 468,812.91 1.84 940.88 MWD+IFR2+MS+sag(4) 3,566.42 50.37 265.46 3,287.97 3,231.77 -7.17 -1,032.50 6,031,048.30 468,788.76 2.16 962.73 MWD+IFR2+MS+sag(4) 3,630.15 49.94 264.80 3,328.80 3,272.60 -11.32 -1,081.25 6,031,044.34 468,740.00 1.04 1,006.83 MWD+IFR2+MS+sag(5) 3,728.64 48.98 264.86 3,392.82 3,336.62 -18.06 -1,155.80 6,031,037.90 468,665.44 0.98 1,074.13 MWD+IFR2+MS+sag(5) 3,823.03 48.55 265.70 3,455.04 3,398.84 -23.91 -1,226.54 6,031,032.35 468,594.68 0.81 1,138.19 MWD+IFR2+MS+sag(5) 3,918.36 47.71 266.13 3,518.66 3,462.46 -28.97 -1,297.34 6,031,027.57 468,523.86 0.94 1,202.59 MWD+IFR2+MS+sag(5) 4,013.58 47.75 266.18 3,582.71 3,526.51 -33.69 -1,367.65 6,031,023.14 468,453.55 0.06 1,266.64 MWD+IFR2+MS+sag(5) 4,108.84 51.32 267.02 3,644.52 3,588.32 -37.97 -1,439.98 6,031,019.15 468,381.20 3.81 1,332.74 MWD+IFR2+MS+sag(5) 4,203.49 54.06 266.88 3,701.89 3,645.69 -41.98 -1,515.15 6,031,015.45 468,306.03 2.90 1,401.59 MWD+IFR2+MS+sag(5) 4,300.86 56.97 265.70 3,757.01 3,700.81 -47.19 -1,595.23 6,031,010.56 468,225.93 3.15 1,474.61 MWD+IFR2+MS+sag(5) 4,398.80 58.70 262.86 3,809.16 3,752.96 -55.47 -1,677.71 6,031,002.62 468,143.43 3.02 1,548.78 MWD+IFR2+MS+sag(5) 4,493.85 61.31 259.87 3,856.68 3,800.48 -67.85 -1,759.07 6,030,990.57 468,062.03 3.87 1,620.44 MWD+IFR2+MS+sag(5) 4,584.47 65.00 259.37 3,897.60 3,841.40 -82.42 -1,838.58 6,030,976.32 467,982.46 4.10 1,689.61 MWD+IFR2+MS+sag(5) 4,684.58 67.49 257.58 3,937.92 3,881.72 -100.74 -1,928.35 6,030,958.37 467,892.63 2.98 1,767.03 MWD+IFR2+MS+sag(5) 4,779.26 68.84 257.43 3,973.14 3,916.94 -119.76 -2,014.15 6,030,939.70 467,806.76 1.43 1,840.50 MW D+I FR2+MS+sag(5) 4,871.89 70.51 256.93 4,005.31 3,949.11 -139.03 -2,098.85 6,030,920.77 467,722.00 1.87 1,912.84 MWD+IFR2+MS+sag(5) 4,965.11 71.34 257.43 4,035.78 3,979.58 -158.58 -2,184.75 6,030,901.58 467,636.02 1.02 1,986.21 MWD+IFR2+MS+sag(5) 5,063.57 71.46 258.28 4,067.18 4,010.98 -178.21 -2,275.98 6,030,882.32 467,544.73 0.83 2,064.53 MWD+IFR2+MS+sag(5) 5,159.38 71.34 258.20 4,097.74 4,041.54 -196.72 -2,364.88 6,030,864.17 467,455.76 0.15 2,141.07 MW D+I FR2+MS+sag(5) 5,254.53 71.20 258.00 4,128.29 4,072.09 -215.30 -2,453.05 6,030,845.95 467,367.52 0.25 2,216.91 MWD+IFR2+MS+sag(5) 5,345.36 70.63 257.39 4,157.99 4,101.79 -233.59 -2,536.92 6,030,828.00 467,283.59 0.89 2,288.82 MWD+IFR2+MS+sag(5) 5,441.12 71.23 257.83 4,189.28 4,133.08 -253.01 -2,625.31 6,030,808.94 467,195.13 0.76 2,364.57 MWD+IFR2+MS+sag(5) 5,536.74 71.07 258.19 4,220.17 4,163.97 -271.81 -2,713.83 6,030,790.51 467,106.54 0.39 2,440.65 MWD+I FR2+MS+sag(5) 5,631.50 70.36 258.20 4,251.47 4,195.27 -290.11 -2,801.38 6,030,772.57 467,018.93 0.75 2,516.00 MWD+IFR2+MS+sag(5) 5,727.44 70.95 258.18 4,283.25 4,227.05 -308.63 -2,889.99 6,030,754.40 466,930.25 0.62 2,592.26 MWD+IFR2+MS+sag(5) 5,824.68 70.61 258.07 4,315.26 4,259.06 -327.53 -2,979.84 6,030,735.87 466,840.33 0.37 2,669.56 MWD+IFR2+MS+sag(5) 5,917.59 70.86 257.56 4,345.92 4,289.72 -346.04 -3,065.57 6,030,717.71 466,754.54 0.58 2,743.14 MWD+I FR2+MS+sag(5) 6,011.23 71.05 257.12 4,376.47 4,320.27 -365.44 -3,151.94 6,030,698.66 466,668.11 0.49 2,816.99 MWD+IFR2+MS+sag(5) 6,109.85 70.29 255.57 4,409.12 4,352.92 -387.41 -3,242.36 6,030,677.07 466,577.60 1.67 2,893.74 MWD+IFR2+MS+sag(5) 6,206.00 70.35 256.98 4,441.50 4,385.30 -408.89 -3,330.31 6,030,655.95 466,489.58 1.38 2,968.33 MWD+IFR2+MS+sag(5) 6,296.96 70.47 257.77 4,472.00 4,415.80 -427.62 -3,413.93 6,030,637.56 466,405.89 0.83 3,039.86 MWD+IFR2+MS+sag(5) 6,392.50 70.96 258.81 4,503.55 4,447.35 -445.92 -3,502.23 6,030,619.62 466,317.52 1.15 3,115.92 MWD+IFR2+MS+sag(5) 6,487.74 71.03 259.25 4,534.57 4,478.37 -463.05 -3,590.63 6,030,602.84 466,229.06 0.44 3,192.48 MWD+IFR2+MS+sag(5) 6,582.74 70.87 258.69 4,565.57 4,509.37 -480.23 -3,678.77 6,030,586.02 466,140.86 0.58 3,268.78 MWD+IFR2+MS+sag(5) 6,677.75 70.73 259.06 4,596.82 4,540.62 -497.54 -3,766.81 6,030,569.07 466,052.76 0.40 3,344.94 MWD+IFR2+MS+sag(5) 6,773.48 71.16 258.45 4,628.07 4,571.87 -515.19 -3,855.56 6,030,551.79 465,963.95 0.75 3,421.65 MWD+IFR2+MS+sag(5) 6,868.81 71.27 257.68 4,658.77 4,602.57 -533.85 -3,943.86 6,030,533.48 465,875.59 0.77 3,497.57 MWD+IFR2+MS+sag(5) 1/31/2011 9:37:37AM Page 4 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 Database: .Pioneer 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) (°1100') (ft) Survey Tool Name 6,964.81 70.80 259.14 4,689.97 4,633.77 -552.10 -4,032.79 6,030,515.61 465,786.59 1.52 3,574.24 MWD+IFR2+MS+sag(5) 7,058.66 71.73 258.75 4,720.12 4,663.92 -569.14 -4,120.02 6,030,498.92 465,699.30 1.07 3,649.74 MWD+IFR2+MS+sag(5) 7,155.94 70.48 258.65 4,751.62 4,695.42 -587.17 -4,210.27 6,030,481.25 465,608.99 1.29 3,727.72 MWD+IFR2+MS+sag(5) 7,249.11 70.27 258.33 4,782.91 4,726.71 -604.68 -4,296.26 6,030,464.09 465,522.93 0.39 3,801.89 MWD+IFR2+MS+sag(5) 7,345.08 71.16 258.01 4,814.61 4,758.41 -623.25 -4,384.92 6,030,445.88 465,434.21 0.98 3,878.19 MWD+IFR2+MS+sag(5) 7,441.17 70.89 257.84 4,845.85 4,789.65 -642.26 -4,473.78 6,030,427.24 465,345.28 0.33 3,954.51 MWD+IFR2+MS+sag(5) 7,536.09 69.56 258.34 4,877.96 4,821.76 -660.70 -4,561.18 6,030,409.16 465,257.82 1.49 4,029.68 MWD+IFR2+MS+sag(5) 7,626.41 69.56 260.20 4,909.51 4,853.31 -676.45 -4,644.33 6,030,393.74 465,174.61 1.93 4,101.82 MWD+IFR2+MS+sag(5) 7,726.42 69.36 260.00 4,944.60 4,888.40 -692.56 -4,736.58 6,030,378.02 465,082.30 0.27 4,182.35 MWD+IFR2+MS+sag(5) 7,820.69 69.02 260.88 4,978.09 4,921.89 -707.19 -4,823.48 6,030,363.74 464,995.36 0.94 4,258.40 MWD+IFR2+MS+sag(5) 7,915.20 69.21 260.17 5,011.78 4,955.58 -721.73 -4,910.57 6,030,349.56 464,908.21 0.73 4,334.66 MWD+IFR2+MS+sag(5) 8,011.00 69.69 260.57 5,045.41 4,989.21 -736.73 -4,999.01 6,030,334.91 464,819.72 0.64 4,412.02 MWD+IFR2+MS+sag(5) 8,106.40 69.26 260.81 5,078.86 5,022.66 -751.19 -5,087.18 6,030,320.82 464,731.51 0.51 4,489.31 MWD+I FR2+MS+sag(5) 8,201.28 69.17 260.04 5,112.53 5,056.33 -765.94 -5,174.65 6,030,306.42 464,643.99 0.76 4,565.85 MWD+IFR2+MS+sag(5) 8,296.82 69.86 258.87 5,145.97 5,089.77 -782.32 -5,262.63 6,030,290.40 464,555.95 1.36 4,642.29 MWD+IFR2+MS+sag(5) 8,392.12 69.57 258.47 5,179.00 5,122.80 -799.88 -5,350.28 6,030,273.19 464,468.24 0.50 4,718.00 MWD+IFR2+MS+sag(5) 8,438.00 69.60 258.48 5,195.01 5,138.81 -808.47 -5,392.41 6,030,264.77 464,426.07 0.07 4,754.33 MWD+IFR2+MS+sag(6) 8,529.05 72.36 255.25 5,224.69 5,168.49 -828.05 -5,476.21 6,030,245.54 464,342.20 4.52 4,825.73 MWD+IFR2+MS+sag(6) 8,575.56 73.36 254.40 5,238.39 5,182.19 -839.68 -5,519.11 6,030,234.08 464,299.27 2.77 4,861.70 MWD+IFR2+MS+sag(6) 8,670.27 74.48 252.70 5,264.63 5,208.43 -865.46 -5,606.38 6,030,208.67 464,211.90 2.09 4,934.14 MWD+IFR2+MS+sag(6) 8,718.63 74.39 251.47 5,277.60 5,221.40 -879.79 -5,650.71 6,030,194.52 464,167.52 2.46 4,970.50 MWD+IFR2+MS+sag(6) 8,785.71 74.04 252.09 5,295.85 5,239.65 -899.97 -5,712.02 6,030,174.59 464,106.13 1.03 5,020.66 MWD+I FR2+MS+sag(6) 8,881.94 73.38 251.52 5,322.84 5,266.64 -928.81 -5,799.77 6,030,146.10 464,018.28 0.89 5,092.45 MWD+IFR2+MS+sag(6) 8,977.86 73.11 252.53 5,350.50 5,294.30 -957.15 -5,887.13 6,030,118.12 463,930.81 1.05 5,164.07 MWD+IFR2+MS+sag(6) 9,072.22 72.75 254.47 5,378.20 5,322.00 -982.77 -5,973.61 6,030,092.85 463,844.23 2.00 5,235.83 MWD+IFR2+MS+sag(6) 9,168.00 72.53 256.55 5,406.78 5,350.58 -1,005.65 -6,062.12 6,030,070.34 463,755.64 2.09 5,310.45 MWD+IFR2+MS+sag(6) 9,262.77 72.47 260.99 5,435.29 5,379.09 -1,023.24 -6,150.74 6,030,053.11 463,666.95 4.47 5,387.06 MWD+IFR2+MS+sag(6) 9,357.47 72.46 264.53 5,463.83 5,407.63 -1,034.62 -6,240.31 6,030,042.09 463,577.35 3.56 5,466.75 MWD+IFR2+MS+sag(6) 9,452.53 71.85 267.34 5,492.97 5,436.77 -1,041.04 -6,330.55 6,030,036.04 463,487.09 2.89 5,548.84 MWD+IFR2+MS+sag(6) 9,547.64 72.27 271.43 5,522.27 5,466.07 -1,042.01 -6,421.01 6,030,035.44 463,396.64 4.11 5,633.07 MWD+IFR2+MS+sag(6) 9,642.41 72.06 275.01 5,551.31 5,495.11 -1,036.94 -6,511.07 6,030,040.87 463,306.61 3.60 5,719.06 MWD+I FR2+MS+sag(6) 9,737.67 71.99 278.14 5,580.71 5,524.51 -1,026.57 -6,601.07 6,030,051.61 463,216.66 3.13 5,806.88 MWD+IFR2+MS+sag(6) 9,833.18 71.37 281.53 5,610.74 5,554.54 -1,011.09 -6,690.39 6,030,067.45 463,127.42 3.43 5,895.88 MWD+IFR2+MS+sag(6) 9,929.57 71.41 286.08 5,641.51 5,585.31 -989.30 -6,779.07 6,030,089.60 463,038.83 4.47 5,986.53 MWD+IFR2+MS+sag(6) 10,024.64 71.38 289.64 5,671.85 5,615.65 -961.67 -6,864.82 6,030,117.57 462,953.21 3.55 6,076.49 MWD+IFR2+MS+sag(6) 10,118.68 72.08 292.42 5,701.34 5,645.14 -929.62 -6,948.16 6,030,149.95 462,870.01 2.90 6,165.78 MWD+IFR2+MS+sag(6) 10,214.27 72.08 296.36 5,730.76 5,674.56 -892.07 -7,030.97 6,030,187.83 462,787.35 3.92 6,256.53 MWD+IFR2+MS+sag(6) 10,309.31 71.94 299.25 5,760.12 5,703.92 -849.92 -7,110.92 6,030,230.31 462,707.59 2.90 6,346.24 MWD+IFR2+MS+sag(6) 10,404.13 72.22 300.94 5,789.30 5,733.10 -804.68 -7,188.97 6,030,275.86 462,629.73 1.72 6,435.27 MWD+IFR2+MS+sag(6) 10,498.75 73.56 303.93 5,817.14 5,760.94 -756.17 -7,265.28 6,030,324.67 462,553.62 3.34 6,523.82 MWD+IFR2+MS+sag(6) 1/31/2011 9:37:37AM Page 5 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 Database: .Pioneer 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) (°I100') (ft) Survey Tool Name 10,593.70 74.26 308.42 5,843.47 5,787.27 -702.34 -7,338.90 6,030,378.80 462,480.23 4.60 6,611.75 MWD+IFR2+MS+sag(6) 10,689.51 74.46 309.71 5,869.30 5,813.10 -644.19 -7,410.53 6,030,437.23 462,408.84 1.31 6,699.36 MWD+IFR2+MS+sag(6) 10,784.19 74.92 311.89 5,894.30 5,838.10 -584.53 -7,479.65 6,030,497.17 462,339.97 2.27 6,785.16 MWD+IFR2+MS+sag(6) 10,879.86 74.40 314.18 5,919.61 5,863.41 -521.57 -7,547.09 6,030,560.39 462,272.80 2.37 6,870.55 MWD+IFR2+MS+sag(6) 10,975.10 74.72 315.49 5,944.97 5,888.77 -456.84 -7,612.19 6,030,625.38 462,207.97 1.37 6,954.38 MWD+IFR2+MS+sag(6) 11,070.33 75.73 317.97 5,969.26 5,913.06 -389.80 -7,675.29 6,030,692.67 462,145.14 2.73 7,037.18 MWD+IFR2+MS+sag(6) 11,166.35 75.55 321.26 5,993.08 5,936.88 -318.96 -7,735.55 6,030,763.75 462,085.18 3.32 7,118.66 MWD+IFR2+MS+sag(6) 11,261.96 75.75 324.90 6,016.78 5,960.58 -244.92 -7,791.18 6,030,838.01 462,029.85 3.69 7,196.95 MWD+IFR2+MS+sag(6) 11,357.50 76.88 328.38 6,039.39 5,983.19 -167.40 -7,842.21 6,030,915.73 461,979.14 3.73 7,272.17 MWD+IFR2+MS+sag(6) 11,451.93 77.90 332.01 6,060.02 6,003.82 -87.45 -7,888.00 6,030,995.85 461,933.68 3.90 7,343.36 MWD+IFR2+MS+sag(6) 11,547.13 79.28 336.17 6,078.86 6,022.66 -3.53 -7,928.76 6,031,079.93 461,893.27 4.52 7,411.25 MWD+IFR2+MS+sag(6) 11,642.52 79.79 339.06 6,096.19 6,039.99 83.20 -7,964.48 6,031,166.79 461,857.91 3.03 7,475.42 MWD+IFR2+MS+sag(6) 11,736.96 79.85 338.89 6,112.88 6,056.68 169.96 -7,997.83 6,031,253.68 461,824.91 0.19 7,537.40 MWD+IFR2+MS+sag(6) 11,831.99 79.89 339.14 6,129.59 6,073.39 257.31 -8,031.33 6,031,341.15 461,791.77 0.26 7,599.72 MWD+IFR2+MS+sag(6) 11,927.00 79.58 341.03 6,146.52 6,090.32 345.20 -8,063.17 6,031,429.17 461,760.29 1.98 7,660.69 MWD+IFR2+MS+sag(6) 12,022.53 80.09 342.27 6,163.38 6,107.18 434.45 -8,092.78 6,031,518.52 461,731.05 1.38 7,720.04 MWD+IFR2+MS+sag(6) 12,067.94 80.08 343.26 6,171.20 6,115.00 477.17 -8,106.03 6,031,561.30 461,717.97 2.15 7,747.59 MWD+IFR2+MS+sag(6) 12,090.00 80.21 343.64 6,174.98 6,118.78 498.01 -8,112.22 6,031,582.15 461,711.87 1.81 7,760.78 MWD+IFR2+MS+sag(6) 12,122.46 80.82 341.19 6,180.33 6,124.13 528.52 -8,121.89 6,031,612.71 461,702.32 7.68 7,780.65 MWD+IFR2+MS+sag(7) 12,148.55 81.79 338.20 6,184.27 6,128.07 552.71 -8,130.84 6,031,636.92 461,693.47 11.92 7,797.60 MWD+IFR2+MS+sag(7) 12,196.49 83.40 336.52 6,190.45 6,134.25 596.58 -8,149.14 6,031,680.87 461,675.35 4.83 7,830.28 MWD+IFR2+MS+sag(7) 12,245.45 84.40 336.18 6,195.65 6,139.45 641.17 -8,168.67 6,031,725.53 461,656.00 2.16 7,864.37 MWD+IFR2+MS+sag(7) 12,289.71 84.07 336.40 6,200.10 6,143.90 681.49 -8,186.38 6,031,765.92 461,638.46 0.89 7,895.23 MWD+IFR2+MS+sag(7) 12,386.42 84.01 338.03 6,210.14 6,153.94 770.17 -8,223.63 6,031,854.74 461,601.58 1.68 7,961.53 MWD+IFR2+MS+sag(7) 12,483.58 83.89 342.52 6,220.39 6,164.19 861.10 -8,256.23 6,031,945.79 461,569.35 4.60 8,024.29 MWD+IFR2+MS+sag(7) 12,532.01 87.52 342.90 6,224.01 6,167.81 907.20 -8,270.58 6,031,991.95 461,555.19 7.54 8,054.07 MWD+IFR2+MS+sag(7) 12,579.25 88.92 342.40 6,225.48 6,169.28 952.27 -8,284.66 6,032,037.07 461,541.29 3.15 8,083.23 MWD+I FR2+MS+sag(7) 12,676.17 91.88 340.53 6,224.80 6,168.60 1,044.15 -8,315.46 6,032,129.06 461,510.86 3.61 8,144.63 MWD+IFR2+MS+sag(7) 12,771.79 93.54 338.11 6,220.28 6,164.08 1,133.49 -8,349.19 6,032,218.53 461,477.50 3.07 8,207.88 MWD+IFR2+MS+sag(7) 12,850.00 93.34 336.38 6,215.59 6,159.39 1,205.48 -8,379.38 6,032,290.64 461,447.60 2.22 8,261.66 MWD+IFR2+MS+sag(8) 12,867.91 92.47 337.25 6,214.68 6,158.48 1,221.93 -8,386.43 6,032,307.11 461,440.63 6.87 8,274.08 MWD+IFR2+MS+sag(8) 12,965.10 91.18 329.71 6,211.58 6,155.38 1,308.78 -8,429.77 6,032,394.13 461,397.64 7.87 8,345.43 MWD+IFR2+MS+sag(8) 13,061.01 90.94 326.12 6,209.81 6,153.61 1,390.01 -8,480.70 6,032,475.56 461,347.05 3.75 8,421.87 MWD+IFR2+MS+sag(8) 13,156.84 91.87 325.44 6,207.46 6,151.26 1,469.23 -8,534.57 6,032,554.98 461,293.50 1.20 8,500.36 MWD+IFR2+MS+sag(8) 13,250.00 89.65 323.82 6,206.22 6,150.02 1,545.18 -8,588.49 6,032,631.15 461,239.90 2.95 8,577.72 MWD+IFR2+MS+sag(9) 13,256.15 89.44 322.68 6,206.27 6,150.07 1,550.11 -8,592.17 6,032,636.09 461,236.24 18.85 8,582.91 MWD+IFR2+MS+sag(9) 13,350.96 87.11 323.73 6,209.12 6,152.92 1,625.99 -8,648.93 6,032,712.19 461,179.80 2.70 8,662.91 MWD+IFR2+MS+sag(9) 13,448.22 88.80 323.22 6,212.60 6,156.40 1,704.09 -8,706.77 6,032,790.52 461,122.28 1.81 8,744.71 MW D+I FR2+MS+sag(9) 13,544.65 85.56 323.73 6,217.34 6,161.14 1,781.48 -8,764.09 6,032,868.13 461,065.28 3.40 8,825.76 MWD+IFR2+MS+sag(9) 13,640.89 86.33 323.44 6,224.14 6,167.94 1,858.73 -8,821.08 6,032,945.61 461,008.61 0.85 8,906.46 MWD+IFR2+MS+sag(9) 1/31/2011 9:37:37AM Page 6 COMPASS 2003.16 Build 42F 4 • Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 Database: .Pioneer 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 13,737.31 86.69 321.32 6,230.01 6,173.81 1,934.96 -8,879.82 6,033,022.07 460,950.18 2.23 8,988.43 MWD+IFR2+MS+sag(9) 13,833.69 90.05 320.88 6,232.76 6,176.56 2,009.93 -8,940.31 6,033,097.27 460,890.00 3.52 9,071.59 MWD+IFR2+MS+sag(9) 13,930.46 89.29 322.09 6,233.31 6,177.11 2,085.64 -9,000.57 6,033,173.22 460,830.06 1.48 9,154.80 MWD+IFR2+MS+sag(9) 14,026.99 90.03 322.46 6,233.89 6,177.69 2,161.99 -9,059.63 6,033,249.80 460,771.31 0.86 9,237.12 MWD+IFR2+MS+sag(9) 14,122.85 88.73 323.92 6,234.92 6,178.72 2,238.73 -9,117.06 6,033,326.76 460,714.20 2.04 9,318.05 MWD+IFR2+MS+sag(9) 14,218.75 89.04 322.55 6,236.79 6,180.59 2,315.54 -9,174.45 6,033,403.80 460,657.13 1.46 9,398.96 MWD+IFR2+MS+sag(9) 14,315.40 87.99 319.97 6,239.29 6,183.09 2,390.89 -9,234.90 6,033,479.39 460,596.99 2.88 9,482.23 MWD+IFR2+MS+sag(9) 14,411.26 90.35 321.18 6,240.68 6,184.48 2,464.92 -9,295.77 6,033,553.66 460,536.43 2.77 9,565.41 MWD+IFR2+MS+sag(9) 14,508.52 90.77 319.56 6,239.73 6,183.53 2,539.83 -9,357.80 6,033,628.81 460,474.71 1.72 9,649.98 MWD+IFR2+MS+sag(9) 14,605.16 90.15 315.20 6,238.96 6,182.76 2,610.92 -9,423.22 6,033,700.16 460,409.59 4.56 9,736.38 MWD+IFR2+MS+sag(9) 14,701.30 92.33 310.59 6,236.87 6,180.67 2,676.32 -9,493.61 6,033,765.84 460,339.47 5.30 9,825.40 MWD+IFR2+MS+sag(9) 14,796.99 88.40 308.16 6,236.26 6,180.06 2,737.01 -9,567.56 6,033,826.82 460,265.78 4.83 9,916.08 MWD+IFR2+MS+sag(9) 14,894.10 86.81 306.14 6,240.32 6,184.12 2,795.60 -9,644.89 6,033,885.72 460,188.70 2.65 10,009.16 MWD+IFR2+MS+sag(9) 14,990.37 88.93 305.66 6,243.90 6,187.70 2,852.01 -9,722.81 6,033,942.43 460,111.01 2.26 10,102.04 MWD+IFR2+MS+sag(9) 15,086.83 91.28 305.32 6,243.72 6,187.52 2,908.00 -9,801.34 6,033,998.74 460,032.71 2.46 10,195.33 MWD+IFR2+MS+sag(9) 15,184.57 91.27 302.39 6,241.55 6,185.35 2,962.43 -9,882.48 6,034,053.50 459,951.80 3.00 10,290.51 MWD+IFR2+MS+sag(9) 15,281.09 87.66 298.31 6,242.45 6,186.25 3,011.18 -9,965.74 6,034,102.58 459,868.75 5.64 10,385.65 MWD+IFR2+MS+sag(9) 15,377.11 88.49 301.47 6,245.68 6,189.48 3,059.00 -10,048.93 6,034,150.73 459,785.77 3.40 10,480.39 MWD+IFR2+MS+sag(9) 15,473.69 86.31 301.13 6,250.06 6,193.86 3,109.12 -10,131.36 6,034,201.18 459,703.54 2.28 10,575.25 MWD+1FR2+MS+sag(9) 15,570.81 89.74 305.23 6,253.41 6,197.21 3,162.22 -10,212.57 6,034,254.61 459,622.56 5.50 10,670.01 MWD+IFR2+MS+sag(9) 15,666.83 94.08 309.64 6,250.20 6,194.00 3,220.53 -10,288.74 6,034,313.21 459,546.64 6.44 10,761.92 MWD+IFR2+MS+sag(9) 15,763.17 91.99 307.54 6,245.10 6,188.90 3,280.53 -10,363.93 6,034,373.51 459,471.70 3.07 10,853.51 MWD+IFR2+MS+sag(9) 15,859.61 94.19 307.64 6,239.91 6,183.71 3,339.27 -10,440.23 6,034,432.55 459,395.65 2.28 10,945.69 MWD+IFR2+MS+sag(9) 15,955.19 92.62 307.55 6,234.23 6,178.03 3,397.47 -10,515.82 6,034,491.06 459,320.30 1.65 11,037.02 MWD+IFR2+MS+sag(9) 16,051.26 91.38 306.13 6,230.88 6,174.68 3,455.04 -10,592.66 6,034,548.93 459,243.70 1.96 11,129.29 MWD+I FR2+MS+sag(9) 16,148.23 90.46 306.50 6,229.32 6,173.12 3,512.46 -10,670.79 6,034,606.66 459,165.82 1.02 11,222.71 MWD+IFR2+MS+sag(9) 16,244.54 88.91 306.71 6,229.85 6,173.65 3,569.88 -10,748.10 6,034,664.39 459,088.75 1.62 11,315.37 MWD+IFR2+MS+sag(9) 16,340.48 88.98 307.43 6,231.61 6,175.41 3,627.70 -10,824.63 6,034,722.52 459,012.46 0.75 11,407.44 MWD+IFR2+MS+sag(9) 16,437.36 89.48 307.73 6,232.92 6,176.72 3,686.78 -10,901.40 6,034,781.90 458,935.93 0.60 11,500.19 MWD+IFR2+MS+sag(9) 16,534.58 90.16 307.48 6,233.22 6,177.02 3,746.11 -10,978.42 6,034,841.53 458,859.16 0.75 11,593.25 MWD+IFR2+MS+sag(9) 16,630.89 92.33 310.64 6,231.13 6,174.93 3,806.77 -11,053.18 6,034,902.49 458,784.66 3.98 11,684.67 MWD+IFR2+MS+sag(9) 16,689.00 92.33 310.64 6,228.77 6,172.57 3,844.58 -11,097.23 6,034,940.48 458,740.76 0.00 11,739.28 PROJECTED to TD 1/31/2011 9:37:37AM Page 7 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB1 Database: .Pioneer 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 ODSN-18-Slot ODS-18 Well Position +NI-S 0.00 ft Northing: 6,031,051.27 ft Latitude: 70°29'45.254 N +E/-W 0.00 ft Easting: 469,821.18 ft Longitude: 150°14'48.375 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft Wellbore ODSN-18 PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (7) (7) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-18 PN11 PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 42.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (7) 42.70 0.00 0.00 290.79 Survey Program Date 1/27/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 141.00 981.00 ODSN-18 PBI Gyro 1 (ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 10/25/2010 1,027.53 1,027.53 ODSN-18 PB1 MWD 1 (ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:lIFR dec&3-axis correction+sag 11/2/2010 1: 1,123.00 1,123.00 ODSN-18 PB1 Gyro 2(ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 11/2/2010 1: 1,174.40 3,566.42 ODSN-18 PB1 MWD 2(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/26/2010 3,630.15 9,109.89 ODSN-18 PB1 MWD 3(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/1/2010 1: 9,183.00 11,847.02 ODSN-18 PB1 MWD 4(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/15/2010 Survey Map Map Vertical . MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (?) (7) (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 6,031,051.27 469,821.18 0.00 0.00 UNDEFINED 141.00 0.26 304.00 141.00 84.80 0.13 -0.19 6,031,051.40 469,820.99 0.26 0.22 SR-Gyro-SS(1) 199.00 0.27 348.71 199.00 142.80 0.33 -0.32 6,031,051.60 469,820.86 0.35 0.42 SR-Gyro-SS(1) 232.00 0.49 322.56 232.00 175.80 0.52 -0.42 6,031,051.79 469,820.76 0.83 0.58 SR-Gyro-SS(1) 290.00 0.48 322.52 290.00 233.80 0.91 -0.72 6,031,052.18 469,820.46 0.02 1.00 SR-Gyro-SS(1) 323.00 0.93 308.43 322.99 266.79 1.19 -1.02 6,031,052.46 469,820.17 1.45 1.37 SR-Gyro-SS(1) 382.00 1.25 295.72 381.98 325.78 1.76 -1.97 6,031,053.04 469,819.22 0.68 2.47 SR-Gyro-SS(1) 415.00 1.90 288.47 414.97 358.77 2.09 -2.81 6,031,053.38 469,818.38 2.06 3.37 SR-Gyro-SS(1) 472.00 2.17 284.07 471.93 415.73 2.66 -4.76 6,031,053.94 469,816.43 0.55 5.39 SR-Gyro-SS(1) 505.00 2.74 284.05 504.90 448.70 3.00 -6.13 6,031,054.29 469,815.06 1.73 6.79 SR-Gyro-SS(1) 1/31/2011 9:36:16AM Page 2 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB1 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 568.00 3.14 281.82 567.82 511.62 3.72 -9.28 6,031,055.03 469,811.92 0.66 9.99 SR-Gyro-SS(1) 601.00 3.54 281.44 600.76 544.56 4.11 -11.16 6,031,055.42 469,810.04 1.21 11.89 SR-Gyro-SS(1) 662.00 3.66 281.14 661.64 605.44 4.86 -14.92 6,031,056.19 469,806.28 0.20 15.67 SR-Gyro-SS(1) 685.00 3.95 280.22 684.59 628.39 5.14 -16.42 6,031,056.47 469,804.79 1.29 17.17 SR-Gyro-SS(1) 758.00 4.41 281.46 757.40 701.20 6.14 -21.64 6,031,057.50 469,799.57 0.64 22.41 SR-Gyro-SS(1) 791.00 4.78 281.29 790.29 734.09 6.66 -24.23 6,031,058.03 469,796.98 1.12 25.02 SR-Gyro-SS(1) 853.00 5.29 282.35 852.05 795.85 7.78 -29.56 6,031,059.17 469,791.66 0.84 30.39 SR-Gyro-SS(1) 886.00 5.85 279.85 884.90 828.70 8.39 -32.70 6,031,059.79 469,788.52 1.85 33.55 SR-Gyro-SS(1) 948.00 6.88 279.90 946.51 890.31 9.57 -39.47 6,031,061.00 469,781.75 1.66 40.30 SR-Gyro-SS(1) 981.00 6.89 278.10 979.28 923.08 10.19 -43.38 6,031,061.64 469,777.85 0.65 44.17 SR-Gyro-SS(1) 1,027.53 6.83 276.30 1,025.47 969.27 10.89 -48.89 6,031,062.35 469,772.34 0.48 49.57 MWD+IFR2+MS+sag(2) j 1,123.00 9.55 277.06 1,119.96 1,063.76 12.48 -62.40 6,031,064.01 469,758.84 2.85 62.76 SR-Gyro-SS(3) 1,174.43 9.71 277.20 1,170.67 1,114.47 13.55 -70.93 6,031,065.11 469,750.31 0.31 71.12 MWD+IFR2+MS+sag(4) 1,218.54 9.91 278.29 1,214.13 1,157.93 14.57 -78.38 6,031,066.15 469,742.87 0.62 78.45 MWD+IFR2+MS+sag(4) 1,314.10 9.75 271.65 1,308.29 1,252.09 15.98 -94.61 6,031,067.64 469,726.65 1.20 94.12 MWD+IFR2+MS+sag(4) 1,409.32 10.15 272.52 1,402.08 1,345.88 16.59 -111.05 6,031,068.30 469,710.21 0.45 109.70 MWD+IFR2+MS+sag(4) 1,504.37 10.95 274.95 1,495.52 1,439.32 17.73 -128.41 6,031,069.52 469,692.86 0.96 126.34 MWD+IFR2+MS+sag(4) 1,599.91 12.48 272.29 1,589.07 1,532.87 18.93 -147.77 6,031,070.80 469,673.51 1.70 144.86 MWD+IFR2+MS+sag(4) 1,631.69 12.76 273.11 1,620.08 1,563.88 19.26 -154.70 6,031,071.15 469,666.57 1.05 151.46 MWD+IFR2+MS+sag(4) 1,725.28 14.37 274.13 1,711.06 1,654.86 20.65 -176.61 6,031,072.64 469,644.68 1.74 172.44 MWD+IFR2+MS+sag(4) 1,821.10 13.44 273.34 1,804.07 1,747.87 22.16 -199.58 6,031,074.24 469,621.71 0.99 194.45 MWD+IFR2+MS+sag(4) 1,915.58 15.28 274.70 1,895.59 1,839.39 23.82 -222.95 6,031,075.99 469,598.35 1.98 216.89 MWD+IFR2+MS+sag(4) 2,011.74 15.85 275.48 1,988.23 1,932.03 26.11 -248.65 6,031,078.39 469,572.66 0.63 241.73 MWD+IFR2+MS+sag(4) 2,107.39 14.66 274.53 2,080.51 2,024.31 28.31 -273.72 6,031,080.69 469,547.60 1.27 265.95 MWD+IFR2+MS+sag(4) 2,202.94 13.62 277.80 2,173.16 2,116.96 30.80 -296.92 6,031,083.27 469,524.41 1.37 288.52 MWD+IFR2+MS+sag(4) 2,241.41 13.96 276.43 2,210.52 2,154.32 31.93 -306.02 6,031,084.44 469,515.32 1.23 297.43 MWD+IFR2+MS+sag(4) 2,298.61 14.97 276.21 2,265.91 2,209.71 33.50 -320.22 6,031,086.07 469,501.13 1.77 311.26 MWD+IFR2+MS+sag(4) 2,333.40 15.89 274.27 2,299.44 2,243.24 34.34 -329.44 6,031,086.95 469,491.92 3.03 320.18 MWD+IFR2+MS+sag(4) 2,393.28 16.92 271.13 2,356.89 2,300.69 35.12 -346.33 6,031,087.80 469,475.03 2.27 336.24 MWD+IFR2+MS+sag(4) 2,488.03 20.47 266.74 2,446.63 2,390.43 34.45 -376.67 6,031,087.25 469,444.70 4.03 364.37 MWD+IFR2+MS+sag(4) 2,583.22 24.38 267.73 2,534.60 2,478.40 32.73 -412.93 6,031,085.67 469,408.43 4.13 397.66 MWD+IFR2+MS+sag(4) 2,678.36 29.60 267.12 2,619.35 2,563.15 30.77 -456.05 6,031,083.89 469,365.31 5.49 437.27 MWD+IFR2+MS+sag(4) 2,773.39 32.86 268.44 2,700.60 2,644.40 28.89 -505.27 6,031,082.21 469,316.08 3.51 482.62 MWD+IFR2+MS+sag(4) 2,868.92 36.48 268.01 2,779.16 2,722.96 27.20 -559.58 6,031,080.73 469,261.77 3.80 532.79 MWD+IFR2+MS+sag(4) 2,963.62 38.66 267.56 2,854.21 2,798.01 24.96 -617.27 6,031,078.73 469,204.08 2.32 585.94 MWD+IFR2+MS+sag(4) 3,059.68 38.65 266.41 2,929.23 2,873.03 21.80 -677.19 6,031,075.82 469,144.15 0.75 640.83 MWD+IFR2+MS+sag(4) 3,155.09 41.44 265.51 3,002.26 2,946.06 17.46 -738.41 6,031,071.73 469,082.92 2.99 696.53 MWD+IFR2+MS+sag(4) 3,249.55 42.15 264.91 3,072.68 3,016.48 12.20 -801.15 6,031,066.73 469,020.17 0.86 753.31 MWD+IFR2+MS+sag(4) 3,344.92 46.28 265.36 3,141.02 3,084.82 6.58 -867.40 6,031,061.37 468,953.90 4.34 813.25 MWD+IFR2+MS+sag(4) 3,439.63 48.20 265.43 3,205.32 3,149.12 0.99 -936.71 6,031,056.07 468,884.58 2.03 876.07 MWD+IFR2+MS+sag(4) 1/31/2011 9:36:16AM Page 3 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB1 Database: .Pioneer 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) (°1100') (ft) Survey Tool Name 3,534.85 49.89 264.83 3,267.73 3,211.53 -5.12 -1,008.36 6,031,050.25 468,812.91 1.84 940.88 MWD+IFR2+MS+sag(4) 3,566.42 50.37 265.46 3,287.97 3,231.77 -7.17 -1,032.50 6,031,048.30 468,788.76 2.16 962.73 MWD+IFR2+MS+sag(4) 3,630.15 49.94 264.80 3,328.80 3,272.60 -11.32 -1,081.25 6,031,044.34 468,740.00 1.04 1,006.83 MWD+IFR2+MS+sag(5) 3,728.64 48.98 264.86 3,392.82 3,336.62 -18.06 -1,155.80 6,031,037.90 468,665.44 0.98 1,074.13 MWD+IFR2+MS+sag(5) 3,823.03 48.55 265.70 3,455.04 3,398.84 -23.91 -1,226.54 6,031,032.35 468,594.68 0.81 1,138.19 MWD+IFR2+MS+sag(5) 3,918.36 47.71 266.13 3,518.66 3,462.46 -28.97 -1,297.34 6,031,027.57 468,523.86 0.94 1,202.59 MWD+IFR2+MS+sag(5) 4,013.58 47.75 266.18 3,582.71 3,526.51 -33.69 -1,367.65 6,031,023.14 468,453.55 0.06 1,266.64 MWD+IFR2+MS+sag(5) 4,108.84 51.32 267.02 3,644.52 3,588.32 -37.97 -1,439.98 6,031,019.15 468,381.20 3.81 1,332.74 MWD+IFR2+MS+sag(5) 4,203.49 54.06 266.88 3,701.89 3,645.69 -41.98 -1,515.15 6,031,015.45 468,306.03 2.90 1,401.59 MWD+IFR2+MS+sag(5) 4,300.86 56.97 265.70 3,757.01 3,700.81 -47.19 -1,595.23 6,031,010.56 468,225.93 3.15 1,474.61 MWD+IFR2+MS+sag(5) 4,398.80 58.70 262.86 3,809.16 3,752.96 -55.47 -1,677.71 6,031,002.62 468,143.43 3.02 1,548.78 MWD+IFR2+MS+sag(5) 4,493.85 61.31 259.87 3,856.68 3,800.48 -67.85 -1,759.07 6,030,990.57 468,062.03 3.87 1,620.44 MWD+IFR2+MS+sag(5) 4,584.47 65.00 259.37 3,897.60 3,841.40 -82.42 -1,838.58 6,030,976.32 467,982.46 4.10 1,689.61 MWD+IFR2+MS+sag(5) 4,684.58 67.49 257.58 3,937.92 3,881.72 -100.74 -1,928.35 6,030,958.37 467,892.63 2.98 1,767.03 MWD+IFR2+MS+sag(5) 4,779.26 68.84 257.43 3,973.14 3,916.94 -119.76 -2,014.15 6,030,939.70 467,806.76 1.43 1,840.50 MWD+IFR2+MS+sag(5) 4,871.89 70.51 256.93 4,005.31 3,949.11 -139.03 -2,098.85 6,030,920.77 467,722.00 1.87 1,912.84 MW D+I FR2+MS+sag(5) 4,965.11 71.34 257.43 4,035.78 3,979.58 -158.58 -2,184.75 6,030,901.58 467,636.02 1.02 1,986.21 MWD+IFR2+MS+sag(5) 5,063.57 71.46 258.28 4,067.18 4,010.98 -178.21 -2,275.98 6,030,882.32 467,544.73 0.83 2,064.53 MWD+IFR2+MS+sag(5) 5,159.38 71.34 258.20 4,097.74 4,041.54 -196.72 -2,364.88 6,030,864.17 467,455.76 0.15 2,141.07 MWD+IFR2+MS+sag(5) 5,254.53 71.20 258.00 4,128.29 4,072.09 -215.30 -2,453.05 6,030,845.95 467,367.52 0.25 2,216.91 MWD+I FR2+MS+sag(5) 5,345.36 70.63 257.39 4,157.99 4,101.79 -233.59 -2,536.92 6,030,828.00 467,283.59 0.89 2,288.82 MWD+IFR2+MS+sag(5) 5,441.12 71.23 257.83 4,189.28 4,133.08 -253.01 -2,625.31 6,030,808.94 467,195.13 0.76 2,364.57 MWD+I F R2+MS+sag(5) 5,536.74 71.07 258.19 4,220.17 4,163.97 -271.81 -2,713.83 6,030,790.51 467,106.54 0.39 2,440.65 MWD+I FR2+MS+sag(5) 5,631.50 70.36 258.20 4,251.47 4,195.27 -290.11 -2,801.38 6,030,772.57 467,018.93 0.75 2,516.00 MWD+IFR2+MS+sag(5) 5,727.44 70.95 258.18 4,283.25 4,227.05 -308.63 -2,889.99 6,030,754.40 466,930.25 0.62 2,592.26 MWD+IFR2+MS+sag(5) 5,824.68 70.61 258.07 4,315.26 4,259.06 -327.53 -2,979.84 6,030,735.87 466,840.33 0.37 2,669.56 MWD+IFR2+MS+sag(5) 5,917.59 70.86 257.56 4,345.92 4,289.72 -346.04 -3,065.57 6,030,717.71 466,754.54 0.58 2,743.14 MWD+I FR2+MS+sag(5) 6,011.23 71.05 257.12 4,376.47 4,320.27 -365.44 -3,151.94 6,030,698.66 466,668.11 0.49 2,816.99 MWD+IFR2+MS+sag(5) 6,109.85 70.29 255.57 4,409.12 4,352.92 -387.41 -3,242.36 6,030,677.07 466,577.60 1.67 2,893.74 MWD+IFR2+MS+sag(5) 6,206.00 70.35 256.98 4,441.50 4,385.30 -408.89 -3,330.31 6,030,655.95 466,489.58 1.38 2,968.33 MWD+IFR2+MS+sag(5) 6,296.96 70.47 257.77 4,472.00 4,415.80 -427.62 -3,413.93 6,030,637.56 466,405.89 0.83 3,039.86 MWD+IFR2+MS+sag(5) 6,392.50 70.96 258.81 4,503.55 4,447.35 -445.92 -3,502.23 6,030,619.62 466,317.52 1.15 3,115.92 MWD+IFR2+MS+sag(5) 6,487.74 71.03 259.25 4,534.57 4,478.37 -463.05 -3,590.63 6,030,602.84 466,229.06 0.44 3,192.48 MWD+IFR2+MS+sag(5) 6,582.74 70.87 258.69 4,565.57 4,509.37 -480.23 -3,678.77 6,030,586.02 466,140.86 0.58 3,268.78 MWD+IFR2+MS+sag(5) 6,677.75 70.73 259.06 4,596.82 4,540.62 -497.54 -3,766.81 6,030,569.07 466,052.76 0.40 3,344.94 MWD+IFR2+MS+sag(5) 6,773.48 71.16 258.45 4,628.07 4,571.87 -515.19 -3,855.56 6,030,551.79 465,963.95 0.75 3,421.65 MWD+IFR2+MS+sag(5) 6,868.81 71.27 257.68 4,658.77 4,602.57 -533.85 -3,943.86 6,030,533.48 465,875.59 0.77 3,497.57 MWD+IFR2+MS+sag(5) 6,964.81 70.80 259.14 4,689.97 4,633.77 -552.10 -4,032.79 6,030,515.61 465,786.59 1.52 3,574.24 MWD+IFR2+MS+sag(5) 7,058.66 71.73 258.75 4,720.12 4,663.92 -569.14 -4,120.02 6,030,498.92 465,699.30 1.07 3,649.74 MWD+IFR2+MS+sag(5) 7,155.94 70.48 258.65 4,751.62 4,695.42 -587.17 -4,210.27 6,030,481.25 465,608.99 1.29 3,727.72 MWD+IFR2+MS+sag(5) 1/31/2011 9:36:16AM Page 4 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB1 Database: .Pioneer 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 7,249.11 70.27 258.33 4,782.91 4,726.71 -604.68 -4,296.26 6,030,464.09 465,522.93 0.39 3,801.89 MWD+IFR2+MS+sag(5) 7,345.08 71.16 258.01 4,814.61 4,758.41 -623.25 -4,384.92 6,030,445.88 465,434.21 0.98 3,878.19 MWD+IFR2+MS+sag(5) 7,441.17 70.89 257.84 4,845.85 4,789.65 -642.26 -4,473.78 6,030,427.24 465,345.28 0.33 3,954.51 MWD+IFR2+MS+sag(5) 7,536.09 69.56 258.34 4,877.96 4,821.76 -660.70 -4,561.18 6,030,409.16 465,257.82 1.49 4,029.68 MWD+IFR2+MS+sag(5) 7,626.41 69.56 260.20 4,909.51 4,853.31 -676.45 -4,644.33 6,030,393.74 465,174.61 1.93 4,101.82 MWD+IFR2+MS+sag(5) 7,726.42 69.36 260.00 4,944.60 4,888.40 -692.56 -4,736.58 6,030,378.02 465,082.30 0.27 4,182.35 MWD+IFR2+MS+sag(5) 7,820.69 69.02 260.88 4,978.09 4,921.89 -707.19 -4,823.48 6,030,363.74 464,995.36 0.94 4,258.40 MWD+IFR2+MS+sag(5) 7,915.20 69.21 260.17 5,011.78 4,955.58 -721.73 -4,910.57 6,030,349.56 464,908.21 0.73 4,334.66 MWD+IFR2+MS+sag(5) 8,011.00 69.69 260.57 5,045.41 4,989.21 -736.73 -4,999.01 6,030,334.91 464,819.72 0.64 4,412.02 MWD+IFR2+MS+sag(5) 8,106.40 69.26 260.81 5,078.86 5,022.66 -751.19 -5,087.18 6,030,320.82 464,731.51 0.51 4,489.31 MWD+IFR2+MS+sag(5) 8,201.28 69.17 260.04 5,112.53 5,056.33 -765.94 -5,174.65 6,030,306.42 464,643.99 0.76 4,565.85 MWD+IFR2+MS+sag(5) 8,296.82 69.86 258.87 5,145.97 5,089.77 -782.32 -5,262.63 6,030,290.40 464,555.95 1.36 4,642.29 MWD+IFR2+MS+sag(5) 8,392.12 69.57 258.47 5,179.00 5,122.80 -799.88 -5,350.28 6,030,273.19 464,468.24 0.50 4,718.00 MWD+IFR2+MS+sag(5) 8,486.56 69.62 258.49 5,211.93 5,155.73 -817.56 -5,437.01 6,030,255.87 464,381.44 0.06 4,792.81 MWD+IFR2+MS+sag(5) 8,582.82 69.31 258.03 5,245.70 5,189.50 -835.90 -5,525.27 6,030,237.89 464,293.12 0.55 4,868.81 MWD+IFR2+MS+sag(5) 8,680.14 70.39 257.88 5,279.22 5,223.02 -854.97 -5,614.62 6,030,219.19 464,203.70 1.12 4,945.57 MWD+IFR2+MS+sag(5) 8,775.17 69.41 258.59 5,311.88 5,255.68 -873.16 -5,701.98 6,030,201.35 464,116.27 1.25 5,020.79 MWD+IFR2+MS+sag(5) 8,869.17 68.90 258.44 5,345.33 5,289.13 -890.66 -5,788.07 6,030,184.21 464,030.12 0.56 5,095.06 MWD+IFR2+MS+sag(5) 8,966.69 68.95 258.91 5,380.40 5,324.20 -908.53 -5,877.30 6,030,166.70 463,940.84 0.45 5,172.14 MWD+IFR2+MS+sag(5) 9,058.61 69.53 262.00 5,412.98 5,356.78 -922.77 -5,962.05 6,030,152.80 463,856.04 3.21 5,246.31 MWD+IFR2+MS+sag(5) 9,109.89 69.65 263.61 5,430.87 5,374.67 -928.79 -6,009.73 6,030,146.98 463,808.34 2.95 5,288.75 MWD+IFR2+MS+sag(5) 9,183.00 68.97 267.26 5,456.71 5,400.51 -934.24 -6,077.89 6,030,141.81 463,740.16 4.76 5,350.54 MWD+IFR2+MS+sag(6) 9,277.66 69.49 269.70 5,490.28 5,434.08 -936.58 -6,166.36 6,030,139.82 463,651.69 2.47 5,432.42 MWD+IFR2+MS+sag(6) 9,373.04 69.27 271.60 5,523.87 5,467.67 -935.57 -6,255.62 6,030,141.20 463,562.45 1.88 5,516.22 MWD+IFR2+MS+sag(6) 9,468.40 69.84 273.65 5,557.18 5,500.98 -931.48 -6,344.87 6,030,145.65 463,473.22 2.10 5,601.12 MWD+IFR2+MS+sag(6) 9,563.51 69.48 277.43 5,590.25 5,534.05 -922.87 -6,433.61 6,030,154.62 463,384.52 3.75 5,687.14 MWD+IFR2+MS+sag(6) 9,658.71 70.56 280.65 5,622.79 5,566.59 -908.81 -6,521.96 6,030,169.04 463,296.25 3.38 5,774.72 MWD+IFR2+MS+sag(6) 9,754.19 70.28 282.55 5,654.79 5,598.59 -890.72 -6,610.07 6,030,187.48 463,208.21 1.90 5,863.52 MWD+IFR2+MS+sag(6) 9,848.39 70.14 284.51 5,686.69 5,630.49 -869.99 -6,696.24 6,030,208.56 463,122.14 1.96 5,951.44 MWD+IFR2+MS+sag(6) 9,943.55 70.74 288.01 5,718.55 5,662.35 -844.88 -6,782.31 6,030,234.02 463,036.18 3.52 6,040.81 MWD+IFR2+MS+sag(6) 10,038.11 71.33 290.47 5,749.29 5,693.09 -815.41 -6,866.73 6,030,263.82 462,951.89 2.54 6,130.19 MWD+IFR2+MS+sag(6) 10,133.74 71.78 292.74 5,779.55 5,723.35 -782.01 -6,951.07 6,030,297.57 462,867.70 2.30 6,220.90 MWD+IFR2+MS+sag(6) 10,229.44 73.13 296.75 5,808.41 5,752.21 -743.81 -7,033.91 6,030,336.09 462,785.02 4.24 6,311.90 MWD+IFR2+MS+sag(6) 10,324.07 74.43 300.97 5,834.85 5,778.65 -699.96 -7,113.46 6,030,380.27 462,705.66 4.50 6,401.84 MWD+IFR2+MS+sag(6) 10,419.48 74.23 301.99 5,860.62 5,804.42 -651.99 -7,191.80 6,030,428.55 462,627.52 1.05 6,492.11 MWD+IFR2+MS+sag(6) 10,515.22 74.05 303.89 5,886.79 5,830.59 -601.91 -7,269.09 6,030,478.93 462,550.44 1.92 6,582.13 MWD+IFR2+MS+sag(6) 10,609.62 75.40 306.68 5,911.66 5,855.46 -549.31 -7,343.41 6,030,531.83 462,476.34 3.19 6,670.29 MWD+IFR2+MS+sag(6) 10,705.95 76.48 309.31 5,935.07 5,878.87 -491.79 -7,417.04 6,030,589.64 462,402.96 2.88 6,759.54 MWD+IFR2+MS+sag(6) 10,800.40 77.68 312.11 5,956.19 5,899.99 -431.75 -7,486.81 6,030,649.96 462,333.44 3.16 6,846.08 MWD+IFR2+MS+sag(6) 10,895.77 76.91 316.41 5,977.18 5,920.98 -366.84 -7,553.42 6,030,715.13 462,267.09 4.47 6,931.39 MWD+IFR2+MS+sag(6) 1/31/2011 9:36:16AM Page 5 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB1 Database: .Pioneer 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 10,991.70 76.66 319.98 5,999.11 5,942.91 -297.24 -7,615.67 6,030,784.98 462,205.14 3.63 7,014.29 MWD+IFR2+MS+sag(6) 11,086.42 76.09 325.02 . 6,021.44 5,965.24 -224.24 -7,671.69 6,030,858.20 462,149.42 5.21 7,092.57 MWD+IFR2+MS+sag(6) 11,180.47 76.48 328.79 6,043.74 5,987.54 -147.71 -7,721.57 6,030,934.93 462,099.86 3.92 7,166.37 MWD+IFR2+MS+sag(6) 11,276.79 76.99 332.18 6,065.85 6,009.65 -66.13 -7,767.74 6,031,016.68 462,054.02 3.47 7,238.49 MWD+IFR2+MS+sag(6) 11,372.24 79.59 335.41 6,085.23 6,029.03 17.71 -7,809.00 6,031,100.68 462,013.11 4.29 7,306.82 MWD+IFR2+MS+sag(6) 11,467.58 80.82 335.40 6,101.45 6,045.25 103.13 -7,848.10 6,031,186.25 461,974.36 1.29 7,373.69 MWD+IFR2+MS+sag(6) 11,562.23 80.38 335.28 6,116.91 6,060.71 188.00 -7,887.06 6,031,271.26 461,935.75 0.48 7,440.24 MWD+IFR2+MS+sag(6) 11,657.90 80.01 336.55 6,133.20 6,077.00 274.06 -7,925.53 6,031,357.47 461,897.63 1.36 7,506.75 MWD+IFR2+MS+sag(6) 11,753.05 80.13 336.68 6,149.61 6,093.41 360.09 -7,962.73 6,031,443.64 461,860.78 0.18 7,572.06 MWD+IFR2+MS+sag(6) 11,847.02 80.62 336.06 6,165.32 6,109.12 444.96 -7,999.86 6,031,528.66 461,824.00 0.83 7,636.91 MWD+IFR2+MS+sag(6) 11,890.00 80.62 336.06 6,172.32 6,116.12 483.72 -8,017.07 6,031,567.48 461,806.95 0.00 7,666.75 PROJECTED to TD 1/31/2011 9.36:16AM Page 6 COMPASS 2003.16 Build 42F s 1 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB2 Database: .Pioneer 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 ODSN-18-Slot ODS-18 Well Position +N/-S 0.00 ft Northing: 6,031,051.27 ft Latitude: 70°29'45.254 N +E/-W 0.00 ft Easting: 469,821.18 ft Longitude: 150°14'48.375 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSN-18 PB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (7) (7) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-18 PN11 PB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,438.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 290.79 Survey Program Date 1/27/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 141.00 981.00 ODSN-18 PB1 Gyro 1 (ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 10/25/2010 1,027.50 1,027.50 ODSN-18 PB1 MWD 1 (ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/2/2010 t 1,123.00 1,123.00 ODSN-18 PB1 Gyro 2(ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 11/2/2010 1: 1,174.40 3,566.40 ODSN-18 PB1 MWD 2(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/26/2010 3,630.10 8,392.12 ODSN-18 PB1 MWD 3(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/1/2010 1: ' 8,438.00 13,381.84 ODSN-18 PB2 MWD 4(ODSN-18 PB2) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/5/2010 1: Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (7) (7) (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 6,031,051.27 469,821.18 0.00 0.00 UNDEFINED 141.00 0.26 304.00 141.00 84.80 0.13 -0.19 6,031,051.40 469,820.99 0.26 0.22 SR-Gyro-SS(1) 199.00 0.27 348.71 199.00 142.80 0.33 -0.32 6,031,051.60 469,820.86 0.35 0.42 SR-Gyro-SS(1) 232.00 0.49 322.56 232.00 175.80 0.52 -0.42 6,031,051.79 469,820.76 0.83 0.58 SR-Gyro-SS(1) 1 290.00 0.48 322.52 290.00 233.80 0.91 -0.72 6,031,052.18 469,820.46 0.02 1.00 SR-Gyro-SS(1) 323.00 0.93 308.43 322.99 266.79 1.19 -1.02 6,031,052.46 469,820.17 1.45 1.37 SR-Gyro-SS(1) 382.00 1.25 295.72 381.98 325.78 1.76 -1.97 6,031,053.04 469,819.22 0.68 2.47 SR-Gyro-SS(1) 415.00 1.90 288.47 414.97 358.77 2.09 -2.81 6,031,053.38 469,818.38 2.06 3.37 SR-Gyro-SS(1) 472.00 2.17 284.07 471.93 415.73 2.66 -4.76 6,031,053.94 469,816.43 0.55 5.39 SR-Gyro-SS(1) 505.00 2.74 284.05 504.90 448.70 3.00 -6.13 6,031,054.29 469,815.06 1.73 6.79 SR-Gyro-SS(1) 1/31/2011 9:34:53AM Page 2 COMPASS 2003.16 Build 42F , Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB2 Database: .Pioneer 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 568.00 3.14 281.82 567.82 511.62 3.72 -9.28 6,031,055.03 469,811.92 0.66 9.99 SR-Gyro-SS(1) 601.00 3.54 281.44 600.76 544.56 4.11 -11.16 6,031,055.42 469,810.04 1.21 11.89 SR-Gyro-SS(1) 662.00 3.66 281.14 661.64 605.44 4.86 -14.92 6,031,056.19 469,806.28 0.20 15.67 SR-Gyro-SS(1) 685.00 3.95 280.22 684.59 628.39 5.14 -16.42 6,031,056.47 469,804.79 1.29 17.17 SR-Gyro-SS(1) 758.00 4.41 281.46 757.40 701.20 6.14 -21.64 6,031,057.50 469,799.57 0.64 22.41 SR-Gyro-SS(1) 791.00 4.78 281.29 790.29 734.09 6.66 -24.23 6,031,058.03 469,796.98 1.12 25.02 SR-Gyro-SS(1) 853.00 5.29 282.35 852.05 795.85 7.78 -29.56 6,031,059.17 469,791.66 0.84 30.39 SR-Gyro-SS(1) 886.00 5.85 279.85 884.90 828.70 8.39 -32.70 6,031,059.79 469,788.52 1.85 33.55 SR-Gyro-SS(1) 948.00 6.88 279.90 946.51 890.31 9.57 -39.47 6,031,061.00 469,781.75 1.66 40.30 SR-Gyro-SS(1) 981.00 6.89 278.10 979.28 923.08 10.19 -43.38 6,031,061.64 469,777.85 0.65 44.17 SR-Gyro-SS(1) 1,027.53 6.83 276.30 1,025.47 969.27 10.89 -48.89 6,031,062.35 469,772.34 0.48 49.57 MWD+IFR2+MS+sag(2) 1,123.00 9.55 277.06 1,119.96 1,063.76 12.48 -62.40 6,031,064.01 469,758.84 2.85 62.76 SR-Gyro-SS(3) 1,174.43 9.71 277.20 1,170.67 1,114.47 13.55 -70.93 6,031,065.11 469,750.31 0.31 71.12 MWD+IFR2+MS+sag(4) 1,218.54 9.91 278.29 1,214.13 1,157.93 14.57 -78.38 6,031,066.15 469,742.87 0.62 78.45 MWD+IFR2+MS+sag(4) 1,314.10 9.75 271.65 1,308.29 1,252.09 15.98 -94.61 6,031,067.64 469,726.65 1.20 94.12 MWD+IFR2+MS+sag(4) 1,409.32 10.15 272.52 1,402.08 1,345.88 16.59 -111.05 6,031,068.30 469,710.21 0.45 109.70 MWD+IFR2+MS+sag(4) 1,504.37 10.95 274.95 1,495.52 1,439.32 17.73 -128.41 6,031,069.52 469,692.86 0.96 126.34 MWD+IFR2+MS+sag(4) 1,599.91 12.48 272.29 1,589.07 1,532.87 18.93 -147.77 6,031,070.80 469,673.51 1.70 144.86 MWD+IFR2+MS+sag(4) 1,631.69 12.76 273.11 1,620.08 1,563.88 19.26 -154.70 6,031,071.15 469,666.57 1.05 151.46 MWD+IFR2+MS+sag(4) 1,725.28 14.37 274.13 1,711.06 1,654.86 20.65 -176.61 6,031,072.64 469,644.68 1.74 172.44 MWD+IFR2+MS+sag(4) 1,821.10 13.44 273.34 1,804.07 1,747.87 22.16 -199.58 6,031,074.24 469,621.71 0.99 194.45 MWD+IFR2+MS+sag(4) 1,915.58 15.28 274.70 1,895.59 1,839.39 23.82 -222.95 6,031,075.99 469,598.35 1.98 216.89 MWD+IFR2+MS+sag(4) 2,011.74 15.85 275.48 1,988.23 1,932.03 26.11 -248.65 6,031,078.39 469,572.66 0.63 241.73 MWD+IFR2+MS+sag(4) 2,107.39 14.66 274.53 2,080.51 2,024.31 28.31 -273.72 6,031,080.69 469,547.60 1.27 265.95 MWD+IFR2+MS+sag(4) 2,202.94 13.62 277.80 2,173.16 2,116.96 30.80 -296.92 6,031,083.27 469,524.41 1.37 288.52 MWD+IFR2+MS+sag(4) 2,241.41 13.96 276.43 2,210.52 2,154.32 31.93 -306.02 6,031,084.44 469,515.32 1.23 297.43 MWD+IFR2+MS+sag(4) 2,298.61 14.97 276.21 2,265.91 2,209.71 33.50 -320.22 6,031,086.07 469,501.13 1.77 311.26 MWD+IFR2+MS+sag(4) 2,333.40 15.89 274.27 2,299.44 2,243.24 34.34 -329.44 6,031,086.95 469,491.92 3.03 320.18 MWD+IFR2+MS+sag(4) 2,393.28 16.92 271.13 2,356.89 2,300.69 35.12 -346.33 6,031,087.80 469,475.03 2.27 336.24 MWD+IFR2+MS+sag(4) 2,488.03 20.47 266.74 2,446.63 2,390.43 34.45 -376.67 6,031,087.25 469,444.70 4.03 364.37 MWD+IFR2+MS+sag(4) 2,583.22 24.38 267.73 2,534.60 2,478.40 32.73 -412.93 6,031,085.67 469,408.43 4.13 397.66 MWD+IFR2+MS+sag(4) 2,678.36 29.60 267.12 2,619.35 2,563.15 30.77 -456.05 6,031,083.89 469,365.31 5.49 437.27 MWD+IFR2+MS+sag(4) 2,773.39 32.86 268.44 2,700.60 2,644.40 28.89 -505.27 6,031,082.21 469,316.08 3.51 482.62 MWD+IFR2+MS+sag(4) 2,868.92 36.48 268.01 2,779.16 2,722.96 27.20 -559.58 6,031,080.73 469,261.77 3.80 532.79 MWD+IFR2+MS+sag(4) 2,963.62 38.66 267.56 2,854.21 2,798.01 24.96 -617.27 6,031,078.73 469,204.08 2.32 585.94 MWD+IFR2+MS+sag(4) 3,059.68 38.65 266.41 2,929.23 2,873.03 21.80 -677.19 6,031,075.82 469,144.15 0.75 640.83 MWD+IFR2+MS+sag(4) 3,155.09 41.44 265.51 3,002.26 2,946.06 17.46 -738.41 6,031,071.73 469,082.92 2.99 696.53 MWD+IFR2+MS+sag(4) 3,249.55 42.15 264.91 3,072.68 3,016.48 12.20 -801.15 6,031,066.73 469,020.17 0.86 753.31 MWD+IFR2+MS+sag(4) 3,344.92 46.28 265.36 3,141.02 3,084.82 6.58 -867.40 6,031,061.37 468,953.90 4.34 813.25 MWD+IFR2+MS+sag(4) 3,439.63 48.20 265.43 3,205.32 3,149.12 0.99 -936.71 6,031,056.07 468,884.58 2.03 876.07 MWD+IFR2+MS+sag(4) 1/31/2011 9:34:53AM Page 3 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.201t(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB2 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°11001 (ft) Survey Tool Name 3,534.85 49.89 264.83 3,267.73 3,211.53 -5.12 -1,008.36 6,031,050.25 468,812.91 1.84 940.88 MWD+IFR2+MS+sag(4) 3,566.42 50.37 265.46 3,287.97 3,231.77 -7.17 -1,032.50 6,031,048.30 468,788.76 2.16 962.73 MWD+IFR2+MS+sag(4) 3,630.15 49.94 264.80 3,328.80 3,272.60 -11.32 -1,081.25 6,031,044.34 468,740.00 1.04 1,006.83 MWD+IFR2+MS+sag(5) 3,728.64 48.98 264.86 3,392.82 3,336.62 -18.06 -1,155.80 6,031,037.90 468,665.44 0.98 1,074.13 MWD+IFR2+MS+sag(5) 3,823.03 48.55 265.70 3,455.04 3,398.84 -23.91 -1,226.54 6,031,032.35 468,594.68 0.81 1,138.19 MWD+IFR2+MS+sag(5) 3,918.36 47.71 266.13 3,518.66 3,462.46 -28.97 -1,297.34 6,031,027.57 468,523.86 0.94 1,202.59 MWD+IFR2+MS+sag(5) 4,013.58 47.75 266.18 3,582.71 3,526.51 -33.69 -1,367.65 6,031,023.14 468,453.55 0.06 1,266.64 MWD+IFR2+MS+sag(5) 4,108.84 51.32 267.02 3,644.52 3,588.32 -37.97 -1,439.98 6,031,019.15 468,381.20 3.81 1,332.74 MWD+IFR2+MS+sag(5) 4,203.49 54.06 266.88 3,701.89 3,645.69 -41.98 -1,515.15 6,031,015.45 468,306.03 2.90 1,401.59 MWD+IFR2+MS+sag(5) 4,300.86 56.97 265.70 3,757.01 3,700.81 -47.19 -1,595.23 6,031,010.56 468,225.93 3.15 1,474.61 MWD+IFR2+MS+sag(5) 4,398.80 58.70 262.86 3,809.16 3,752.96 -55.47 -1,677.71 6,031,002.62 468,143.43 3.02 1,548.78 MWD+IFR2+MS+sag(5) 4,493.85 61.31 259.87 3,856.68 3,800.48 -67.85 -1,759.07 6,030,990.57 468,062.03 3.87 1,620.44 MWD+IFR2+MS+sag(5) 4,584.47 65.00 259.37 3,897.60 3,841.40 -82.42 -1,838.58 6,030,976.32 467,982.46 4.10 1,689.61 MWD+IFR2+MS+sag(5) 4,684.58 67.49 257.58 3,937.92 3,881.72 -100.74 -1,928.35 6,030,958.37 467,892.63 2.98 1,767.03 MWD+IFR2+MS+sag(5) 4,779.26 68.84 257.43 3,973.14 3,916.94 -119.76 -2,014.15 6,030,939.70 467,806.76 1.43 1,840.50 MWD+IFR2+MS+sag(5) 4,871.89 70.51 256.93 4,005.31 3,949.11 -139.03 -2,098.85 6,030,920.77 467,722.00 1.87 1,912.84 MWD+IFR2+MS+sag(5) 4,965.11 71.34 257.43 4,035.78 3,979.58 -158.58 -2,184.75 6,030,901.58 467,636.02 1.02 1,986.21 MWD+IFR2+MS+sag(5) 5,063.57 71.46 258.28 4,067.18 4,010.98 -178.21 -2,275.98 6,030,882.32 467,544.73 0.83 2,064.53 MWD+IFR2+MS+sag(5) 5,159.38 71.34 258.20 4,097.74 4,041.54 -196.72 -2,364.88 6,030,864.17 467,455.76 0.15 2,141.07 MWD+IFR2+MS+sag(5) 5,254.53 71.20 258.00 4,128.29 4,072.09 -215.30 -2,453.05 6,030,845.95 467,367.52 0.25 2,216.91 MWD+IFR2+MS+sag(5) 5,345.36 70.63 257.39 4,157.99 4,101.79 -233.59 -2,536.92 6,030,828.00 467,283.59 0.89 2,288.82 MWD+IFR2+MS+sag(5) 5,441.12 71.23 257.83 4,189.28 4,133.08 -253.01 -2,625.31 6,030,808.94 467,195.13 0.76 2,364.57 MWD+IFR2+MS+sag(5) 5,536.74 71.07 258.19 4,220.17 4,163.97 -271.81 -2,713.83 6,030,790.51 467,106.54 0.39 2,440.65 MWD+IFR2+MS+sag(5) 5,631.50 70.36 258.20 4,251.47 4,195.27 -290.11 -2,801.38 6,030,772.57 467,018.93 0.75 2,516.00 MWD+IFR2+MS+sag(5) 5,727.44 70.95 258.18 4,283.25 4,227.05 -308.63 -2,889.99 6,030,754.40 466,930.25 0.62 2,592.26 MWD+IFR2+MS+sag(5) 5,824.68 70.61 258.07 4,315.26 4,259.06 -327.53 -2,979.84 6,030,735.87 466,840.33 0.37 2,669.56 MWD+IFR2+MS+sag(5) 5,917.59 70.86 257.56 4,345.92 4,289.72 -346.04 -3,065.57 6,030,717.71 466,754.54 0.58 2,743.14 MWD+IFR2+MS+sag(5) 6,011.23 71.05 257.12 4,376.47 4,320.27 -365.44 -3,151.94 6,030,698.66 466,668.11 0.49 2,816.99 MWD+IFR2+MS+sag(5) 6,109.85 70.29 255.57 4,409.12 4,352.92 -387.41 -3,242.36 6,030,677.07 466,577.60 1.67 2,893.74 MWD+IFR2+MS+sag(5) 6,206.00 70.35 256.98 4,441.50 4,385.30 -408.89 -3,330.31 6,030,655.95 466,489.58 1.38 2,968.33 MWD+IFR2+MS+sag(5) 6,296.96 70.47 257.77 4,472.00 4,415.80 -427.62 -3,413.93 6,030,637.56 466,405.89 0.83 3,039.86 MWD+IFR2+MS+sag(5) 6,392.50 70.96 258.81 4,503.55 4,447.35 -445.92 -3,502.23 6,030,619.62 466,317.52 1.15 3,115.92 MWD+IFR2+MS+sag(5) 6,487.74 71.03 259.25 4,534.57 4,478.37 -463.05 -3,590.63 6,030,602.84 466,229.06 0.44 3,192.48 MWD+IFR2+MS+sag(5) 6,582.74 70.87 258.69 4,565.57 4,509.37 -480.23 -3,678.77 6,030,586.02 466,140.86 0.58 3,268.78 MWD+IFR2+MS+sag(5) 6,677.75 70.73 259.06 4,596.82 4,540.62 -497.54 -3,766.81 6,030,569.07 466,052.76 0.40 3,344.94 MWD+IFR2+MS+sag(5) 6,773.48 71.16 258.45 4,628.07 4,571.87 -515.19 -3,855.56 6,030,551.79 465,963.95 0.75 3,421.65 MWD+IFR2+MS+sag(5) 6,868.81 71.27 257.68 4,658.77 4,602.57 -533.85 -3,943.86 6,030,533.48 465,875.59 0.77 3,497.57 MWD+IFR2+MS+sag(5) 6,964.81 70.80 259.14 4,689.97 4,633.77 -552.10 -4,032.79 6,030,515.61 465,786.59 1.52 3,574.24 MWD+IFR2+MS+sag(5) 7,058.66 71.73 258.75 4,720.12 4,663.92 -569.14 -4,120.02 6,030,498.92 465,699.30 1.07 3,649.74 MWD+IFR2+MS+sag(5) 7,155.94 70.48 258.65 4,751.62 4,695.42 -587.17 -4,210.27 6,030,481.25 465,608.99 1.29 3,727.72 MWD+IFR2+MS+sag(5) 1/31/2011 9:34:53AM Page 4 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB2 Database: .Pioneer 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 7,249.11 70.27 258.33 4,782.91 4,726.71 -604.68 -4,296.26 6,030,464.09 465,522.93 0.39 3,801.89 MWD+IFR2+MS+sag(5) 7,345.08 71.16 258.01 4,814.61 4,758.41 -623.25 -4,384.92 6,030,445.88 465,434.21 0.98 3,878.19 MWD+IFR2+MS+sag(5) 7,441.17 70.89 257.84 4,845.85 4,789.65 -642.26 -4,473.78 6,030,427.24 465,345.28 0.33 3,954.51 MWD+IFR2+MS+sag(5) 7,536.09 69.56 258.34 4,877.96 4,821.76 -660.70 -4,561.18 6,030,409.16 465,257.82 1.49 4,029.68 MWD+IFR2+MS+sag(5) 7,626.41 69.56 260.20 4,909.51 4,853.31 -676.45 -4,644.33 6,030,393.74 465,174.61 1.93 4,101.82 MWD+IFR2+MS+sag(5) 7,726.42 69.36 260.00 4,944.60 4,888.40 -692.56 -4,736.58 6,030,378.02 465,082.30 0.27 4,182.35 MWD+IFR2+MS+sag(5) 7,820.69 69.02 260.88 4,978.09 4,921.89 -707.19 -4,823.48 6,030,363.74 464,995.36 0.94 4,258.40 MWD+IFR2+MS+sag(5) 7,915.20 69.21 260.17 5,011.78 4,955.58 -721.73 -4,910.57 6,030,349.56 464,908.21 0.73 4,334.66 MWD+IFR2+MS+sag(5) 8,011.00 69.69 260.57 5,045.41 4,989.21 -736.73 -4,999.01 6,030,334.91 464,819.72 0.64 4,412.02 MWD+IFR2+MS+sag(5) 8,106.40 69.26 260.81 5,078.86 5,022.66 -751.19 -5,087.18 6,030,320.82 464,731.51 0.51 4,489.31 MWD+IFR2+MS+sag(5) 8,201.28 69.17 260.04 5,112.53 5,056.33 -765.94 -5,174.65 6,030,306.42 464,643.99 0.76 4,565.85 MWD+IFR2+MS+sag(5) 8,296.82 69.86 258.87 5,145.97 5,089.77 -782.32 -5,262.63 6,030,290.40 464,555.95 1.36 4,642.29 MWD+IFR2+MS+sag(5) 8,392.12 69.57 258.47 5,179.00 5,122.80 -799.88 -5,350.28 6,030,273.19 464,468.24 0.50 4,718.00 MWD+IFR2+MS+sag(5) 8,438.00 69.60 258.48 5,195.01 5,138.81 -808.47 -5,392.41 6,030,264.77 464,426.07 0.07 4,754.33 MWD+IFR2+MS+sag(6) 8,529.05 72.36 255.25 5,224.69 5,168.49 -828.05 -5,476.21 6,030,245.54 464,342.20 4.52 4,825.73 MWD+IFR2+MS+sag(6) 8,575.56 73.36 254.40 5,238.39 5,182.19 -839.68 -5,519.11 6,030,234.08 464,299.27 2.77 4,861.70 MWD+IFR2+MS+sag(6) 8,670.27 74.48 252.70 5,264.63 5,208.43 -865.46 -5,606.38 6,030,208.67 464,211.90 2.09 4,934.14 MWD+IFR2+MS+sag(6) 8,718.63 74.39 251.47 5,277.60 5,221.40 -879.79 -5,650.71 6,030,194.52 464,167.52 2.46 4,970.50 MWD+IFR2+MS+sag(6) 8,785.71 74.04 252.09 5,295.85 5,239.65 -899.97 -5,712.02 6,030,174.59 464,106.13 1.03 5,020.66 MWD+IFR2+MS+sag(6) 8,881.94 73.38 251.52 5,322.84 5,266.64 -928.81 -5,799.77 6,030,146.10 464,018.28 0.89 5,092.45 MWD+IFR2+MS+sag(6) 8,977.86 73.11 252.53 5,350.50 5,294.30 -957.15 -5,887.13 6,030,118.12 463,930.81 1.05 5,164.07 MWD+IFR2+MS+sag(6) 9,072.22 72.75 254.47 5,378.20 5,322.00 -982.77 -5,973.61 6,030,092.85 463,844.23 2.00 5,235.83 MWD+IFR2+MS+sag(6) 9,168.00 72.53 256.55 5,406.78 5,350.58 -1,005.65 -6,062.12 6,030,070.34 463,755.64 2.09 5,310.45 MWD+IFR2+MS+sag(6) 9,262.77 72.47 260.99 5,435.29 5,379.09 -1,023.24 -6,150.74 6,030,053.11 463,666.95 4.47 5,387.06 MWD+IFR2+MS+sag(6) 9,357.47 72.46 264.53 5,463.83 5,407.63 -1,034.62 -6,240.31 6,030,042.09 463,577.35 3.56 5,466.75 MWD+IFR2+MS+sag(6) 9,452.53 71.85 267.34 5,492.97 5,436.77 -1,041.04 -6,330.55 6,030,036.04 463,487.09 2.89 5,548.84 MWD+IFR2+MS+sag(6) 9,547.64 72.27 271.43 5,522.27 5,466.07 -1,042.01 -6,421.01 6,030,035.44 463,396.64 4.11 5,633.07 MWD+IFR2+MS+sag(6) 9,642.41 72.06 275.01 5,551.31 5,495.11 -1,036.94 -6,511.07 6,030,040.87 463,306.61 3.60 5,719.06 MWD+IFR2+MS+sag(6) 9,737.67 71.99 278.14 5,580.71 5,524.51 -1,026.57 -6,601.07 6,030,051.61 463,216.66 3.13 5,806.88 MWD+IFR2+MS+sag(6) 9,833.18 71.37 281.53 5,610.74 5,554.54 -1,011.09 -6,690.39 6,030,067.45 463,127.42 3.43 5,895.88 MWD+IFR2+MS+sag(6) 9,929.57 71.41 286.08 5,641.51 5,585.31 -989.30 -6,779.07 6,030,089.60 463,038.83 4.47 5,986.53 MWD+IFR2+MS+sag(6) 10,024.64 71.38 289.64 5,671.85 5,615.65 -961.67 -6,864.82 6,030,117.57 462,953.21 3.55 6,076.49 MWD+IFR2+MS+sag(6) 10,118.68 72.08 292.42 5,701.34 5,645.14 -929.62 -6,948.16 6,030,149.95 462,870.01 2.90 6,165.78 MWD+IFR2+MS+sag(6) 10,214.27 72.08 296.36 5,730.76 5,674.56 -892.07 -7,030.97 6,030,187.83 462,787.35 3.92 6,256.53 MWD+IFR2+MS+sag(6) 10,309.31 71.94 299.25 5,760.12 5,703.92 -849.92 -7,110.92 6,030,230.31 462,707.59 2.90 6,346.24 MWD+IFR2+MS+sag(6) 10,404.13 72.22 300.94 5,789.30 5,733.10 -804.68 -7,188.97 6,030,275.86 462,629.73 1.72 6,435.27 MWD+IFR2+MS+sag(6) 10,498.75 73.56 303.93 5,817.14 5,760.94 -756.17 -7,265.28 6,030,324.67 462,553.62 3.34 6,523.82 MWD+IFR2+MS+sag(6) 10,593.70 74.26 308.42 5,843.47 5,787.27 -702.34 -7,338.90 6,030,378.80 462,480.23 4.60 6,611.75 MWD+IFR2+MS+sag(6) 10,689.51 74.46 309.71 5,869.30 5,813.10 -644.19 -7,410.53 6,030,437.23 462,408.84 1.31 6,699.36 MWD+IFR2+MS+sag(6) 10,784.19 74.92 311.89 5,894.30 5,838.10 -584.53 -7,479.65 6,030,497.17 462,339.97 2.27 6,785.16 MWD+IFR2+MS+sag(6) 1/31/2011 9:34:53AM Page 5 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB2 Database: .Pioneer 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 10,879.86 74.40 314.18 5,919.61 5,863.41 -521.57 -7,547.09 6,030,560.39 462,272.80 2.37 6,870.55 MWD+IFR2+MS+sag(6) 10,975.10 74.72 315.49 5,944.97 5,888.77 -456.84 -7,612.19 6,030,625.38 462,207.97 1.37 6,954.38 MWD+IFR2+MS+sag(6) 11,070.33 75.73 317.97 5,969.26 5,913.06 -389.80 -7,675.29 6,030,692.67 462,145.14 2.73 7,037.18 MWD+IFR2+MS+sag(6) 11,166.35 75.55 321.26 5,993.08 5,936.88 -318.96 -7,735.55 6,030,763.75 462,085.18 3.32 7,118.66 MWD+IFR2+MS+sag(6) 11,261.96 75.75 324.90 6,016.78 5,960.58 -244.92 -7,791.18 6,030,838.01 462,029.85 3.69 7,196.95 MWD+I FR2+MS+sag(6) 11,357.50 76.88 328.38 6,039.39 5,983.19 -167.40 -7,842.21 6,030,915.73 461,979.14 3.73 7,272.17 MWD+IFR2+MS+sag(6) 11,451.93 77.90 332.01 6,060.02 6,003.82 -87.45 -7,888.00 6,030,995.85 461,933.68 3.90 7,343.36 MWD+IFR2+MS+sag(6) 11,547.13 79.28 336.17 6,078.86 6,022.66 -3.53 -7,928.76 6,031,079.93 461,893.27 4.52 7,411.25 MWD+IFR2+MS+sag(6) 11,642.52 79.79 339.06 6,096.19 6,039.99 83.20 -7,964.48 6,031,166.79 461,857.91 3.03 7,475.42 MWD+IFR2+MS+sag(6) 11,736.96 79.85 338.89 6,112.88 6,056.68 169.96 -7,997.83 6,031,253.68 461,824.91 0.19 7,537.40 MWD+IFR2+MS+sag(6) 11,831.99 79.89 339.14 6,129.59 6,073.39 257.31 -8,031.33 6,031,341.15 461,791.77 0.26 7,599.72 MWD+IFR2+MS+sag(6) 11,927.00 79.58 341.03 6,146.52 6,090.32 345.20 -8,063.17 6,031,429.17 461,760.29 1.98 7,660.69 MWD+IFR2+MS+sag(6) 12,022.53 80.09 342.27 6,163.38 6,107.18 434.45 -8,092.78 6,031,518.52 461,731.05 1.38 7,720.04 MWD+IFR2+MS+sag(6) 12,067.94 80.08 343.26 6,171.20 6,115.00 477.17 -8,106.03 6,031,561.30 461,717.97 2.15 7,747.59 MWD+IFR2+MS+sag(6) 12,130.35 80.46 344.34 6,181.75 6,125.55 536.24 -8,123.19 6,031,620.43 461,701.05 1.81 7,784.60 MWD+IFR2+MS+sag(6) 12,226.85 78.05 345.06 6,199.74 6,143.54 627.68 -8,148.21 6,031,711.96 461,676.41 2.60 7,840.45 MWD+IFR2+MS+sag(6) 12,323.13 79.90 344.39 6,218.15 6,161.95 718.84 -8,173.11 6,031,803.21 461,651.89 2.04 7,896.08 MWD+IFR2+MS+sag(6) 12,419.53 83.34 341.67 6,232.20 6,176.00 810.03 -8,200.94 6,031,894.51 461,624.42 4.53 7,954.48 MWD+IFR2+MS+sag(6) 12,515.15 85.33 338.85 6,241.64 6,185.44 899.58 -8,233.08 6,031,984.17 461,592.65 3.60 8,016.30 MWD+IFR2+MS+sag(6) 12,611.86 86.43 338.69 6,248.59 6,192.39 989.49 -8,268.01 6,032,074.22 461,558.09 1.15 8,080.87 MWD+I FR2+MS+sag(6) 12,709.02 86.05 335.00 6,254.96 6,198.76 1,078.62 -8,306.13 6,032,163.49 461,520.34 3.81 8,148.14 MWD+IFR2+MS+sag(6) 12,756.65 88.94 333.98 6,257.05 6,200.85 1,121.56 -8,326.62 6,032,206.51 461,500.03 6.43 8,182.54 MWD+IFR2+MS+sag(6) 12,805.33 88.59 332.68 6,258.10 6,201.90 1,165.05 -8,348.46 6,032,250.08 461,478.36 2.76 8,218.40 MWD+I FR2+MS+sag(6) 12,858.81 84.34 333.33 6,261.39 6,205.19 1,212.60 -8,372.69 6,032,297.72 461,454.33 8.04 8,257.92 MW D+I FR2+MS+sag(6) 12,900.82 83.69 333.14 6,265.77 6,209.57 1,249.90 -8,391.50 6,032,335.10 461,435.67 1.61 8,288.75 MW D+I FR2+MS+sag(6) 12,954.44 84.76 333.80 6,271.17 6,214.97 1,297.63 -8,415.33 6,032,382.92 461,412.04 2.34 8,327.97 MWD+IFR2+MS+sag(6) 12,998.29 88.76 333.26 6,273.65 6,217.45 1,336.81 -8,434.84 6,032,422.18 461,392.69 9.20 8,360.12 MWD+IFR2+MS+sag(6) 13,051.34 91.03 333.55 6,273.74 6,217.54 1,384.25 -8,458.59 6,032,469.70 461,369.14 4.31 8,399.16 MWD+IFR2+MS+sag(6) 13,093.81 90.88 332.65 6,273.03 6,216.83 1,422.12 -8,477.80 6,032,507.65 461,350.08 2.15 8,430.56 MWD+IFR2+MS+sag(6) 13,191.37 91.50 329.19 6,271.01 6,214.81 1,507.35 -8,525.20 6,032,593.06 461,303.03 3.60 8,505.12 MWD+IFR2+MS+sag(6) 13,287.26 92.68 329.55 6,267.51 6,211.31 1,589.80 -8,574.02 6,032,675.70 461,254.55 1.29 8,580.03 MWD+IFR2+MS+sag(6) 13,381.84 93.67 330.17 6,262.27 6,206.07 1,671.47 -8,621.44 6,032,757.55 461,207.47 1.23 8,653.35 MWD+IFR2+MS+sag(6) 1/31/2011 9:34:53AM Page 6 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB3 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB3 Database: .Pioneer 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 ODSN-18-Slot ODS-18 Well Position +N/-S 0.00 ft Northing: 6,031,051.27 ft Latitude: 70°29'45.254 N +E/-W 0.00 ft Easting: 469,821.18 ft Longitude: 150°14'48.375 W' Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft Wellbore ODSN-18 PB3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-18 PN11 PB3 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,090.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 273.96 Survey Program Date 1/27/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 141.00 981.00 ODSN-18 PB1 Gyro 1 (ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 10/25/2010 • 1,027.53 1,027.53 ODSN-18 PB1 MWD 1 (ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/2/2010 1: 1,123.00 1,123.00 ODSN-18 PB1 Gyro 2(ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 11/2/2010 1: 1,174.40 3,566.42 ODSN-18 PB1 MWD 2(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/26/2010 3,630.15 8,392.10 ODSN-18 PB1 MWD 3(ODSN-18 PBI) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/1/2010 1: 8,438.00 12,090.00 ODSN-18 PB2 MWD 4(ODSN-18 PB2) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/5/2010 1: 12,122.46 13,831.22 ODSN-18 PB3 MWD 5(ODSN-18 PB3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/22/2010 • 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 6,031,051.27 469,821.18 0.00 0.00 UNDEFINED 141.00 0.26 304.00 141.00 84.80 0.13 -0.19 6,031,051.40 469,820.99 0.26 0.19 SR-Gyro-SS(1) 199.00 0.27 348.71 199.00 142.80 0.33 -0.32 6,031,051.60 469,820.86 0.35 0.34 SR-Gyro-SS(1) 232.00 0.49 322.56 232.00 175.80 0.52 -0.42 6,031,051.79 469,820.76 0.83 0.46 SR-Gyro-SS(1) 290.00 0.48 322.52 290.00 233.80 0.91 -0.72 6,031,052.18 469,820.46 0.02 0.78 SR-Gyro-SS(1) , 323.00 0.93 308.43 322.99 266.79 1.19 -1.02 6,031,052.46 469,820.17 1.45 1.09 SR-Gyro-SS(1) 382.00 1.25 295.72 381.98 325.78 1.76 -1.97 6,031,053.04 469,819.22 0.68 2.09 SR-Gyro-SS(1) 415.00 1.90 288.47 414.97 358.77 2.09 -2.81 6,031,053.38 469,818.38 2.06 2.95 SR-Gyro-SS(1) 472.00 2.17 284.07 471.93 415.73 2.66 -4.76 6,031,053.94 469,816.43 0.55 4.93 SR-Gyro-SS(1) 1/31/2011 9:33:25AM Page 2 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB3 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB3 Database: .Pioneer 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 505.00 2.74 284.05 504.90 448.70 3.00 -6.13 6,031,054.29 469,815.06 1.73 6.32 SR-Gyro-SS(1) 568.00 3.14 281.82 567.82 511.62 3.72 -9.28 6,031,055.03 469,811.92 0.66 9.51 SR-Gyro-SS(1) I 601.00 3.54 281.44 600.76 544.56 4.11 -11.16 6,031,055.42 469,810.04 1.21 11.42 SR-Gyro-SS(1) 662.00 3.66 281.14 661.64 605.44 4.86 -14.92 6,031,056.19 469,806.28 0.20 15.22 SR-Gyro-SS(1) 685.00 3.95 280.22 684.59 628.39 5.14 -16.42 6,031,056.47 469,804.79 1.29 16.73 SR-Gyro-SS(1) 758.00 4.41 281.46 757.40 701.20 6.14 -21.64 6,031,057.50 469,799.57 0.64 22.01 SR-Gyro-SS(1) 791.00 4.78 281.29 790.29 734.09 6.66 -24.23 6,031,058.03 469,796.98 1.12 24.63 SR-Gyro-SS(1) 853.00 5.29 282.35 852.05 795.85 7.78 -29.56 6,031,059.17 469,791.66 0.84 30.02 SR-Gyro-SS(1) 886.00 5.85 279.85 884.90 828.70 8.39 -32.70 6,031,059.79 469,788.52 1.85 33.20 SR-Gyro-SS(1) 948.00 6.88 279.90 946.51 890.31 9.57 -39.47 6,031,061.00 469,781.75 1.66 40.04 SR-Gyro-SS(1) 981.00 6.89 278.10 979.28 923.08 10.19 -43.38 6,031,061.64 469,777.85 0.65 43.98 SR-Gyro-SS(1) 1,027.53 6.83 276.30 1,025.47 969.27 10.89 -48.89 6,031,062.35 469,772.34 0.48 49.53 MWD+IFR2+MS+sag(2) 1,123.00 9.55 277.06 1,119.96 1,063.76 12.48 -62.40 6,031,064.01 469,758.84 2.85 63.11 SR-Gyro-SS(3) 1,174.43 9.71 277.20 1,170.67 1,114.47 13.55 -70.93 6,031,065.11 469,750.31 0.31 71.70 MWD+IFR2+MS+sag(4) 1,218.54 9.91 278.29 1,214.13 1,157.93 14.57 -78.38 6,031,066.15 469,742.87 0.62 79.20 MWD+IFR2+MS+sag(4) 1,314.10 9.75 271.65 1,308.29 1,252.09 15.98 -94.61 6,031,067.64 469,726.65 1.20 95.48 MWD+IFR2+MS+sag(4) 1,409.32 10.15 272.52 1,402.08 1,345.88 16.59 -111.05 6,031,068.30 469,710.21 0.45 111.93 MWD+IFR2+MS+sag(4) 1,504.37 10.95 274.95 1,495.52 1,439.32 17.73 -128.41 6,031,069.52 469,692.86 0.96 129.33 MWD+IFR2+MS+sag(4) 1,599.91 12.48 272.29 1,589.07 1,532.87 18.93 -147.77 6,031,070.80 469,673.51 1.70 148.72 MWD+IFR2+MS+sag(4) 1,631.69 12.76 273.11 1,620.08 1,563.88 19.26 -154.70 6,031,071.15 469,666.57 1.05 155.66 MWD+IFR2+MS+sag(4) 1,725.28 14.37 274.13 1,711.06 1,654.86 20.65 -176.61 6,031,072.64 469,644.68 1.74 177.61 MWD+IFR2+MS+sag(4) 1,821.10 13.44 273.34 1,804.07 1,747.87 22.16 -199.58 6,031,074.24 469,621.71 0.99 200.64 MWD+IFR2+MS+sag(4) 1,915.58 15.28 274.70 1,895.59 1,839.39 23.82 -222.95 6,031,075.99 469,598.35 1.98 224.07 MWD+IFR2+MS+sag(4) 2,011.74 15.85 275.48 1,988.23 1,932.03 26.11 -248.65 6,031,078.39 469,572.66 0.63 249.86 MWD+IFR2+MS+sag(4) 2,107.39 14.66 274.53 2,080.51 2,024.31 28.31 -273.72 6,031,080.69 469,547.60 1.27 275.02 MWD+IFR2+MS+sag(4) 2,202.94 13.62 277.80 2,173.16 2,116.96 30.80 -296.92 6,031,083.27 469,524.41 1.37 298.34 MWD+IFR2+MS+sag(4) 2,241.41 13.96 276.43 2,210.52 2,154.32 31.93 -306.02 6,031,084.44 469,515.32 1.23 307.50 MWD+IFR2+MS+sag(4) 2,298.61 14.97 276.21 2,265.91 2,209.71 33.50 -320.22 6,031,086.07 469,501.13 1.77 321.77 MWD+IFR2+MS+sag(4) 2,333.40 15.89 274.27 2,299.44 2,243.24 34.34 -329.44 6,031,086.95 469,491.92 3.03 331.02 MWD+IFR2+MS+sag(4) 2,393.28 16.92 271.13 2,356.89 2,300:69 35.12 -346.33 6,031,087.80 469,475.03 2.27 347.93 MWD+IFR2+MS+sag(4) 2,488.03 20.47 266.74 2,446.63 2,390.43 34.45 -376.67 6,031,087.25 469,444.70 4.03 378.14 MWD+IFR2+MS+sag(4) 2,583.22 24.38 267.73 2,534.60 2,478.40 32.73 -412.93 6,031,085.67 469,408.43 4.13 414.20 MWD+IFR2+MS+sag(4) 2,678.36 29.60 267.12 2,619.35 2,563.15 30.77 -456.05 6,031,083.89 469,365.31 5.49 457.08 MWD+IFR2+MS+sag(4) 2,773.39 32.86 268.44 2,700.60 2,644.40 28.89 -505.27 6,031,082.21 469,316.08 3.51 506.06 MWD+IFR2+MS+sag(4) 2,868.92 36.48 268.01 2,779.16 2,722.96 27.20 -559.58 6,031,080.73 469,261.77 3.80 560.12 MWD+IFR2+MS+sag(4) 2,963.62 38.66 267.56 2,854.21 2,798.01 24.96 -617.27 6,031,078.73 469,204.08 2.32 617.52 MWD+IFR2+MS+sag(4) 3,059.68 38.65 266.41 2,929.23 2,873.03 21.80 -677.19 6,031,075.82 469,144.15 0.75 677.08 MWD+IFR2+MS+sag(4) 3,155.09 41.44 265.51 3,002.26 2,946.06 17.46 -738.41 6,031,071.73 469,082.92 2.99 737.85 MWD+IFR2+MS+sag(4) 3,249.55 42.15 264.91 3,072.68 3,016.48 12.20 -801.15 6,031,066.73 469,020.17 0.86 800.07 MWD+IFR2+MS+sag(4) 3,344.92 46.28 265.36 3,141.02 3,084.82 6.58 -867.40 6,031,061.37 468,953.90 4.34 865.78 MWD+IFR2+MS+sag(4) 1/31/2011 9:33:25AM Page 3 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB3 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB3 Database: .Pioneer 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) (11001 (ft) Survey Tool Name 3,439.63 48.20 265.43 3,205.32 3,149.12 0.99 -936.71 6,031,056.07 468,884.58 2.03 934.54 MWD+IFR2+MS+sag(4) 3,534.85 49.89 264.83 3,267.73 3,211.53 -5.12 -1,008.36 6,031,050.25 468,812.91 1.84 1,005.59 MWD+IFR2+MS+sag(4) 3,566.42 50.37 265.46 3,287.97 3,231.77 -7.17 -1,032.50 6,031,048.30 468,788.76 2.16 1,029.54 MWD+IFR2+MS+sag(4) 3,630.15 49.94 264.80 3,328.80 3,272.60 -11.32 -1,081.25 6,031,044.34 468,740.00 1.04 1,077.89 MWD+IFR2+MS+sag(5) 3,728.64 48.98 264.86 3,392.82 3,336.62 -18.06 -1,155.80 6,031,037.90 468,665.44 0.98 1,151.78 MWD+IFR2+MS+sag(5) 3,823.03 48.55 265.70 3,455.04 3,398.84 -23.91 -1,226.54 6,031,032.35 468,594.68 0.81 1,221.95 MWD+IFR2+MS+sag(5) 3,918.36 47.71 266.13 3,518.66 3,462.46 -28.97 -1,297.34 6,031,027.57 468,523.86 0.94 1,292.24 MWD+IFR2+MS+sag(5) 4,013.58 47.75 266.18 3,582.71 3,526.51 -33.69 -1,367.65 6,031,023.14 468,453.55 0.06 1,362.05 MWD+IFR2+MS+sag(5) 4,108.84 51.32 267.02 3,644.52 3,588.32 -37.97 -1,439.98 6,031,019.15 468,381.20 3.81 1,433.91 MWD+IFR2+MS+sag(5) 4,203.49 54.06 266.88 3,701.89 3,645.69 -41.98 -1,515.15 6,031,015.45 468,306.03 2.90 1,508.62 MWD+IFR2+MS+sag(5) 4,300.86 56.97 265.70 3,757.01 3,700.81 -47.19 -1,595.23 6,031,010.56 468,225.93 3.15 1,588.15 MWD+IFR2+MS+sag(5) 4,398.80 58.70 262.86 3,809.16 3,752.96 -55.47 -1,677.71 6,031,002.62 468,143.43 3.02 1,669.86 MWD+IFR2+MS+sag(5) 4,493.85 61.31 259.87 3,856.68 3,800.48 -67.85 -1,759.07 6,030,990.57 468,062.03 3.87 1,750.17 MWD+IFR2+MS+sag(5) 4,584.47 65.00 259.37 3,897.60 3,841.40 -82.42 -1,838.58 6,030,976.32 467,982.46 4.10 1,828.49 MWD+IFR2+MS+sag(5) 4,684.58 67.49 257.58 3,937.92 3,881.72 -100.74 -1,928.35 6,030,958.37 467,892.63 2.98 1,916.78 MWD+IFR2+MS+sag(5) 4,779.26 68.84 257.43 3,973.14 3,916.94 -119.76 -2,014.15 6,030,939.70 467,806.76 1.43 2,001.06 MWD+IFR2+MS+sag(5) 4,871.89 70.51 256.93 4,005.31 3,949.11 -139.03 -2,098.85 6,030,920.77 467,722.00 1.87 2,084.22 MWD+IFR2+MS+sag(5) 4,965.11 71.34 257.43 4,035.78 3,979.58 -158.58 -2,184.75 6,030,901.58 467,636.02 1.02 2,168.57 MWD+IFR2+MS+sag(5) 5,063.57 71.46 258.28 4,067.18 4,010.98 -178.21 -2,275.98 6,030,882.32 467,544.73 0.83 2,258.22 MWD+IFR2+MS+sag(5) 5,159.38 71.34 258.20 4,097.74 4,041.54 -196.72 -2,364.88 6,030,864.17 467,455.76 0.15 2,345.63 MWD+IFR2+MS+sag(5) 5,254.53 71.20 258.00 4,128.29 4,072.09 -215.30 -2,453.05 6,030,845.95 467,367.52 0.25 2,432.31 MWD+IFR2+MS+sag(5) 5,345.36 70.63 257.39 4,157.99 4,101.79 -233.59 -2,536.92 6,030,828.00 467,283.59 0.89 2,514.71 MWD+IFR2+MS+sag(5) 5,441.12 71.23 257.83 4,189.28 4,133.08 -253.01 -2,625.31 6,030,808.94 467,195.13 0.76 2,601.55 MWD+IFR2+MS+sag(5) 5,536.74 71.07 258.19 4,220.17 4,163.97 -271.81 -2,713.83 6,030,790.51 467,106.54 0.39 2,688.56 MWD+IFR2+MS+sag(5) 5,631.50 70.36 258.20 4,251.47 4,195.27 -290.11 -2,801.38 6,030,772.57 467,018.93 0.75 2,774.64 MWD+IFR2+MS+sag(5) 5,727.44 70.95 258.18 4,283.25 4,227.05 -308.63 -2,889.99 6,030,754.40 466,930.25 0.62 2,861.75 MWD+IFR2+MS+sag(5) 5,824.68 70.61 258.07 4,315.26 4,259.06 -327.53 -2,979.84 6,030,735.87 466,840.33 0.37 2,950.09 MWD+IFR2+MS+sag(5) 5,917.59 70.86 257.56 4,345.92 4,289.72 -346.04 -3,065.57 6,030,717.71 466,754.54 0.58 3,034.33 MWD+IFR2+MS+sag(5) 6,011.23 71.05 257.12 4,376.47 4,320.27 -365.44 -3,151.94 6,030,698.66 466,668.11 0.49 3,119.15 MWD+IFR2+MS+sag(5) 6,109.85 70.29 255.57 4,409.12 4,352.92 -387.41 -3,242.36 6,030,677.07 466,577.60 1.67 3,207.84 MWD+IFR2+MS+sag(5) 6,206.00 70.35 256.98 4,441.50 4,385.30 -408.89 -3,330.31 6,030,655.95 466,489.58 1.38 3,294.09 MWD+IFR2+MS+sag(5) 6,296.96 70.47 257.77 4,472.00 4,415.80 -427.62 -3,413.93 6,030,637.56 466,405.89 0.83 3,376.22 MWD+IFR2+MS+sag(5) 6,392.50 70.96 258.81 4,503.55 4,447.35 -445.92 -3,502.23 6,030,619.62 466,317.52 1.15 3,463.04 MWD+IFR2+MS+sag(5) 6,487.74 71.03 259.25 4,534.57 4,478.37 -463.05 -3,590.63 6,030,602.84 466,229.06 0.44 3,550.05 MWD+IFR2+MS+sag(5) 6,582.74 70.87 258.69 4,565.57 4,509.37 -480.23 -3,678.77 6,030,586.02 466,140.86 0.58 3,636.79 MWD+IFR2+MS+sag(5) 6,677.75 70.73 259.06 4,596.82 4,540.62 -497.54 -3,766.81 6,030,569.07 466,052.76 0.40 3,723.42 MWD+IFR2+MS+sag(5) 6,773.48 71.16 258.45 4,628.07 4,571.87 -515.19 -3,855.56 6,030,551.79 465,963.95 0.75 3,810.74 MWD+IFR2+MS+sag(5) 6,868.81 71.27 257.68 4,658.77 4,602.57 -533.85 -3,943.86 6,030,533.48 465,875.59 0.77 3,897.54 MWD+IFR2+MS+sag(5) 6,964.81 70.80 259.14 4,689.97 4,633.77 -552.10 -4,032.79 6,030,515.61 465,786.59 1.52 3,985.00 MWD+IFR2+MS+sag(5) I 7,058.66 71.73 258.75 4,720.12 4,663.92 -569.14 -4,120.02 6,030,498.92 465,699.30 1.07 4,070.84 MWD+IFR2+MS+sag(5) 1/31/2011 9:33:25AM Page 4 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report • Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB3 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB3 Database: .Pioneer 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) (°/10(Y) (ft) Survey Tool Name 7,155.94 70.48 258.65 4,751.62 4,695.42 -587.17 -4,210.27 6,030,481.25 465,608.99 1.29 4,159.63 MWD+IFR2+MS+sag(5) 7,249.11 70.27 258.33 4,782.91 4,726.71 -604.68 -4,296.26 6,030,464.09 465,522.93 0.39 4,244.21 MWD+IFR2+MS+sag(5) 7,345.08 71.16 258.01 4,814.61 4,758.41 -623.25 -4,384.92 6,030,445.88 465,434.21 0.98 4,331.37 MWD+IFR2+MS+sag(5) 7,441.17 70.89 257.84 4,845.85 4,789.65 -642.26 -4,473.78 6,030,427.24 465,345.28 0.33 4,418.70 MWD+IFR2+MS+sag(5) 7,536.09 69.56 258.34 4,877.96 4,821.76 -660.70 -4,561.18 6,030,409.16 465,257.82 1.49 4,504.62 MWD+IFR2+MS+sag(5) 7,626.41 69.56 260.20 4,909.51 4,853.31 -676.45 -4,644.33 6,030,393.74 465,174.61 1.93 4,586.48 MWD+IFR2+MS+sag(5) 7,726.42 69.36 260.00 4,944.60 4,888.40 -692.56 -4,736.58 6,030,378.02 465,082.30 0.27 4,677.40 MWD+IFR2+MS+sag(5) 7,820.69 69.02 260.88 4,978.09 4,921.89 -707.19 -4,823.48 6,030,363.74 464,995.36 0.94 4,763.08 MWD+IFR2+MS+sag(5) 7,915.20 69.21 260.17 5,011.78 4,955.58 -721.73 -4,910.57 6,030,349.56 464,908.21 0.73 4,848.96 MWD+IFR2+MS+sag(5) 8,011.00 69.69 260.57 5,045.41 4,989.21 -736.73 -4,999.01 6,030,334.91 464,819.72 0.64 4,936.15 MWD+IFR2+MS+sag(5) 8,106.40 69.26 260.81 5,078.86 5,022.66 -751.19 -5,087.18 6,030,320.82 464,731.51 0.51 5,023.11 MWD+IFR2+MS+sag(5) 8,201.28 69.17 260.04 5,112.53 5,056.33 -765.94 -5,174.65 6,030,306.42 464,643.99 0.76 5,109.35 MWD+IFR2+MS+sag(5) 8,296.82 69.86 258.87 5,145.97 5,089.77 -782.32 -5,262.63 6,030,290.40 464,555.95 1.36 5,195.99 MWD+IFR2+MS+sag(5) 8,392.12 69.57 258.47 5,179.00 5,122.80 -799.88 -5,350.28 6,030,273.19 464,468.24 0.50 5,282.22 MWD+IFR2+MS+sag(5) 8,438.00 69.60 258.48 5,195.01 5,138.81 -808.47 -5,392.41 6,030,264.77 464,426.07 0.07 5,323.65 MWD+IFR2+MS+sag(6) 8,529.05 72.36 255.25 5,224.69 5,168.49 -828.05 -5,476.21 6,030,245.54 464,342.20 4.52 5,405.90 MWD+IFR2+MS+sag(6) 8,575.56 73.36 254.40 5,238.39 5,182.19 -839.68 -5,519.11 6,030,234.08 464,299.27 2.77 5,447.89 MWD+IFR2+MS+sag(6) 8,670.27 74.48 252.70 5,264.63 5,208.43 -865.46 -5,606.38 6,030,208.67 464,211.90 2.09 5,533.17 MWD+IFR2+MS+sag(6) 8,718.63 74.39 251.47 5,277.60 5,221.40 -879.79 -5,650.71 6,030,194.52 464,167.52 2.46 5,576.40 MWD+IFR2+MS+sag(6) 8,785.71 74.04 252.09 5,295.85 5,239.65 -899.97 -5,712.02 6,030,174.59 464,106.13 1.03 5,636.18 MWD+IFR2+MS+sag(6) 8,881.94 73.38 251.52 5,322.84 5,266.64 -928.81 -5,799.77 6,030,146.10 464,018.28 0.89 5,721.72 MWD+IFR2+MS+sag(6) 8,977.86 73.11 252.53 5,350.50 5,294.30 -957.15 -5,887.13 6,030,118.12 463,930.81 1.05 5,806.92 MWD+IFR2+MS+sag(6) 9,072.22 72.75 254.47 5,378.20 5,322.00 -982.77 -5,973.61 6,030,092.85 463,844.23 2.00 5,891.42 MWD+IFR2+MS+sag(6) 9,168.00 72.53 256.55 5,406.78 5,350.58 -1,005.65 -6,062.12 6,030,070.34 463,755.64 2.09 5,978.13 MWD+IFR2+MS+sag(6) 9,262.77 72.47 260.99 5,435.29 5,379.09 -1,023.24 -6,150.74 6,030,053.11 463,666.95 4.47 6,065.33 MWD+IFR2+MS+sag(6) 9,357.47 72.46 264.53 5,463.83 5,407.63 -1,034.62 -6,240.31 6,030,042.09 463,577.35 3.56 6,153.90 MWD+IFR2+MS+sag(6) 9,452.53 71.85 267.34 5,492.97 5,436.77 -1,041.04 -6,330.55 6,030,036.04 463,487.09 2.89 6,243.48 MWD+IFR2+MS+sag(6) 9,547.64 72.27 271.43 5,522.27 5,466.07 -1,042.01 -6,421.01 6,030,035.44 463,396.64 4.11 6,333.66 MWD+IFR2+MS+sag(6) 9,642.41 72.06 275.01 5,551.31 5,495.11 -1,036.94 -6,511.07 6,030,040.87 463,306.61 3.60 6,423.85 MWD+IFR2+MS+sag(6) 9,737.67 71.99 278.14 5,580.71 5,524.51 -1,026.57 -6,601.07 6,030,051.61 463,216.66 3.13 6,514.35 MWD+IFR2+MS+sag(6) 9,833.18 71.37 281.53 5,610.74 5,554.54 -1,011.09 -6,690.39 6,030,067.45 463,127.42 3.43 6,604.53 MWD+IFR2+MS+sag(6) 9,929.57 71.41 286.08 5,641.51 5,585.31 -989.30 -6,779.07 6,030,089.60 463,038.83 4.47 6,694.51 MWD+IFR2+MS+sag(6) 10,024.64 71.38 289.64 5,671.85 5,615.65 -961.67 -6,864.82 6,030,117.57 462,953.21 3.55 6,781.95 MWD+IFR2+MS+sag(6) 10,118.68 72.08 292.42 5,701.34 5,645.14 -929.62 -6,948.16 6,030,149.95 462,870.01 2.90 6,867.31 MWD+IFR2+MS+sag(6) 10,214.27 72.08 296.36 5,730.76 5,674.56 -892.07 -7,030.97 6,030,187.83 462,787.35 3.92 6,952.52 MWD+IFR2+MS+sag(6) 10,309.31 71.94 299.25 5,760.12 5,703.92 -849.92 -7,110.92 6,030,230.31 462,707.59 2.90 7,035.19 MWD+IFR2+MS+sag(6) 10,404.13 72.22 300.94 5,789.30 5,733.10 -804.68 -7,188.97 6,030,275.86 462,629.73 1.72 7,116.18 MWD+IFR2+MS+sag(6) 10,498.75 73.56 303.93 5,817.14 5,760.94 -756.17 -7,265.28 6,030,324.67 462,553.62 3.34 7,195.66 MWD+IFR2+MS+sag(6) 10,593.70 74.26 308.42 5,843.47 5,787.27 -702.34 -7,338.90 6,030,378.80 462,480.23 4.60 7,272.82 MWD+IFR2+MS+sag(6) 10,689.51 74.46 309.71 5,869.30 5,813.10 -644.19 -7,410.53 6,030,437.23 462,408.84 1.31 7,348.30 MWD+IFR2+MS+sag(6) 1/31/2011 9:33:25AM Page 5 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB3 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB3 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 10,784.19 74.92 311.89 5,894.30 5,838.10 -584.53 -7,479.65 6,030,497.17 462,339.97 2.27 7,421.38 MWD+IFR2+MS+sag(6) 10,879.86 74.40 314.18 5,919.61 5,863.41 -521.57 -7,547.09 6,030,560.39 462,272.80 2.37 7,493.01 MWD+IFR2+MS+sag(6) 10,975.10 74.72 315.49 5,944.97 5,888.77 -456.84 -7,612.19 6,030,625.38 462,207.97 1.37 7,562.42 MWD+IFR2+MS+sag(6) 11,070.33 75.73 317.97 5,969.26 5,913.06 -389.80 -7,675.29 6,030,692.67 462,145.14 2.73 7,630.01 MWD+I FR2+MS+sag(6) 11,166.35 75.55 321.26 5,993.08 5,936.88 -318.96 -7,735.55 6,030,763.75 462,085.18 3.32 7,695.02 MWD+IFR2+MS+sag(6) 11,261.96 75.75 324.90 6,016.78 5,960.58 -244.92 -7,791.18 6,030,838.01 462,029.85 3.69 7,755.63 MWD+IFR2+MS+sag(6) 11,357.50 76.88 328.38 6,039.39 5,983.19 -167.40 -7,842.21 6,030,915.73 461,979.14 3.73 7,811.90 MWD+IFR2+MS+sag(6) 11,451.93 77.90 332.01 6,060.02 6,003.82 -87.45 -7,888.00 6,030,995.85 461,933.68 3.90 7,863.11 MWD+IFR2+MS+sag(6) 11,547.13 79.28 336.17 6,078.86 6,022.66 -3.53 -7,928.76 6,031,079.93 461,893.27 4.52 7,909.57 MWD+IFR2+MS+sag(6) 11,642.52 79.79 339.06 6,096.19 6,039.99 83.20 -7,964.48 6,031,166.79 461,857.91 3.03 7,951.19 MWD+IFR2+MS+sag(6) 11,736.96 79.85 338.89 6,112.88 6,056.68 169.96 -7,997.83 6,031,253.68 461,824.91 0.19 7,990.45 MW D+I FR2+MS+sag(6) 11,831.99 79.89 339.14 6,129.59 6,073.39 257.31 -8,031.33 6,031,341.15 461,791.77 0.26 8,029.91 MWD+IFR2+MS+sag(6) 11,927.00 79.58 341.03 6,146.52 6,090.32 345.20 -8,063.17 6,031,429.17 461,760.29 1.98 8,067.75 MWD+IFR2+MS+sag(6) 12,022.53 80.09 342.27 6,163.38 6,107.18 434.45 -8,092.78 6,031,518.52 461,731.05 1.38 8,103.45 MWD+IFR2+MS+sag(6) 12,067.94 80.08 343.26 6,171.20 6,115.00 477.17 -8,106.03 6,031,561.30 461,717.97 2.15 8,119.63 MWD+IFR2+MS+sag(6) 12,090.00 80.21 343.64 6,174.98 6,118.78 498.01 -8,112.22 6,031,582.15 461,711.87 1.81 8,127.24 MWD+IFR2+MS+sag(6) 12,122.46 80.82 341.19 6,180.33 6,124.13 528.52 -8,121.89 6,031,612.71 461,702.32 7.68 8,139.00 MWD+IFR2+MS+sag(7) 12,148.55 81.79 338.20 6,184.27 6,128.07 552.71 -8,130.84 6,031,636.92 461,693.47 11.92 8,149.60 MWD+IFR2+MS+sag(7) 12,196.49 83.40 336.52 6,190.45 6,134.25 596.58 -8,149.14 6,031,680.87 461,675.35 4.83 8,170.89 MWD+IFR2+MS+sag(7) 12,245.45 84.40 336.18 6,195.65 6,139.45 641.17 -8,168.67 6,031,725.53 461,656.00 2.16 8,193.45 MWD+IFR2+MS+sag(7) 12,289.71 84.07 336.40 6,200.10 6,143.90 681.49 -8,186.38 6,031,765.92 461,638.46 0.89 8,213.90 MWD+IFR2+MS+sag(7) 12,386.42 84.01 338.03 6,210.14 6,153.94 770.17 -8,223.63 6,031,854.74 461,601.58 1.68 8,257.19 MWD+IFR2+MS+sag(7) 12,483.58 83.89 342.52 6,220.39 6,164.19 861.10 -8,256.23 6,031,945.79 461,569.35 4.60 8,295.99 MWD+IFR2+MS+sag(7) 12,532.01 87.52 342.90 6,224.01 6,167.81 907.20 -8,270.58 6,031,991.95 461,555.19 7.54 8,313.50 MWD+IFR2+MS+sag(7) 12,579.25 88.92 342.40 6,225.48 6,169.28 952.27 -8,284.66 6,032,037.07 461,541.29 3.15 8,330.66 MWD+I FR2+MS+sag(7) 12,676.17 91.88 340.53 6,224.80 6,168.60 1,044.15 -8,315.46 6,032,129.06 461,510.86 3.61 8,367.74 MWD+I FR2+MS+sag(7) 12,771.79 93.54 338.11 6,220.28 6,164.08 1,133.49 -8,349.19 6,032,218.53 461,477.50 3.07 8,407.56 MWD+IFR2+MS+sag(7) 12,867.97 93.29 335.98 6,214.55 6,158.35 1,221.90 -8,386.63 6,032,307.08 461,440.43 2.23 8,451.02 MWD+IFR2+MS+sag(7) 12,964.98 94.47 334.09 6,207.99 6,151.79 1,309.64 -8,427.48 6,032,394.97 461,399.94 2.29 8,497.83 MWD+IFR2+MS+sag(7) 13,060.50 93.10 329.05 6,201.68 6,145.48 1,393.42 -8,472.84 6,032,478.93 461,354.92 5.46 8,548.87 MWD+IFR2+MS+sag(7) 13,157.22 93.54 323.98 6,196.07 6,139.87 1,473.93 -8,526.10 6,032,559.65 461,302.00 5.25 8,607.56 MWD+IFR2+MS+sag(7) 13,253.93 92.85 326.30 6,190.68 6,134.48 1,553.15 -8,581.28 6,032,639.09 461,247.14 2.50 8,668.09 MWD+IFR2+MS+sag(7) 13,350.10 94.35 326.92 6,184.64 6,128.44 1,633.29 -8,634.10 6,032,719.43 461,194.65 1.69 8,726.32 MWD+IFR2+MS+sag(7) 13,445.74 92.47 326.08 6,178.96 6,122.76 1,712.90 -8,686.79 6,032,799.24 461,142.29 2.15 8,784.39 MWD+IFR2+MS+sag(7) 13,542.36 88.76 325.39 6,177.92 6,121.72 1,792.73 -8,741.18 6,032,879.29 461,088.23 3.91 8,844.16 MWD+IFR2+MS+sag(7) 13,640.95 85.11 324.65 6,183.19 6,126.99 1,873.38 -8,797.61 6,032,960.16 461,032.14 3.78 8,906.03 MWD+IFR2+MS+sag(7) 13,735.11 81.38 323.29 6,194.26 6,138.06 1,948.99 -8,852.60 6,033,035.98 460,977.46 4.21 8,966.11 MWD+IFR2+MS+sag(7) 13,831.22 81.47 320.84 6,208.60 6,152.40 2,023.93 -8,911.02 6,033,111.16 460,919.35 2.52 9,029.57 MWD+IFR2+MS+sag(7) 1/31/2011 9:33:25AM Page 6 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB4 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB4 Database: .Pioneer 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 ODSN-18-Slot ODS-18 Well Position +NI-S 0.00 ft Northing: 6,031,051.27 ft Latitude: 70°29'45.254 N +E/-W 0.00 ft Easting: 469,821.18 ft Longitude: 150°14'48.375 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSN-18 PB4 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-18 PN11 PB4 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,771.79 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 277.72 Survey Program Date 1/27/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 141.00 981.00 ODSN-18 PB1 Gyro 1 (ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 10/25/2010 • 1,027.53 1,027.53 ODSN-18 PB1 MWD 1 (ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/2/2010 1: 1,123.00 1,123.00 ODSN-18 PB1 Gyro 2(ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 11/2/2010 1: 1,174.40 3,566.42 ODSN-18 PB1 MWD 2(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:lIFR dec&3-axis correction+sag 10/26/2010 3,630.15 8,392.10 ODSN-18 PB1 MWD 3(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/1/2010 1: 8,438.00 12,090.00 ODSN-18 PB2 MWD 4(ODSN-18 PB2) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/5/2010 1: 12,122.46 12,771.79 ODSN-18 PB3 MWD 5(ODSN-18 PB3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/22/2010 12,850.00 13,736.40 ODSN-18 PB4 MWD 6(ODSN-18 PB4) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/30/2010 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-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 6,031,051.27 469,821.18 0.00 0.00 UNDEFINED 141.00 0.26 304.00 141.00 84.80 0.13 -0.19 6,031,051.40 469,820.99 0.26 0.20 SR-Gyro-SS(1) 199.00 0.27 348.71 199.00 142.80 0.33 -0.32 6,031,051.60 469,820.86 0.35 0.36 SR-Gyro-SS(1) 232.00 0.49 322.56 232.00 175.80 0.52 -0.42 6,031,051.79 469,820.76 0.83 0.49 SR-Gyro-SS(1) 290.00 0.48 322.52 290.00 233.80 0.91 -0.72 6,031,052.18 469,820.46 0.02 0.84 SR-Gyro-SS(1) 323.00 0.93 308.43 322.99 266.79 1.19 -1.02 6,031,052.46 469,820.17 1.45 1.16 SR-Gyro-SS(1) 382.00 1.25 295.72 381.98 325.78 1.76 -1.97 6,031,053.04 469,819.22 0.68 2.19 SR-Gyro-SS(1) 415.00 1.90 288.47 414.97 358.77 2.09 -2.81 6,031,053.38 469,818.38 2.06 3.07 SR-Gyro-SS(1) 1/31/2011 9:31:53AM Page 2 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB4 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB4 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 472.00 2.17 284.07 471.93 415.73 2.66 -4.76 6,031,053.94 469,816.43 0.55 5.07 SR-Gyro-SS(1) 505.00 2.74 284.05 504.90 448.70 3.00 -6.13 6,031,054.29 469,815.06 1.73 6.47 SR-Gyro-SS(1) 568.00 3.14 281.82 567.82 511.62 3.72 -9.28 6,031,055.03 469,811.92 0.66 9.69 SR-Gyro-SS(1) 601.00 3.54 281.44 600.76 544.56 4.11 -11.16 6,031,055.42 469,810.04 1.21 11.61 SR-Gyro-SS(1) 662.00 3.66 281.14 661.64 605.44 4.86 -14.92 6,031,056.19 469,806.28 0.20 15.43 SR-Gyro-SS(1) 685.00 3.95 280.22 684.59 628.39 5.14 -16.42 6,031,056.47 469,804.79 1.29 16.96 SR-Gyro-SS(1) 758.00 4.41 281.46 757.40 701.20 6.14 -21.64 6,031,057.50 469,799.57 0.64 22.27 SR-Gyro-SS(1) 791.00 4.78 281.29 790.29 734.09 6.66 -24.23 6,031,058.03 469,796.98 1.12 24.91 SR-Gyro-SS(1) 853.00 5.29 282.35 852.05 795.85 7.78 -29.56 6,031,059.17 469,791.66 0.84 30.33 SR-Gyro-SS(1) 886.00 5.85 279.85 884.90 828.70 8.39 -32.70 6,031,059.79 469,788.52 1.85 33.53 SR-Gyro-SS(1) 948.00 6.88 279.90 946.51 890.31 9.57 -39.47 6,031,061.00 469,781.75 1.66 40.40 SR-Gyro-SS(1) 981.00 6.89 278.10 979.28 923.08 10.19 -43.38 6,031,061.64 469,777.85 0.65 44.35 SR-Gyro-SS(1) 1,027.53 6.83 276.30 1,025.47 969.27 10.89 -48.89 6,031,062.35 469,772.34 0.48 49.91 MWD+IFR2+MS+sag(2) 1,123.00 9.55 277.06 1,119.96 1,063.76 12.48 -62.40 6,031,064.01 469,758.84 2.85 63.51 SR-Gyro-SS(3) 1,174.43 9.71 277.20 1,170.67 1,114.47 13.55 -70.93 6,031,065.11 469,750.31 0.31 72.11 MWD+IFR2+MS+sag(4) 1,218.54 9.91 278.29 1,214.13 1,157.93 14.57 -78.38 6,031,066.15 469,742.87 0.62 79.63 MWD+IFR2+MS+sag(4) 1,314.10 9.75 271.65 1,308.29 1,252.09 15.98 -94.61 6,031,067.64 469,726.65 1.20 95.90 MWD+IFR2+MS+sag(4) 1,409.32 10.15 272.52 1,402.08 1,345.88 16.59 -111.05 6,031,068.30 469,710.21 0.45 112.27 MWD+IFR2+MS+sag(4) 1,504.37 10.95 274.95 1,495.52 1,439.32 17.73 -128.41 6,031,069.52 469,692.86 0.96 129.63 MWD+IFR2+MS+sag(4) 1,599.91 12.48 272.29 1,589.07 1,532.87 18.93 -147.77 6,031,070.80 469,673.51 1.70 148.97 MWD+IFR2+MS+sag(4) 1,631.69 12.76 273.11 1,620.08 1,563.88 19.26 -154.70 6,031,071.15 469,666.57 1.05 155.88 MWD+IFR2+MS+sag(4) 1,725.28 14.37 274.13 1,711.06 1,654.86 20.65 -176.61 6,031,072.64 469,644.68 1.74 177.78 MWD+IFR2+MS+sag(4) 1,821.10 13.44 273.34 1,804.07 1,747.87 22.16 -199.58 6,031,074.24 469,621.71 0.99 200.75 MWD+IFR2+MS+sag(4) 1,915.58 15.28 274.70 1,895.59 1,839.39 23.82 -222.95 6,031,075.99 469,598.35 1.98 224.13 MWD+IFR2+MS+sag(4) 2,011.74 15.85 275.48 1,988.23 1,932.03 26.11 -248.65 6,031,078.39 469,572.66 0.63 249.91 MWD+IFR2+MS+sag(4) 2,107.39 14.66 274.53 2,080.51 2,024.31 28.31 -273.72 6,031,080.69 469,547.60 1.27 275.04 MWD+IFR2+MS+sag(4) 2,202.94 13.62 277.80 2,173.16 2,116.96 30.80 -296.92 6,031,083.27 469,524.41 1.37 298.37 MWD+IFR2+MS+sag(4) 2,241.41 13.96 276.43 2,210.52 2,154.32 31.93 -306.02 6,031,084.44 469,515.32 1.23 307.54 MWD+IFR2+MS+sag(4) 2,298.61 14.97 276.21 2,265.91 2,209.71 33.50 -320.22 6,031,086.07 469,501.13 1.77 321.82 MWD+IFR2+MS+sag(4) 2,333.40 15.89 274.27 2,299.44 2,243.24 34.34 -329.44 6,031,086.95 469,491.92 3.03 331.07 MWD+IFR2+MS+sag(4) 2,393.28 16.92 271.13 2,356.89 2,300.69 35.12 -346.33 6,031,087.80 469,475.03 2.27 347.90 MWD+IFR2+MS+sag(4) 2,488.03 20.47 266.74 2,446.63 2,390.43 34.45 -376.67 6,031,087.25 469,444.70 4.03 377.88 MWD+IFR2+MS+sag(4) 2,583.22 24.38 267.73 2,534.60 2,478.40 32.73 -412.93 6,031,085.67 469,408.43 4.13 413.58 MWD+IFR2+MS+sag(4) 2,678.36 29.60 267.12 2,619.35 2,563.15 30.77 -456.05 6,031,083.89 469,365.31 5.49 456.04 MWD+IFR2+MS+sag(4) 2,773.39 32.86 268.44 2,700.60 2,644.40 28.89 -505.27 6,031,082.21 469,316.08 3.51 504.57 MWD+IFR2+MS+sag(4) 2,868.92 36.48 268.01 2,779.16 2,722.96 27.20 -559.58 6,031,080.73 469,261.77 3.80 558.15 MWD+IFR2+MS+sag(4) 2,963.62 38.66 267.56 2,854.21 2,798.01 24.96 -617.27 6,031,078.73 469,204.08 2.32 615.02 MWD+IFR2+MS+sag(4) 3,059.68 38.65 266.41 2,929.23 2,873.03 21.80 -677.19 6,031,075.82 469,144.15 0.75 673.97 MWD+IFR2+MS+sag(4) 3,155.09 41.44 265.51 3,002.26 2,946.06 17.46 -738.41 6,031,071.73 469,082.92 2.99 734.06 MWD+IFR2+MS+sag(4) 3,249.55 42.15 264.91 3,072.68 3,016.48 12.20 -801.15 6,031,066.73 469,020.17 0.86 795.52 MWD+IFR2+MS+sag(4) 1/31/2011 9:31:53AM Page 3 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB4 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB4 Database: .Pioneer 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 3,344.92 46.28 265.36 3,141.02 3,084.82 6.58 -867.40 6,031,061.37 468,953.90 4.34 860.41 MWD+IFR2+MS+sag(4) 3,439.63 48.20 265.43 3,205.32 3,149.12 0.99 -936.71 6,031,056.07 468,884.58 2.03 928.34 MWD+IFR2+MS+sag(4) 3,534.85 49.89 264.83 3,267.73 3,211.53 -5.12 -1,008.36 6,031,050.25 468,812.91 1.84 998.52 MWD+IFR2+MS+sag(4) 3,566.42 50.37 265.46 3,287.97 3,231.77 -7.17 -1,032.50 6,031,048.30 468,788.76 2.16 1,022.17 MWD+IFR2+MS+sag(4) 3,630.15 49.94 264.80 3,328.80 3,272.60 -11.32 -1,081.25 6,031,044.34 468,740.00 1.04 1,069.92 MWD+IFR2+MS+sag(5) 3,728.64 48.98 264.86 3,392.82 3,336.62 -18.06 -1,155.80 6,031,037.90 468,665.44 0.98 1,142.88 MWD+IFR2+MS+sag(5) 3,823.03 48.55 265.70 3,455.04 3,398.84 -23.91 -1,226.54 6,031,032.35 468,594.68 0.81 1,212.19 MWD+IFR2+MS+sag(5) 3,918.36 47.71 266.13 3,518.66 3,462.46 -28.97 -1,297.34 6,031,027.57 468,523.86 0.94 1,281.68 MWD+IFR2+MS+sag(5) 4,013.58 47.75 266.18 3,582.71 3,526.51 -33.69 -1,367.65 6,031,023.14 468,453.55 0.06 1,350.71 MWD+IFR2+MS+sag(5) 4,108.84 51.32 267.02 3,644.52 3,588.32 -37.97 -1,439.98 6,031,019.15 468,381.20 3.81 1,421.81 MWD+IFR2+MS+sag(5) 4,203.49 54.06 266.88 3,701.89 3,645.69 -41.98 -1,515.15 6,031,015.45 468,306.03 2.90 1,495.75 MWD+IFR2+MS+sag(5) 4,300.86 56.97 265.70 3,757.01 3,700.81 -47.19 -1,595.23 6,031,010.56 468,225.93 3.15 1,574.41 MWD+IFR2+MS+sag(5) 4,398.80 58.70 262.86 3,809.16 3,752.96 -55.47 -1,677.71 6,031,002.62 468,143.43 3.02 1,655.02 MWD+IFR2+MS+sag(5) 4,493.85 61.31 259.87 3,856.68 3,800.48 -67.85 -1,759.07 6,030,990.57 468,062.03 3.87 1,733.98 MWD+IFR2+MS+sag(5) 4,584.47 65.00 259.37 3,897.60 3,841.40 -82.42 -1,838.58 6,030,976.32 467,982.46 4.10 1,810.82 MWD+IFR2+MS+sag(5) 4,684.58 67.49 257.58 3,937.92 3,881.72 -100.74 -1,928.35 6,030,958.37 467,892.63 2.98 1,897.31 MWD+IFR2+MS+sag(5) 4,779.26 68.84 257.43 3,973.14 3,916.94 -119.76 -2,014.15 6,030,939.70 467,806.76 1.43 1,979.77 MWD+IFR2+MS+sag(5) 4,871.89 70.51 256.93 4,005.31 3,949.11 -139.03 -2,098.85 6,030,920.77 467,722.00 1.87 2,061.11 MWD+IFR2+MS+sag(5) 4,965.11 71.34 257.43 4,035.78 3,979.58 -158.58 -2,184.75 6,030,901.58 467,636.02 1.02 2,143.61 MWD+IFR2+MS+sag(5) 5,063.57 71.46 258.28 4,067.18 4,010.98 -178.21 -2,275.98 6,030,882.32 467,544.73 0.83 2,231.37 MWD+IFR2+MS+sag(5) 5,159.38 71.34 258.20 4,097.74 4,041.54 -196.72 -2,364.88 6,030,864.17 467,455.76 0.15 2,316.97 MWD+IFR2+MS+sag(5) 5,254.53 71.20 258.00 4,128.29 4,072.09 -215.30 -2,453.05 6,030,845.95 467,367.52 0.25 2,401.85 MWD+IFR2+MS+sag(5) 5,345.36 70.63 257.39 4,157.99 4,101.79 -233.59 -2,536.92 6,030,828.00 467,283.59 0.89 2,482.49 MWD+IFR2+MS+sag(5) 5,441.12 71.23 257.83 4,189.28 4,133.08 -253.01 -2,625.31 6,030,808.94 467,195.13 0.76 2,567.48 MWD+IFR2+MS+sag(5) 5,536.74 71.07 258.19 4,220.17 4,163.97 -271.81 -2,713.83 6,030,790.51 467,106.54 0.39 2,652.66 MWD+IFR2+MS+sag(5) 5,631.50 70.36 258.20 4,251.47 4,195.27 -290.11 -2,801.38 6,030,772.57 467,018.93 0.75 2,736.96 MWD+IFR2+MS+sag(5) 5,727.44 70.95 258.18 4,283.25 4,227.05 -308.63 -2,889.99 6,030,754.40 466,930.25 0.62 2,822.27 MWD+IFR2+MS+sag(5) 5,824.68 70.61 258.07 4,315.26 4,259.06 -327.53 -2,979.84 6,030,735.87 466,840.33 0.37 2,908.77 MWD+IFR2+MS+sag(5) 5,917.59 70.86 257.56 4,345.92 4,289.72 -346.04 -3,065.57 6,030,717.71 466,754.54 0.58 2,991.24 MWD+IFR2+MS+sag(5) 6,011.23 71.05 257.12 4,376.47 4,320.27 -365.44 -3,151.94 6,030,698.66 466,668.11 0.49 3,074.21 MWD+I FR2+MS+sag(5) 6,109.85 70.29 255.57 4,409.12 4,352.92 -387.41 -3,242.36 6,030,677.07 466,577.60 1.67 3,160.86 MWD+IFR2+MS+sag(5) 6,206.00 70.35 256.98 4,441.50 4,385.30 -408.89 -3,330.31 6,030,655.95 466,489.58 1.38 3,245.12 MWD+IFR2+MS+sag(5) 6,296.96 70.47 257.77 4,472.00 4,415.80 -427.62 -3,413.93 6,030,637.56 466,405.89 0.83 3,325.47 MWD+IFR2+MS+sag(5) 6,392.50 70.96 258.81 4,503.55 4,447.35 -445.92 -3,502.23 6,030,619.62 466,317.52 1.15 3,410.51 MWD+IFR2+MS+sag(5) 6,487.74 71.03 259.25 4,534.57 4,478.37 -463.05 -3,590.63 6,030,602.84 466,229.06 0.44 3,495.80 MWD+IFR2+MS+sag(5) 6,582.74 70.87 258.69 4,565.57 4,509.37 -480.23 -3,678.77 6,030,586.02 466,140.86 0.58 3,580.83 MWD+IFR2+MS+sag(5) 6,677.75 70.73 259.06 4,596.82 4,540.62 -497.54 -3,766.81 6,030,569.07 466,052.76 0.40 3,665.75 MWD+IFR2+MS+sag(5) 6,773.48 71.16 258.45 4,628.07 4,571.87 -515.19 -3,855.56 6,030,551.79 465,963.95 0.75 3,751.32 MWD+IFR2+MS+sag(5) 6,868.81 71.27 257.68 4,658.77 4,602.57 -533.85 -3,943.86 6,030,533.48 465,875.59 0.77 3,836.31 MWD+IFR2+MS+sag(5) 6,964.81 70.80 259.14 4,689.97 4,633.77 -552.10 -4,032.79 6,030,515.61 465,786.59 1.52 3,921.98 MWD+IFR2+MS+sag(5) 1/3112011 9:31:53AM Page 4 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB4 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB4 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 7,058.66 71.73 258.75 4,720.12 4,663.92 -569.14 -4,120.02 6,030,498.92 465,699.30 1.07 4,006.12 MWD+IFR2+MS+sag(5) 7,155.94 70.48 258.65 4,751.62 4,695.42 -587.17 -4,210.27 6,030,481.25 465,608.99 1.29 4,093.13 MWD+IFR2+MS+sag(5) 7,249.11 70.27 258.33 4,782.91 4,726.71 -604.68 -4,296.26 6,030,464.09 465,522.93 0.39 4,175.99 MWD+IFR2+MS+sag(5) 7,345.08 71.16 258.01 4,814.61 4,758.41 -623.25 -4,384.92 6,030,445.88 465,434.21 0.98 4,261.35 MWD+IFR2+MS+sag(5) 7,441.17 70.89 257.84 4,845.85 4,789.65 -642.26 -4,473.78 6,030,427.24 465,345.28 0.33 4,346.85 MWD+IFR2+MS+sag(5) 7,536.09 69.56 258.34 4,877.96 4,821.76 -660.70 -4,561.18 6,030,409.16 465,257.82 1.49 4,430.97 MWD+IFR2+MS+sag(5) 7,626.41 69.56 260.20 4,909.51 4,853.31 -676.45 -4,644.33 6,030,393.74 465,174.61 1.93 4,511.25 MWD+IFR2+MS+sag(5) 7,726.42 69.36 260.00 4,944.60 4,888.40 -692.56 -4,736.58 6,030,378.02 465,082.30 0.27 4,600.51 MWD+IFR2+MS+sag(5) 7,820.69 69.02 260.88 4,978.09 4,921.89 -707.19 -4,823.48 6,030,363.74 464,995.36 0.94 4,684.64 MWD+IFR2+MS+sag(5) 7,915.20 69.21 260.17 5,011.78 4,955.58 -721.73 -4,910.57 6,030,349.56 464,908.21 0.73 4,769.00 MWD+IFR2+MS+sag(5) 8,011.00 69.69 260.57 5,045.41 4,989.21 -736.73 -4,999.01 6,030,334.91 464,819.72 0.64 4,854.62 MWD+IFR2+MS+sag(5) 8,106.40 69.26 260.81 5,078.86 5,022.66 -751.19 -5,087.18 6,030,320.82 464,731.51 0.51 4,940.04 MWD+IFR2+MS+sag(5) 8,201.28 69.17 260.04 5,112.53 5,056.33 -765.94 -5,174.65 6,030,306.42 464,643.99 0.76 5,024.73 MWD+IFR2+MS+sag(5) 8,296.82 69.86 258.87 5,145.97 5,089.77 -782.32 -5,262.63 6,030,290.40 464,555.95 1.36 5,109.71 MWD+IFR2+MS+sag(5) 8,392.12 69.57 258.47 5,179.00 5,122.80 -799.88 -5,350.28 6,030,273.19 464,468.24 0.50 5,194.21 MWD+IFR2+MS+sag(5) 8,438.00 69.60 258.48 5,195.01 5,138.81 -808.47 -5,392.41 6,030,264.77 464,426.07 0.07 5,234.80 MWD+IFR2+MS+sag(6) 8,529.05 72.36 255.25 5,224.69 5,168.49 -828.05 -5,476.21 6,030,245.54 464,342.20 4.52 5,315.21 MWD+IFR2+MS+sag(6) 8,575.56 73.36 254.40 5,238.39 5,182.19 -839.68 -5,519.11 6,030,234.08 464,299.27 2.77 5,356.15 MWD+IFR2+MS+sag(6) 8,670.27 74.48 252.70 5,264.63 5,208.43 -865.46 -5,606.38 6,030,208.67 464,211.90 2.09 5,439.17 MWD+IFR2+MS+sag(6) 8,718.63 74.39 251.47 5,277.60 5,221.40 -879.79 -5,650.71 6,030,194.52 464,167.52 2.46 5,481.16 MWD+IFR2+MS+sag(6) 8,785.71 74.04 252.09 5,295.85 5,239.65 -899.97 -5,712.02 6,030,174.59 464,106.13 1.03 5,539.21 MWD+IFR2+MS+sag(6) 8,881.94 73.38 251.52 5,322.84 5,266.64 -928.81 -5,799.77 6,030,146.10 464,018.28 0.89 5,622.28 MWD+IFR2+MS+sag(6) 8,977.86 73.11 252.53 5,350.50 5,294.30 -957.15 -5,887.13 6,030,118.12 463,930.81 1.05 5,705.04 MWD+IFR2+MS+sag(6) 9,072.22 72.75 254.47 5,378.20 5,322.00 -982.77 -5,973.61 6,030,092.85 463,844.23 2.00 5,787.30 MWD+IFR2+MS+sag(6) 9,168.00 72.53 256.55 5,406.78 5,350.58 -1,005.65 -6,062.12 6,030,070.34 463,755.64 2.09 5,871.92 MWD+IFR2+MS+sag(6) 9,262.77 72.47 260.99 5,435.29 5,379.09 -1,023.24 -6,150.74 6,030,053.11 463,666.95 4.47 5,957.38 MWD+IFR2+MS+sag(6) 9,357.47 72.46 264.53 5,463.83 5,407.63 -1,034.62 -6,240.31 6,030,042.09 463,577.35 3.56 6,044.60 MWD+IFR2+MS+sag(6) 9,452.53 71.85 267.34 5,492.97 5,436.77 -1,041.04 -6,330.55 6,030,036.04 463,487.09 2.89 6,133.17 MWD+IFR2+MS+sag(6) 9,547.64 72.27 271.43 5,522.27 5,466.07 -1,042.01 -6,421.01 6,030,035.44 463,396.64 4.11 6,222.67 MWD+IFR2+MS+sag(6) 9,642.41 72.06 275.01 5,551.31 5,495.11 -1,036.94 -6,511.07 6,030,040.87 463,306.61 3.60 6,312.59 MWD+IFR2+MS+sag(6) 9,737.67 71.99 278.14 5,580.71 5,524.51 -1,026.57 -6,601.07 6,030,051.61 463,216.66 3.13 6,403.17 MWD+IFR2+MS+sag(6) 9,833.18 71.37 281.53 5,610.74 5,554.54 -1,011.09 -6,690.39 6,030,067.45 463,127.42 3.43 6,493.76 MWD+IFR2+MS+sag(6) 9,929.57 71.41 286.08 5,641.51 5,585.31 -989.30 -6,779.07 6,030,089.60 463,038.83 4.47 6,584.57 MWD+IFR2+MS+sag(6) 10,024.64 71.38 289.64 5,671.85 5,615.65 -961.67 -6,864.82 6,030,117.57 462,953.21 3.55 6,673.25 MWD+IFR2+MS+sag(6) 10,118.68 72.08 292.42 5,701.34 5,645.14 -929.62 -6,948.16 6,030,149.95 462,870.01 2.90 6,760.14 MWD+IFR2+MS+sag(6) 10,214.27 72.08 296.36 5,730.76 5,674.56 -892.07 -7,030.97 6,030,187.83 462,787.35 3.92 6,847.25 MWD+IFR2+MS+sag(6) 10,309.31 71.94 299.25 5,760.12 5,703.92 -849.92 -7,110.92 6,030,230.31 462,707.59 2.90 6,932.14 MWD+IFR2+MS+sag(6) 10,404.13 72.22 300.94 5,789.30 5,733.10 -804.68 -7,188.97 6,030,275.86 462,629.73 1.72 7,015.57 MWD+IFR2+MS+sag(6) 10,498.75 73.56 303.93 5,817.14 5,760.94 -756.17 -7,265.28 6,030,324.67 462,553.62 3.34 7,097.70 MWD+IFR2+MS+sag(6) 10,593.70 74.26 308.42 5,843.47 5,787.27 -702.34 -7,338.90 6,030,378.80 462,480.23 4.60 7,177.89 MWD+IFR2+MS+sag(6) 1/31/2011 9:31:53AM Page 5 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB4 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB4 Database: .Pioneer 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) ('/100') (ft) Survey Tool Name 10,689.51 74.46 309.71 5,869.30 5,813.10 -644.19 -7,410.53 6,030,437.23 462,408.84 1.31 7,256.69 MWD+IFR2+MS+sag(6) 10,784.19 74.92 311.89 5,894.30 5,838.10 -584.53 -7,479.65 6,030,497.17 462,339.97 2.27 7,333.20 MWD+IFR2+MS+sag(6) 10,879.86 74.40 314.18 5,919.61 5,863.41 -521.57 -7,547.09 6,030,560.39 462,272.80 2.37 7,408.49 MWD+IFR2+MS+sag(6) 10,975.10 74.72 315.49 5,944.97 5,888.77 -456.84 -7,612.19 6,030,625.38 462,207.97 1.37 7,481.70 MWD+IFR2+MS+sag(6) 11,070.33 75.73 317.97 5,969.26 5,913.06 -389.80 -7,675.29 6,030,692.67 462,145.14 2.73 7,553.24 MWD+IFR2+MS+sag(6) 11,166.35 75.55 321.26 5,993.08 5,936.88 -318.96 -7,735.55 6,030,763.75 462,085.18 3.32 7,622.48 MWD+IFR2+MS+sag(6) 11,261.96 75.75 324.90 6,016.78 5,960.58 -244.92 -7,791.18 6,030,838.01 462,029.85 3.69 7,687.55 MWD+IFR2+MS+sag(6) 11,357.50 76.88 328.38 6,039.39 5,983.19 -167.40 -7,842.21 6,030,915.73 461,979.14 3.73 7,748.54 MWD+I FR2+MS+sag(6) 11,451.93 77.90 332.01 6,060.02 6,003.82 -87.45 -7,888.00 6,030,995.85 461,933.68 3.90 7,804.66 MWD+IFR2+MS+sag(6) 11,547.13 79.28 336.17 6,078.86 6,022.66 -3.53 -7,928.76 6,031,079.93 461,893.27 4.52 7,856.33 MWD+IFR2+MS+sag(6) 11,642.52 79.79 339.06 6,096.19 6,039.99 83.20 -7,964.48 6,031,166.79 461,857.91 3.03 7,903.38 MWD+IFR2+MS+sag(6) 11,736.96 79.85 338.89 6,112.88 6,056.68 169.96 -7,997.83 6,031,253.68 461,824.91 0.19 7,948.09 MWD+IFR2+MS+sag(6) 11,831.99 79.89 339.14 6,129.59 6,073.39 257.31 -8,031.33 6,031,341.15 461,791.77 0.26 7,993.03 MWD+IFR2+MS+sag(6) 11,927.00 79.58 341.03 6,146.52 6,090.32 345.20 -8,063.17 6,031,429.17 461,760.29 1.98 8,036.40 MWD+IFR2+MS+sag(6) 12,022.53 80.09 342.27 6,163.38 6,107.18 434.45 -8,092.78 6,031,518.52 461,731.05 1.38 8,077.73 MWD+IFR2+MS+sag(6) 12,067.94 80.08 343.26 6,171.20 6,115.00 477.17 -8,106.03 6,031,561.30 461,717.97 2.15 8,096.60 MWD+IFR2+MS+sag(6) 12,090.00 80.21 343.64 6,174.98 6,118.78 498.01 -8,112.22 6,031,582.15 461,711.87 1.81 8,105.54 MWD+IFR2+MS+sag(6) 12,122.46 80.82 341.19 6,180.33 6,124.13 528.52 -8,121.89 6,031,612.71 461,702.32 7.68 8,119.23 MWD+IFR2+MS+sag(7) 12,148.55 81.79 338.20 6,184.27 6,128.07 552.71 -8,130.84 6,031,636.92 461,693.47 11.92 8,131.34 MWD+IFR2+MS+sag(7) 12,196.49 83.40 336.52 6,190.45 6,134.25 596.58 -8,149.14 6,031,680.87 461,675.35 4.83 8,155.38 MWD+IFR2+MS+sag(7) 12,245.45 84.40 336.18 6,195.65 6,139.45 641.17 -8,168.67 6,031,725.53 461,656.00 2.16 8,180.72 MWD+IFR2+MS+sag(7) 12,289.71 84.07 336.40 6,200.10 6,143.90 681.49 -8,186.38 6,031,765.92 461,638.46 0.89 8,203.69 MWD+IFR2+MS+sag(7) 12,386.42 84.01 338.03 6,210.14 6,153.94 770.17 -8,223.63 6,031,854.74 461,601.58 1.68 8,252.52 MWD+IFR2+MS+sag(7) 12,483.58 83.89 342.52 6,220.39 6,164.19 861.10 -8,256.23 6,031,945.79 461,569.35 4.60 8,297.05 MWD+IFR2+MS+sag(7) 12,532.01 87.52 342.90 6,224.01 6,167.81 907.20 -8,270.58 6,031,991.95 461,555.19 7.54 8,317.46 MWD+IFR2+MS+sag(7) 12,579.25 88.92 342.40 6,225.48 6,169.28 952.27 -8,284.66 6,032,037.07 461,541.29 3.15 8,337.47 MWD+IFR2+MS+sag(7) 12,676.17 91.88 340.53 6,224.80 6,168.60 1,044.15 -8,315.46 6,032,129.06 461,510.86 3.61 8,380.35 MWD+IFR2+MS+sag(7) 12,771.79 93.54 338.11 6,220.28 6,164.08 1,133.49 -8,349.19 6,032,218.53 461,477.50 3.07 8,425.78 MWD+IFR2+MS+sag(7) 12,850.00 93.34 336.38 6,215.59 6,159.39 1,205.48 -8,379.38 6,032,290.64 461,447.60 2.22 8,465.38 MWD+IFR2+MS+sag(8) 12,867.91 92.47 337.25 6,214.68 6,158.48 1,221.93 -8,386.43 6,032,307.11 461,440.63 6.87 8,474.56 MWD+IFR2+MS+sag(8) 12,965.10 91.18 329.71 6,211.58 6,155.38 1,308.78 -8,429.77 6,032,394.13 461,397.64 7.87 8,529.19 MWD+I FR2+MS+sag(8) 13,061.01 90.94 326.12 6,209.81 6,153.61 1,390.01 -8,480.70 6,032,475.56 461,347.05 3.75 8,590.57 MWD+IFR2+MS+sag(8) 13,156.84 91.87 325.44 6,207.46 6,151.26 1,469.23 -8,534.57 6,032,554.98 461,293.50 1.20 8,654.61 MWD+IFR2+MS+sag(8) 13,253.35 89.57 323.76 6,206.24 6,150.04 1,547.88 -8,590.47 6,032,633.86 461,237.93 2.95 8,720.57 MWD+IFR2+MS+sag(8) 13,350.54 90.76 320.72 6,205.96 6,149.76 1,624.71 -8,649.98 6,032,710.92 461,178.74 3.36 8,789.86 MWD+IFR2+MS+sag(8) 13,446.19 94.36 320.50 6,201.69 6,145.49 1,698.55 -8,710.60 6,032,784.99 461,118.42 3.77 8,859.87 MWD+IFR2+MS+sag(8) 13,544.30 96.90 320.37 6,192.07 6,135.87 1,773.81 -8,772.79 6,032,860.50 461,056.55 2.59 8,931.60 MWD+IFR2+MS+sag(8) 13,639.07 97.39 320.51 6,180.28 6,124.08 1,846.30 -8,832.68 6,032,933.23 460,996.96 0.54 9,000.69 MWD+IFR2+MS+sag(8) 13,736.40 97.94 321.09 6,167.30 6,111.10 1,921.05 -8,893.64 6,033,008.22 460,936.31 0.82 9,071.15 MWD+IFR2+MS+sag(8) I 1/31/2011 9:31:53AM Page 6 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB5 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB5 Database: .Pioneer 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 ODSN-18-Slot ODS-18 Well Position +N/-S 0.00 ft Northing: 6,031,051.27 ft Latitude: 70°29'45.254 N +E/-W 0.00 ft Easting: 469,821.18 ft Longitude: 150°14'48.375 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSN-18 PB5 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (7) (7) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-18 PN11 PB5 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 13,350.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 290.79 Survey Program Date 1/27/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 141.00 981.00 ODSN-18 PB1 Gyro 1 (ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 10/25/2010 1,027.53 1,027.53 ODSN-18 PB1 MWD 1 (ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/2/2010 1: 1,123.00 1,123.00 ODSN-18 PB1 Gyro 2(ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 11/2/2010 t 1,174.40 3,566.42 ODSN-18 PB1 MWD 2(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/26/2010 3,630.15 8,392.10 ODSN-18 PB1 MWD 3(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/1/2010 1: 8,438.00 12,090.00 ODSN-18 PB2 MWD 4(ODSN-18 PB2) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/5/2010 t 12,122.46 12,771.79 ODSN-18 PB3 MWD 5(ODSN-18 PB3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/22/2010 12,850.00 13,350.00 ODSN-18 PB4 MWD 6(ODSN-18 PB4) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/30/2010 13,375.00 14,796.87 ODSN-18 PB5 MWD 7(ODSN-18 PB5)MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 1/1/2011 12: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (7) (7) (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 6,031,051.27 469,821.18 0.00 0.00 UNDEFINED 141.00 0.26 304.00 141.00 84.80 0.13 -0.19 6,031,051.40 469,820.99 0.26 0.22 SR-Gyro-SS(1) 199.00 0.27 348.71 199.00 142.80 0.33 -0.32 6,031,051.60 469,820.86 0.35 0.42 SR-Gyro-SS(1) 232.00 0.49 322.56 232.00 175.80 0.52 -0.42 6,031,051.79 469,820.76 0.83 0.58 SR-Gyro-SS(1) 290.00 0.48 322.52 290.00 233.80 0.91 -0.72 6,031,052.18 469,820.46 0.02 1.00 SR-Gyro-SS(1) 323.00 0.93 308.43 322.99 266.79 1.19 -1.02 6,031,052.46 469,820.17 1.45 1.37 SR-Gyro-SS(1) 382.00 1.25 295.72 381.98 325.78 1.76 -1.97 6,031,053.04 469,819.22 0.68 2.47 SR-Gyro-SS(1) 1/31/2011 9:29:49AM Page 2 COMPASS 2003.16 Build 42F Halliburton Company . Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB5 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB5 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 415.00 1.90 288.47 414.97 358.77 2.09 -2.81 6,031,053.38 469,818.38 2.06 3.37 SR-Gyro-SS(1) I 472.00 2.17 284.07 471.93 415.73 2.66 -4.76 6,031,053.94 469,816.43 0.55 5.39 SR-Gyro-SS(1) 505.00 2.74 284.05 504.90 448.70 3.00 -6.13 6,031,054.29 469,815.06 1.73 6.79 SR-Gyro-SS(1) 568.00 3.14 281.82 567.82 511.62 3.72 -9.28 6,031,055.03 469,811.92 0.66 9.99 SR-Gyro-SS(1) , 601.00 3.54 281.44 600.76 544.56 4.11 -11.16 6,031,055.42 469,810.04 1.21 11.89 SR-Gyro-SS(1) 662.00 3.66 281.14 661.64 605.44 4.86 -14.92 6,031,056.19 469,806.28 0.20 15.67 SR-Gyro-SS(1) 685.00 3.95 280.22 684.59 628.39 5.14 -16.42 6,031,056.47 469,804.79 1.29 17.17 SR-Gyro-SS(1) 758.00 4.41 281.46 757.40 701.20 6.14 -21.64 6,031,057.50 469,799.57 0.64 22.41 SR-Gyro-SS(1) 791.00 4.78 281.29 790.29 734.09 6.66 -24.23 6,031,058.03 469,796.98 1.12 25.02 SR-Gyro-SS(1) 853.00 5.29 282.35 852.05 795.85 7.78 -29.56 6,031,059.17 469,791.66 0.84 30.39 SR-Gyro-SS(1) 886.00 5.85 279.85 884.90 828.70 8.39 -32.70 6,031,059.79 469,788.52 1.85 33.55 SR-Gyro-SS(1) 948.00 6.88 279.90 946.51 890.31 9,57 -39.47 6,031,061.00 469,781.75 1.66 40.30 SR-Gyro-SS(1) 981.00 6.89 278.10 979.28 923.08 10.19 -43.38 6,031,061.64 469,777.85 0.65 44.17 SR-Gyro-SS(1) 1,027.53 6.83 276.30 1,025.47 969.27 10.89 -48.89 6,031,062.35 469,772.34 0.48 49.57 MWD+IFR2+MS+sag(2) 1,123.00 9.55 277.06 1,119.96 1,063.76 12.48 -62.40 6,031,064.01 469,758.84 2.85 62.76 SR-Gyro-SS(3) 1,174.43 9.71 277.20 1,170.67 1,114.47 13.55 -70.93 6,031,065.11 469,750.31 0.31 71.12 MWD+IFR2+MS+sag(4) 1,218.54 9.91 278.29 1,214.13 1,157.93 14.57 -78.38 6,031,066.15 469,742.87 0.62 78.45 MWD+IFR2+MS+sag(4) 1,314.10 9.75 271.65 1,308.29 1,252.09 15.98 -94.61 6,031,067.64 469,726.65 1.20 94.12 MWD+IFR2+MS+sag(4) 1,409.32 10.15 272.52 1,402.08 1,345.88 16.59 -111.05 6,031,068.30 469,710.21 0.45 109.70 MWD+IFR2+MS+sag(4) 1,504.37 10.95 274.95 1,495.52 1,439.32 17.73 -128.41 6,031,069.52 469,692.86 0.96 126.34 MWD+IFR2+MS+sag(4) 1,599.91 12.48 272.29 1,589.07 1,532.87 18.93 -147.77 6,031,070.80 469,673.51 1.70 144.86 MWD+IFR2+MS+sag(4) 1,631.69 12.76 273.11 1,620.08 1,563.88 19.26 -154.70 6,031,071.15 469,666.57 1.05 151.46 MWD+IFR2+MS+sag(4) 1,725.28 14.37 274.13 1,711.06 1,654.86 20.65 -176.61 6,031,072.64 469,644.68 1.74 172.44 MWD+IFR2+MS+sag(4) 1,821.10 13.44 273.34 1,804.07 1,747.87 22.16 -199.58 6,031,074.24 469,621.71 0.99 194.45 MWD+IFR2+MS+sag(4) 1,915.58 15.28 274.70 1,895.59 1,839.39 23.82 -222.95 6,031,075.99 469,598.35 1.98 216.89 MWD+IFR2+MS+sag(4) 2,011.74 15.85 275.48 1,988.23 1,932.03 26.11 -248.65 6,031,078.39 469,572.66 0.63 241.73 MWD+IFR2+MS+sag(4) 2,107.39 14.66 274.53 2,080.51 2,024.31 28.31 -273.72 6,031,080.69 469,547.60 1.27 265.95 MWD+IFR2+MS+sag(4) 2,202.94 13.62 277.80 2,173.16 2,116.96 30.80 -296.92 6,031,083.27 469,524.41 1.37 288.52 MWD+IFR2+MS+sag(4) 2,241.41 13.96 276.43 2,210.52 2,154.32 31.93 -306.02 6,031,084.44 469,515.32 1.23 297.43 MWD+IFR2+MS+sag(4) 2,298.61 14.97 276.21 2,265.91 2,209.71 33.50 -320.22 6,031,086.07 469,501.13 1.77 311.26 MWD+IFR2+MS+sag(4) 2,333.40 15.89 274.27 2,299.44 2,243.24 34.34 -329.44 6,031,086.95 469,491.92 3.03 320.18 MWD+IFR2+MS+sag(4) 2,393.28 16.92 271.13 2,356.89 2,300.69 35.12 -346.33 6,031,087.80 469,475.03 2.27 336.24 MWD+IFR2+MS+sag(4) 2,488.03 20.47 266.74 2,446.63 2,390.43 34.45 -376.67 6,031,087.25 469,444.70 4.03 364.37 MWD+IFR2+MS+sag(4) 2,583.22 24.38 267.73 2,534.60 2,478.40 32.73 -412.93 6,031,085.67 469,408.43 4.13 397.66 MWD+IFR2+MS+sag(4) j 2,678.36 29.60 267.12 2,619.35 2,563.15 30.77 -456.05 6,031,083.89 469,365.31 5.49 437.27 MWD+IFR2+MS+sag(4) 2,773.39 32.86 268.44 2,700.60 2,644.40 28.89 -505.27 6,031,082.21 469,316.08 3.51 482.62 MWD+IFR2+MS+sag(4) 2,868.92 36.48 268.01 2,779.16 2,722.96 27.20 -559.58 6,031,080.73 469,261.77 3.80 532.79 MWD+IFR2+MS+sag(4) 2,963.62 38.66 267.56 2,854.21 2,798.01 24.96 -617.27 6,031,078.73 469,204.08 2.32 585.94 MWD+IFR2+MS+sag(4) 3,059.68 38.65 266.41 2,929.23 2,873.03 21.80 -677.19 6,031,075.82 469,144.15 0.75 640.83 MWD+IFR2+MS+sag(4) 3,155.09 41.44 265.51 3,002.26 2,946.06 17.46 -738.41 6,031,071.73 469,082.92 2.99 696.53 MWD+IFR2+MS+sag(4) 1/31/2011 9:29:49AM Page 3 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB5 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB5 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,249.55 42.15 264.91 3,072.68 3,016.48 12.20 -801.15 6,031,066.73 469,020.17 0.86 753.31 MWD+IFR2+MS+sag(4) 3,344.92 46.28 265.36 3,141.02 3,084.82 6.58 -867.40 6,031,061.37 468,953.90 4.34 813.25 MWD+IFR2+MS+sag(4) 3,439.63 48.20 265.43 3,205.32 3,149.12 0.99 -936.71 6,031,056.07 468,884.58 2.03 876.07 MWD+IFR2+MS+sag(4) 3,534.85 49.89 264.83 3,267.73 3,211.53 -5.12 -1,008.36 6,031,050.25 468,812.91 1.84 940.88 MWD+IFR2+MS+sag(4) 3,566.42 50.37 265.46 3,287.97 3,231.77 -7.17 -1,032.50 6,031,048.30 468,788.76 2.16 962.73 MWD+IFR2+MS+sag(4) 3,630.15 49.94 264.80 3,328.80 3,272.60 -11.32 -1,081.25 6,031,044.34 468,740.00 1.04 1,006.83 MWD+IFR2+MS+sag(5) 3,728.64 48.98 264.86 3,392.82 3,336.62 -18.06 -1,155.80 6,031,037.90 468,665.44 0.98 1,074.13 MWD+IFR2+MS+sag(5) 3,823.03 48.55 265.70 3,455.04 3,398.84 -23.91 -1,226.54 6,031,032.35 468,594.68 0.81 1,138.19 MWD+IFR2+MS+sag(5) 3,918.36 47.71 266.13 3,518.66 3,462.46 -28.97 -1,297.34 6,031,027.57 468,523.86 0.94 1,202.59 MWD+IFR2+MS+sag(5) 4,013.58 47.75 266.18 3,582.71 3,526.51 -33.69 -1,367.65 6,031,023.14 468,453.55 0.06 1,266.64 MWD+IFR2+MS+sag(5) 4,108.84 51.32 267.02 3,644.52 3,588.32 -37.97 -1,439.98 6,031,019.15 468,381.20 3.81 1,332.74 MWD+IFR2+MS+sag(5) 4,203.49 54.06 266.88 3,701.89 3,645.69 -41.98 -1,515.15 6,031,015.45 468,306.03 2.90 1,401.59 MWD+IFR2+MS+sag(5) 4,300.86 56.97 265.70 3,757.01 3,700.81 -47.19 -1,595.23 6,031,010.56 468,225.93 3.15 1,474.61 MWD+I FR2+MS+sag(5) 4,398.80 58.70 262.86 3,809.16 3,752.96 -55.47 -1,677.71 6,031,002.62 468,143.43 3.02 1,548.78 MW D+I FR2+MS+sag(5) 4,493.85 61.31 259.87 3,856.68 3,800.48 -67.85 -1,759.07 6,030,990.57 468,062.03 3.87 1,620.44 MWD+IFR2+MS+sag(5) 4,584.47 65.00 259.37 3,897.60 3,841.40 -82.42 -1,838.58 6,030,976.32 467,982.46 4.10 1,689.61 MWD+IFR2+MS+sag(5) 4,684.58 67.49 257.58 3,937.92 3,881.72 -100.74 -1,928.35 6,030,958.37 467,892.63 2.98 1,767.03 MWD+IFR2+MS+sag(5) 4,779.26 68.84 257.43 3,973.14 3,916.94 -119.76 -2,014.15 6,030,939.70 467,806.76 1.43 1,840.50 MWD+I FR2+MS+sag(5) 4,871.89 70.51 256.93 4,005.31 3,949.11 -139.03 -2,098.85 6,030,920.77 467,722.00 1.87 1,912.84 MWD+IFR2+MS+sag(5) 4,965.11 71.34 257.43 4,035.78 3,979.58 -158.58 -2,184.75 6,030,901.58 467,636.02 1.02 1,986.21 MWD+IFR2+MS+sag(5) 5,063.57 71.46 258.28 4,067.18 4,010.98 -178.21 -2,275.98 6,030,882.32 467,544.73 0.83 2,064.53 MWD+IFR2+MS+sag(5) 5,159.38 71.34 258.20 4,097.74 4,041.54 -196.72 -2,364.88 6,030,864.17 467,455.76 0.15 2,141.07 MWD+IFR2+MS+sag(5) 5,254.53 71.20 258.00 4,128.29 4,072.09 -215.30 -2,453.05 6,030,845.95 467,367.52 0.25 2,216.91 MWD+IFR2+MS+sag(5) 5,345.36 70.63 257.39 4,157.99 4,101.79 -233.59 -2,536.92 6,030,828.00 467,283.59 0.89 2,288.82 MWD+IFR2+MS+sag(5) 5,441.12 71.23 257.83 4,189.28 4,133.08 -253.01 -2,625.31 6,030,808.94 467,195.13 0.76 2,364.57 MWD+IFR2+MS+sag(5) 5,536.74 71.07 258.19 4,220.17 4,163.97 -271.81 -2,713.83 6,030,790.51 467,106.54 0.39 2,440.65 MWD+IFR2+MS+sag(5) 5,631.50 70.36 258.20 4,251.47 4,195.27 -290.11 -2,801.38 6,030,772.57 467,018.93 0.75 2,516.00 MWD+IFR2+MS+sag(5) 5,727.44 70.95 258.18 4,283.25 4,227.05 -308.63 -2,889.99 6,030,754.40 466,930.25 0.62 2,592.26 MWD+IFR2+MS+sag(5) 5,824.68 70.61 258.07 4,315.26 4,259.06 -327.53 -2,979.84 6,030,735.87 466,840.33 0.37 2,669.56 MWD+IFR2+MS+sag(5) 5,917.59 70.86 257.56 4,345.92 4,289.72 -346.04 -3,065.57 6,030,717.71 466,754.54 0.58 2,743.14 MWD+IFR2+MS+sag(5) 6,011.23 71.05 257.12 4,376.47 4,320.27 -365.44 -3,151.94 6,030,698.66 466,668.11 0.49 2,816.99 MWD+IFR2+MS+sag(5) 6,109.85 70.29 255.57 4,409.12 4,352.92 -387.41 -3,242.36 6,030,677.07 466,577.60 1.67 2,893.74 MWD+IFR2+MS+sag(5) 6,206.00 70.35 256.98 4,441.50 4,385.30 -408.89 -3,330.31 6,030,655.95 466,489.58 1.38 2,968.33 MWD+IFR2+MS+sag(5) 6,296.96 70.47 257.77 4,472.00 4,415.80 -427.62 -3,413.93 6,030,637.56 466,405.89 0.83 3,039.86 MWD+IFR2+MS+sag(5) 6,392.50 70.96 258.81 4,503.55 4,447.35 -445.92 -3,502.23 6,030,619.62 466,317.52 1.15 3,115.92 MWD+IFR2+MS+sag(5) 6,487.74 71.03 259.25 4,534.57 4,478.37 -463.05 -3,590.63 6,030,602.84 466,229.06 0.44 3,192.48 MWD+IFR2+MS+sag(5) ' 6,582.74 70.87 258.69 4,565.57 4,509.37 -480.23 -3,678.77 6,030,586.02 466,140.86 0.58 3,268.78 MWD+IFR2+MS+sag(5) 6,677.75 70.73 259.06 4,596.82 4,540.62 -497.54 -3,766.81 6,030,569.07 466,052.76 0.40 3,344.94 MWD+IFR2+MS+sag(5) 6,773.48 71.16 258.45 4,628.07 4,571.87 -515.19 -3,855.56 6,030,551.79 465,963.95 0.75 3,421.65 MWD+IFR2+MS+sag(5) 6,868.81 71.27 257.68 4,658.77 4,602.57 -533.85 -3,943.86 6,030,533.48 465,875.59 0.77 3,497.57 MWD+IFR2+MS+sag(5) 1/31/2011 9:29:49AM Page 4 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB5 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB5 Database: .Pioneer 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) (°I100') (ft) Survey Tool Name 6,964.81 70.80 259.14 4,689.97 4,633.77 -552.10 -4,032.79 6,030,515.61 465,786.59 1.52 3,574.24 MWD+IFR2+MS+sag(5) 7,058.66 71.73 258.75 4,720.12 4,663.92 -569.14 -4,120.02 6,030,498.92 465,699.30 1.07 3,649.74 MWD+IFR2+MS+sag(5) 7,155.94 70.48 258.65 4,751.62 4,695.42 -587.17 -4,210.27 6,030,481.25 465,608.99 1.29 3,727.72 MWD+IFR2+MS+sag(5) 7,249.11 70.27 258.33 4,782.91 4,726.71 -604.68 -4,296.26 6,030,464.09 465,522.93 0.39 3,801.89 MWD+IFR2+MS+sag(5) 7,345.08 71.16 258.01 4,814.61 4,758.41 -623.25 -4,384.92 6,030,445.88 465,434.21 0.98 3,878.19 MWD+IFR2+MS+sag(5) 7,441.17 70.89 257.84 4,845.85 4,789.65 -642.26 -4,473.78 6,030,427.24 465,345.28 0.33 3,954.51 MWD+IFR2+MS+sag(5) 7,536.09 69.56 258.34 4,877.96 4,821.76 -660.70 -4,561.18 6,030,409.16 465,257.82 1.49 4,029.68 MWD+IFR2+MS+sag(5) 7,626.41 69.56 260.20 4,909.51 4,853.31 -676.45 -4,644.33 6,030,393.74 465,174.61 1.93 4,101.82 MWD+IFR2+MS+sag(5) 7,726.42 69.36 260.00 4,944.60 4,888.40 -692.56 -4,736.58 6,030,378.02 465,082.30 0.27 4,182.35 MWD+IFR2+MS+sag(5) 7,820.69 69.02 260.88 4,978.09 4,921.89 -707.19 -4,823.48 6,030,363.74 464,995.36 0.94 4,258.40 MWD+IFR2+MS+sag(5) 7,915.20 69.21 260.17 5,011.78 4,955.58 -721.73 -4,910.57 6,030,349.56 464,908.21 0.73 4,334.66 MWD+IFR2+MS+sag(5) 8,011.00 69.69 260.57 5,045.41 4,989.21 -736.73 -4,999.01 6,030,334.91 464,819.72 0.64 4,412.02 MWD+IFR2+MS+sag(5) 8,106.40 69.26 260.81 5,078.86 5,022.66 -751.19 -5,087.18 6,030,320.82 464,731.51 0.51 4,489.31 MWD+IFR2+MS+sag(5) 8,201.28 69.17 260.04 5,112.53 5,056.33 -765.94 -5,174.65 6,030,306.42 464,643.99 0.76 4,565.85 MWD+IFR2+MS+sag(5) 8,296.82 69.86 258.87 5,145.97 5,089.77 -782.32 -5,262.63 6,030,290.40 464,555.95 1.36 4,642.29 MWD+IFR2+MS+sag(5) 8,392.12 69.57 258.47 5,179.00 5,122.80 -799.88 -5,350.28 6,030,273.19 464,468.24 0.50 4,718.00 MWD+IFR2+MS+sag(5) 8,438.00 69.60 258.48 5,195.01 5,138.81 -808.47 -5,392.41 6,030,264.77 464,426.07 0.07 4,754.33 MWD+IFR2+MS+sag(6) 8,529.05 72.36 255.25 5,224.69 5,168.49 -828.05 -5,476.21 6,030,245.54 464,342.20 4.52 4,825.73 MWD+IFR2+MS+sag(6) 8,575.56 73.36 254.40 5,238.39 5,182.19 -839.68 -5,519.11 6,030,234.08 464,299.27 2.77 4,861.70 MWD+IFR2+MS+sag(6) 8,670.27 74.48 252.70 5,264.63 5,208.43 -865.46 -5,606.38 6,030,208.67 464,211.90 2.09 4,934.14 MWD+IFR2+MS+sag(6) 8,718.63 74.39 251.47 5,277.60 5,221.40 -879.79 -5,650.71 6,030,194.52 464,167.52 2.46 4,970.50 MWD+IFR2+MS+sag(6) 8,785.71 74.04 252.09 5,295.85 5,239.65 -899.97 -5,712.02 6,030,174.59 464,106.13 1.03 5,020.66 MWD+IFR2+MS+sag(6) 8,881.94 73.38 251.52 5,322.84 5,266.64 -928.81 -5,799.77 6,030,146.10 464,018.28 0.89 5,092.45 MWD+IFR2+MS+sag(6) 8,977.86 73.11 252.53 5,350.50 5,294.30 -957.15 -5,887.13 6,030,118.12 463,930.81 1.05 5,164.07 MWD+IFR2+MS+sag(6) 9,072.22 72.75 254.47 5,378.20 5,322.00 -982.77 -5,973.61 6,030,092.85 463,844.23 2.00 5,235.83 MWD+IFR2+MS+sag(6) 9,168.00 72.53 256.55 5,406.78 5,350.58 -1,005.65 -6,062.12 6,030,070.34 463,755.64 2.09 5,310.45 MWD+IFR2+MS+sag(6) 9,262.77 72.47 260.99 5,435.29 5,379.09 -1,023.24 -6,150.74 6,030,053.11 463,666.95 4.47 5,387.06 MWD+IFR2+MS+sag(6) 9,357.47 72.46 264.53 5,463.83 5,407.63 -1,034.62 -6,240.31 6,030,042.09 463,577.35 3.56 5,466.75 MWD+IFR2+MS+sag(6) 9,452.53 71.85 267.34 5,492.97 5,436.77 -1,041.04 -6,330.55 6,030,036.04 463,487.09 2.89 5,548.84 MWD+IFR2+MS+sag(6) 9,547.64 72.27 271.43 5,522.27 5,466.07 -1,042.01 -6,421.01 6,030,035.44 463,396.64 4.11 5,633.07 MWD+IFR2+MS+sag(6) 9,642.41 72.06 275.01 5,551.31 5,495.11 -1,036.94 -6,511.07 6,030,040.87 463,306.61 3.60 5,719.06 MWD+IFR2+MS+sag(6) 9,737.67 71.99 278.14 5,580.71 5,524.51 -1,026.57 -6,601.07 6,030,051.61 463,216.66 3.13 5,806.88 MWD+IFR2+MS+sag(6) 9,833.18 71.37 281.53 5,610.74 5,554.54 -1,011.09 -6,690.39 6,030,067.45 463,127.42 3.43 5,895.88 MWD+IFR2+MS+sag(6) 9,929.57 71.41 286.08 5,641.51 5,585.31 -989.30 -6,779.07 6,030,089.60 463,038.83 4.47 5,986.53 MWD+IFR2+MS+sag(6) 10,024.64 71.38 289.64 5,671.85 5,615.65 -961.67 -6,864.82 6,030,117.57 462,953.21 3.55 6,076.49 MWD+IFR2+MS+sag(6) 10,118.68 72.08 292.42 5,701.34 5,645.14 -929.62 -6,948.16 6,030,149.95 462,870.01 2.90 6,165.78 MWD+IFR2+MS+sag(6) 10,214.27 72.08 296.36 5,730.76 5,674.56 -892.07 -7,030.97 6,030,187.83 462,787.35 3.92 6,256.53 MWD+IFR2+MS+sag(6) 10,309.31 71.94 299.25 5,760.12 5,703.92 -849.92 -7,110.92 6,030,230.31 462,707.59 2.90 6,346.24 MWD+IFR2+MS+sag(6) 10,404.13 72.22 300.94 5,789.30 5,733.10 -804.68 -7,188.97 6,030,275.86 462,629.73 1.72 6,435.27 MWD+IFR2+MS+sag(6) 10,498.75 73.56 303.93 5,817.14 5,760.94 -756.17 -7,265.28 6,030,324.67 462,553.62 3.34 6,523.82 MWD+IFR2+MS+sag(6) 1/31/2011 9:29:49AM Page 5 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB5 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB5 Database: .Pioneer 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) (°I100') (ft) Survey Tool Name 10,593.70 74.26 308.42 5,843.47 5,787.27 -702.34 -7,338.90 6,030,378.80 462,480.23 4.60 6,611.75 MWD+IFR2+MS+sag(6) 10,689.51 74.46 309.71 5,869.30 5,813.10 -644.19 -7,410.53 6,030,437.23 462,408.84 1.31 6,699.36 MWD+IFR2+MS+sag(6) 10,784.19 74.92 311.89 5,894.30 5,838.10 -584.53 -7,479.65 6,030,497.17 462,339.97 2.27 6,785.16 MWD+IFR2+MS+sag(6) 10,879.86 74.40 314.18 5,919.61 5,863.41 -521.57 -7,547.09 6,030,560.39 462,272.80 2.37 6,870.55 MWD+IFR2+MS+sag(6) 10,975.10 74.72 315.49 5,944.97 5,888.77 -456.84 -7,612.19 6,030,625.38 462,207.97 1.37 6,954.38 MWD+IFR2+MS+sag(6) 11,070.33 75.73 317.97 5,969.26 5,913.06 -389.80 -7,675.29 6,030,692.67 462,145.14 2.73 7,037.18 MWD+IFR2+MS+sag(6) 11,166.35 75.55 321.26 5,993.08 5,936.88 -318.96 -7,735.55 6,030,763.75 462,085.18 3.32 7,118.66 MWD+IFR2+MS+sag(6) 11,261.96 75.75 324.90 6,016.78 5,960.58 -244.92 -7,791.18 6,030,838.01 462,029.85 3.69 7,196.95 MWD+IFR2+MS+sag(6) 11,357.50 76.88 328.38 6,039.39 5,983.19 -167.40 -7,842.21 6,030,915.73 461,979.14 3.73 7,272.17 MWD+IFR2+MS+sag(6) 11,451.93 77.90 332.01 6,060.02 6,003.82 -87.45 -7,888.00 6,030,995.85 461,933.68 3.90 7,343.36 MWD+IFR2+MS+sag(6) 11,547.13 79.28 336.17 6,078.86 6,022.66 -3.53 -7,928.76 6,031,079.93 461,893.27 4.52 7,411.25 MWD+IFR2+MS+sag(6) 11,642.52 79.79 339.06 6,096.19 6,039.99 83.20 -7,964.48 6,031,166.79 461,857.91 3.03 7,475.42 MWD+IFR2+MS+sag(6) 11,736.96 79.85 338.89 6,112.88 6,056.68 169.96 -7,997.83 6,031,253.68 461,824.91 0.19 7,537.40 MWD+IFR2+MS+sag(6) 11,831.99 79.89 339.14 6,129.59 6,073.39 257.31 -8,031.33 6,031,341.15 461,791.77 0.26 7,599.72 MWD+IFR2+MS+sag(6) 11,927.00 79.58 341.03 6,146.52 6,090.32 345.20 -8,063.17 6,031,429.17 461,760.29 1.98 7,660.69 MWD+IFR2+MS+sag(6) 12,022.53 80.09 342.27 6,163.38 6,107.18 434.45 -8,092.78 6,031,518.52 461,731.05 1.38 7,720.04 MWD+IFR2+MS+sag(6) 12,067.94 80.08 343.26 6,171.20 6,115.00 477.17 -8,106.03 6,031,561.30 461,717.97 2.15 7,747.59 MWD+IFR2+MS+sag(6) 12,090.00 80.21 343.64 6,174.98 6,118.78 498.01 -8,112.22 6,031,582.15 461,711.87 1.81 7,760.78 MW D+I FR2+MS+sag(6) 12,122.46 80.82 341.19 6,180.33 6,124.13 528.52 -8,121.89 6,031,612.71 461,702.32 7.68 7,780.65 MWD+IFR2+MS+sag(7) 12,148.55 81.79 338.20 6,184.27 6,128.07 552.71 -8,130.84 6,031,636.92 461,693.47 11.92 7,797.60 MWD+IFR2+MS+sag(7) 12,196.49 83.40 336.52 6,190.45 6,134.25 596.58 -8,149.14 6,031,680.87 461,675.35 4.83 7,830.28 MWD+IFR2+MS+sag(7) 12,245.45 84.40 336.18 6,195.65 6,139.45 641.17 -8,168.67 6,031,725.53 461,656.00 2.16 7,864.37 MWD+IFR2+MS+sag(7) 12,289.71 84.07 336.40 6,200.10 6,143.90 681.49 -8,186.38 6,031,765.92 461,638.46 0.89 7,895.23 MWD+IFR2+MS+sag(7) 12,386.42 84.01 338.03 6,210.14 6,153.94 770.17 -8,223.63 6,031,854.74 461,601.58 1.68 7,961.53 MWD+IFR2+MS+sag(7) 12,483.58 83.89 342.52 6,220.39 6,164.19 861.10 -8,256.23 6,031,945.79 461,569.35 4.60 8,024.29 MWD+IFR2+MS+sag(7) 12,532.01 87.52 342.90 6,224.01 6,167.81 907.20 -8,270.58 6,031,991.95 461,555.19 7.54 8,054.07 MWD+IFR2+MS+sag(7) 12,579.25 88.92 342.40 6,225.48 6,169.28 952.27 -8,284.66 6,032,037.07 461,541.29 3.15 8,083.23 MWD+IFR2+MS+sag(7) 12,676.17 91.88 340.53 6,224.80 6,168.60 1,044.15 -8,315.46 6,032,129.06 461,510.86 3.61 8,144.63 MWD+IFR2+MS+sag(7) 12,771.79 93.54 338.11 6,220.28 6,164.08 1,133.49 -8,349.19 6,032,218.53 461,477.50 3.07 8,207.88 MWD+IFR2+MS+sag(7) 12,850.00 93.34 336.38 6,215.59 6,159.39 1,205.48 -8,379.38 6,032,290.64 461,447.60 2.22 8,261.66 MWD+I FR2+MS+sag(8) 12,867.91 92.47 337.25 6,214.68 6,158.48 1,221.93 -8,386.43 6,032,307.11 461,440.63 6.87 8,274.08 MWD+IFR2+MS+sag(8) 12,965.10 91.18 329.71 6,211.58 6,155.38 1,308.78 -8,429.77 6,032,394.13 461,397.64 7.87 8,345.43 MWD+IFR2+MS+sag(8) 13,061.01 90.94 326.12 6,209.81 6,153.61 1,390.01 -8,480.70 6,032,475.56 461,347.05 3.75 8,421.87 MWD+IFR2+MS+sag(8) 13,156.84 91.87 325.44 6,207.46 6,151.26 1,469.23 -8,534.57 6,032,554.98 461,293.50 1.20 8,500.36 MWD+IFR2+MS+sag(8) 13,253.35 89.57 323.76 6,206.24 6,150.04 1,547.88 -8,590.47 6,032,633.86 461,237.93 2.95 8,580.53 MWD+IFR2+MS+sag(8) 13,375.00 91.68 320.68 6,204.92 6,148.72 1,644.01 -8,664.98 6,032,730.27 461,163.82 3.07 8,684.31 MWD+IFR2+MS+sag(9) 13,446.88 90.87 317.43 6,203.32 6,147.12 1,698.28 -8,712.07 6,032,784.73 461,116.96 4.66 8,747.59 MWD+IFR2+MS+sag(9) 13,543.96 91.45 317.15 6,201.35 6,145.15 1,769.60 -8,777.90 6,032,856.31 461,051.42 0.66 8,834.46 MWD+IFR2+MS+sag(9) 13,641.29 94.56 317.18 6,196.25 6,140.05 1,840.87 -8,843.97 6,032,927.84 460,985.64 3.20 8,921.52 MWD+IFR2+MS+sag(9) 13,739.42 93.61 316.67 6,189.26 6,133.06 1,912.36 -8,910.82 6,032,999.60 460,919.09 1.10 9,009.40 MWD+IFR2+MS+sag(9) 1/31/2011 9:29:49AM Page 6 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB5 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB5 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 13,834.13 94.61 317.01 6,182.47 6,126.27 1,981.27 -8,975.44 6,033,068.76 460,854.76 1.11 9,094.27 MWD+IFR2+MS+sag(9) 13,931.48 94.29 317.29 6,174.92 6,118.72 2,052.43 -9,041.45 6,033,140.18 460,789.05 0.44 9,181.23 MWD+IFR2+MS+sag(9) 14,027.23 94.23 318.52 6,167.81 6,111.61 2,123.28 -9,105.45 6,033,211.28 460,725.34 1.28 9,266.22 MWD+IFR2+MS+sag(9) 14,123.13 93.79 319.76 6,161.10 6,104.90 2,195.63 -9,168.04 6,033,283.88 460,663.06 1.37 9,350.41 MWD+IFR2+MS+sag(9) 14,218.72 89.45 320.37 6,158.40 6,102.20 2,268.88 -9,229.36 6,033,357.37 460,602.04 4.58 9,433.74 MWD+IFR2+MS+sag(9) 14,315.07 86.86 319.79 6,161.50 6,105.30 2,342.73 -9,291.15 6,033,431.46 460,540.55 2.75 9,517.72 MWD+IFR2+MS+sag(9) 14,411.34 85.57 318.65 6,167.85 6,111.65 2,415.47 -9,353.89 6,033,504.44 460,478.12 1.79 9,602.19 MWD+IFR2+MS+sag(9) 14,507.77 86.70 319.05 6,174.35 6,118.15 2,487.91 -9,417.20 6,033,577.14 460,415.11 1.24 9,687.09 MWD+IFR2+MS+sag(9) 14,604.45 81.76 320.25 6,184.07 6,127.87 2,561.19 -9,479.46 6,033,650.66 460,353.15 5.26 9,771.31 MWD+IFR2+MS+sag(9) 14,700.67 82.59 319.87 6,197.17 6,140.97 2,634.28 -9,540.66 6,033,723.99 460,292.26 0.95 9,854.46 MWD+IFR2+MS+sag(9) 14,796.87 82.15 317.76 6,209.95 6,153.75 2,706.03 -9,603.44 6,033,795.99 460,229.78 2.22 9,938.62 MWD+IFR2+MS+sag(9) 14,843.00 82.15 317.76 6,216.25 6,160.05 2,739.86 -9,634.16 6,033,829.94 460,199.20 0.00 9,979.35 PROJECTED to TD 1/31/2011 9:29:49AM Page 7 COMPASS 2003.16 Build 42F .......,\., '' 1-• 0 ...) .-, :.N '--.• •--.• • '..' 1-'2, -- rj NJ 1 i hs.,. r4- = -CI / --.. . 0 (1) 76 --------43 X. 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O CD fa} I I I I o 0 p p Vw N N W (T A - -• A W N - O W coT 3▪ 3 N N) -, T1 r CD CD cO N 6) CO CO N N O J co CO N j a s N N N N N N N �' -K1_ O O_, O O O O, �O O O 0 O O� ? CD CD A it - -1 - � -' - -1 O p 0 Om N L -0 -0 N \ 3:- . o II II c c NQ rt N = = N m Al 3 8 N 1 i f"-- O - .s a II it z o 0) O O L S r �� Q II <O m ,. 11 O < ,, n o 0 +- " 4 II co ,N Q o i,. L C O II II j 0 v Restricted Season s-- O Q • 7 o rn d cn — n rn 1 m ei '` Hazzard, Vance From: OoogurukDrillingSupervisor Sent: Tuesday, January 18, 2011 12:54 PM To: Johnson, Vern; Hazzard, Vance Cc: Tirpack, Robert; Crumrine, Tim; Zimmer, Marvin Subject: IA&OA test chart. 1St Test. 1. Initial OA pressure 210 psi. 2. IA pressure 0 psi. 3. Pressured up IA t/2,300 psi. 4. OA pressure increased t/500 psi. 5. 30 min OA increased 640 psi. 6. 30 min IA decreased to 1,850 psi. 2nd Test PTv z/o -/ie_ 1. Initital OA pressure 100 psi. 2. IA pressure 0 psi. 3. Pressured up IA t/2,300 psi. 4. OA increased to 370 psi. 5. 30 min OA increased 515 psi. 6. 30 min IA decreased to 1,800 psi. 7. Bleed down IA to 0 psi. 8. 30 min static test on OA. Pressure bleed back to 370 psi w/o IA pressure increase. Red'weey e. i�e,frip y Pioneer Wellsite Leader Pioner Natural Resources Alaska, Inc. Office # 907-670-6606 Cell # 907-440-9994. This email was sent on 1/18/11 at 12:53 PM by klepzigr. i."--- r,z- , :,-":;,-s+6* „,...------- ---,0„„iiiii•ele, - 4—_____ ••••••• Allirw ---ftoitty , '‘ '' \ .,/, ,,0, ,, m-w- ,,M Wm,.-:=Wr Ai•S*t L'- *‘<\\ **,,,\7\4W / /7; -.- , A • , idigiut.7_,,,41,-4.44k7, ,N.--,x,, s'N„.. \ \N" th., al? *Ao0•04000112,50,4. - ,40„,\0,\A",,, :-, \ tit was %, i Mitsfri#444,0414111,17. 'IT Isat1/4*1 \ *4,t\ A II% iti Illill 144,01t44* °. 7:(90,4"0"AtaSx inSA1111111% lit rdiilnielitti 6,04..:4't illitatipedttil e RIR iiktippnilliiikial , ( J 111111111111111 10141 " ii 1 lb 4' luitatzoo. 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WA WS r MO 0 0 All 40.1 74f4 / ‘%, 1,W**,111�� w }`i 9 AO etril,/,' ODS. 18 Completion - As EllAlt Well Head: 9-5/8",5K,VetcoGray Tree: 4-1/2",5K,Horizontal 0 m b P 16"Conductor 2 u") " '-11 158'MDrkb/158'TVDrkb I N Q_ N O O Top of Intermediate 1 Liner @ 3,321'MD 2,200 psi applied at surface +10.2 ppg MW to 11-3/4"shoe Surface Casing J 0°P 4� =23.0 ppg EMW at shoe 11-3/4",60#L-80 BTC, 10.625"ID c is greater than 3,600'MD/3,309'TVDrkb yry l 11-3/4"Shoe LOT 14.7 ppg EMW 14.7 ppg LOT, 11/14/2010 icTop of Intermediate 1 Cement Squeeze Job 14 bbls cement O Intermediate 2 Tie Back - 7",26#L-80 BTC-M,6.276"ID 8,308'MD/5,150'TVDrkb .t- 4 rA Top of Intermediate 2 Liner @ 8,288'MD O O � f X.14 - z,s c� Intermediate 1 liner Window f- 9-5/8",40#L-80 Hydril 521,8.835"ID 5'10.51.1` Top of Window @ 8,438'MD - ---- Bottom of Window @ 8,455'MD 11-3/4"&9-5/8"x 7"Annulug 13.6 ppg FIT, 12/2/2010 Date.Pressure.Duration.Result 12/12/2010,2500psi,5 min, Passed 1/16/2011,2200psi.30min, Failed 1/16/2011.2200psi.30min, Failed 1/16/2011,2200psi,30min, Passed ■ ■ Frac String 4'/2"12.6#L-80 Hydril 521 11,916'MDrkb/6,145 TVDrkb • ►�� 1�� Intermediate 2 Liner 7",26#L-80 BTC,6.276"ID 4y ;!; 12,090'MD/6,174'TVDrkb Intermediate 2 Liner Cement Job 74 bbls cement 00 c 00 00 00 00 00 :q1 00 � 00 ,q0 00 00 00 � 00 � ~ 00 cC 00 00 Lateral Liner 4.44"12.6#L-80 Hydril 521 16,400'MDrkb/6,232'TVDrkb Date: Revision By: Comments PIONEER 01-11-2011 TWC Revised for Frac Completion 01-12-2011 TWC Corrected Numbering/Lettering NATR RESQ Rl`ESAI4CiG 1-18 2011 Alex Vaughan . As Built Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, January 20, 2011 4:21 PM To: 'Johnson, Vern' Cc: Hazzard, Vance; Hart, David; Williams, Theresa; Belanger, Ward; Cutting, Dan; Crumrine, Tim; Tirpack, Robert; Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: RE: ODSN-18 Operations (PTD 210-142) Vern, Thanks for the proposal outlined below. Your plan below is prudent and your forethought is appreciated. As I mentioned... you don't need regulatory approval to produce the well even with the possibility of the OA pressure climbing to a value higher than 1000 psi. If the pressure climbs above 1000 psi notify the commission as CO 597 requires. If bleed cycles are not manageable or the OA pressure climbs toward 2400 psi the well will have to be shut in at that point. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Johnson, Vern [mailto:Vern.Johnson@pxd.com] Sent: Thursday, January 20, 2011 2:45 PM To: Schwartz, Guy L (DOA) Cc: Hazzard, Vance; Hart, David; Williams,Theresa; Belanger, Ward; Cutting, Dan; Crumrine,Tim; Tirpack, Robert Subject: FW: ODSN-18 Operations (PTD 210-142) Guy, As discussed yesterday,we have pressure communication between the inner annulus(IA)and outer annulus (OA)on ODSN-18. Early pressure tests of the 7" casing tieback string and seal assembly,and pressure tests of the 4-1/2" production liner top did not indicate a problem, however after additional testing of the inner annulus after running the production tubing, a leak path has been identified between the inner and outer annulus.The outer annulus holds pressure, so it appears to be a one way leak. The most likely leak path is through the seals on the 7"tieback string. Plans for the well are to flow it back with gas lift in the next few days,then frac the well in late January/early February. After the frac,the well will be flowed back via gas lift until a workover,currently scheduled for early April. The workover will occur when the well has cleaned up from the frac where an ESP completion will see limited proppant flowback. Our intent for the rig workover would be twofold: 1)permanently repair this outer/inner annuli communication and 2) replace the frac completion with an ESP. The outer annulus has 10.2 ppg mud in it, so the hydrostatic pressure at the seal assembly should be sufficient to prevent pressure from transmitting to the outer annulus during gas lift operations. If the leak is not at the seal assembly as suspected, but in a shallow casing connection,or if gas is able to migrate past the seals into the OA, pressure in the OA could approach the lift gas header pressure ("'1400 psi). This would result in sustained outer annulus pressure which exceeds 1000 psi. Per Conservation Order No. 597, Rule 10,the OA pressure limit for notification to the AOGCC is 1000 psi. • 1/21/2011 Page 2 of 2 k To prevent bleeding too much freeze protect volume from the OA,to minimize the potential for gas migration into the OA,and to manage the potentially elevated OA pressures,Pioneer proposes operating the well as follows: - Continuously monitor the inner and outer annulus pressure with SCADA pressure sensors and Historian data logging system - Provide additional surveillance data of OA and IA pressures to the AOGCC in the form of a weekly email update - After kicking the well off with gas lift and allowing the well to stabilize to its thermal equilibrium, initially bleed the annulus pressure to 500 psi - If the outer annulus pressure approaches 1500 psi, shut the well in and bleed pressure such that the OA pressure does not exceed 1500 psi,otherwise,do not bleed pressure from the OA(burst pressure for 11-3/4" 60ppf L80 surface casing is 5380 psi,45%of burst is 2421 psi) If you need to discuss further, need additional documentation, or want to go through the details of the various pressure tests, please call. Vern Johnson Drilling Superintendent 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. 1/21/2011 • 1 ll C 'R N k �; Y. SEAN PARNELL, GOVERNOR t3 p_ 'dam '\ L ALAt SSA OIL AND GA17 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Alex Vaughan Operations Drilling Engineer Pioneer Natural Resources Alaska, Inc. ( 1 4-t 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-18 Sundry Number: 311-010 Dear Mr. Vaughan: 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, // Daniel T. Seamount, Jr. Chair DATED this2 day of January, 2011. Encl. u‘w .,\ ,,, Th, i 0' i I i STATE OF ALASKA /� JAN 1 2 2011 ALASKA OIL AND GAS CONSERVATION COMMISSION 1- APPLICATION FOR SUNDRY APPROVALS 7.1-.114.P >.,gar Cons.C d�Fission 20 AAC 25.280 33 1.Type of Request: Abandon 0 Plug for Redrill❑ Perforate New Pool 0 Repair Well 0 ChanglI11 Mrogram Q Suspend 0 Plug Perforations❑ Perforate❑ Pull Tubing 0 Time Extension 0 Operations Shutdown 0 Re-enter Susp.Well 0 Stimulate❑✓ . Alter Casing 0 Other: 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Pioneer Natural Resourcs Alaska, Inc. Development Q • Exploratory ❑ 210-142 ' 3.Address: 700 G Street, Suite 600 Stratigraphic 0 Service ❑ 6.API Number: Anchorage,AK 99501 50-703-20624-00-00 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 1=1 ODSN-18 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036 i Oooguruk-Nuiqsut 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): 16,689' 6229' 16,689' 6229' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3557' 11-3/4" 3600' 3309' 5830 psi 3180 psi Intermediate 5504' 9-5/8" 3320'-8824' 3124'-5329' 5750 psi 3090 psi Tie-back 8270' 7" 8308' 5149' 7240 psi 5410 psi Liner 3801' 7" 8289'-12,090' 5143'-6175' 7240 psi 5410 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A Packers and SSSV Type: N/A Packers and SSSV MD(ft)and ND(ft): N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑.r • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 1/14/2011 Oil ❑.r • Gas ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ D GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Delmonico, 343-2182 Printed Name Alex Vau han,343-2186 _Tale Operations Drilling Engineer SignaturPhone Date Prepared By:Kathy Campoamor,343-2183 1/12/2011 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 1! (�— °I v - Plug Integrity ❑ BOP Test 2( Mechanical Integrity Test 0 Location Clearance ❑ Other: 44 sy•lp ,-oh.5- ;IN or;0?fte...0 P%L.) ZOO` /41 Z 4.9/ 17 Subsequent Form Required: /, _ i/ / APPROVED BY Approved b , / COMMISSI N R THE COMMISSI N Date: 2 / ( � /•i.3.i, R�DM8 JAN 2'� �0���� Form 10-403 Revised 1/.t 0 ORIGINAL Submit in Duplicate �.1( yn ,. ,•j - f/ OIONEER NATURAL RESOURCES ALASKA Pioneer Natural Resources Alaska, Inc. 700 G Street,Suite 600 Anchorage,Alaska 99501 Tel:(907)277-2700 Fax:(907)343-2190 January 12, 2011 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite#100 Anchorage, AK 99501 „-tat/),aLlJ RE: Application for Sundry, Change to Approved Drilling Program prC Gp w,`( alo 11 be Permit to Drill #210-142 (ODSN-18) ("1_,�,,,;f�,�r�-"`• //J 11 Surface Location: 2935' FSL, 1177' FEL, Sec 11, T13N, R7E, UM X = 469821.18, Y = 6031051.27, ASP4 Pioneer Natural Resources, Alaska (PNRA) is submitting a proposal to forgo drilling ODSN- - 18L1(PTD#210-143), to complete ODSN-18 (PTD#210-142)with a 4-1/2"fracture stimulation . string. Due to geologic uncertainty in the Nuiqsut sands, operations to drill (ODSN-18L1, PTD#210- . 143) have been cancelled. ODSN-18 will be completed as a conventional 4-1/2" production liner . hung off in the 7" production casing. A 4-1/2"fracture stimulation upper completion will be stabbed into the liner top. Plan forward as outlined below will be to run the 4-1/2" lower completion with pre perforated - pups and a 4-1/2"fracture stimulation work string. ODSN-18 will be produced via gas lift until the ensuing fracture stimulation program can be executed. After the frac job the well will be produced through flow back equipment until an ESP is installed. A Sundry application to install an ESP will be submitted at that time. . Current Well Condition: • 6-1/8" ODSN-18 TD at 16,689' MD. • 7" shoe at 12,090' MD. Rid Activity: Run Upper and Lower Completion 1. Change one set of pipe rams to 4-1/2" and test BOPE as required. 2. RIH w/4-1/2" solid production liner w/ perforated pups from 150' inside the intermediate shoe to TD. 3. Set the liner hanger, release from the liner and set the liner top packer. Test 7"casing by • Alaska Oil & Gas Conservation Commission January 11, 2011 Page 2 of 3 DP annulus to 2200 psi for 5 min. 4. Displace the well over to 10 ppg Brine and POOH. • 5. RIH w/4 1/2"fracture stimulation string to top of 4-1/2" liner seal bore. • 6. Reverse circulate corrosion inhibited brine or diesel to freeze protect the well to -2000' TVD. 7. Sting 4 %2"fracture stimulation string into the 4-1/2" liner seal bore. 8. Pressure test 7" x 4-1g annulu§_to2209•.psi - chart and hold for 30 minute pressure. Send chart to ODE. 9. Gas lift ODSN-18 until fracture stimulation program can be executed. • Rig Activity: Fracture Stimulation 10. Fracture stimulate well 1,000,000 lbs of 16/20 Carboceramics Carbolite proppant pumped in 300,000 gallons of Schlumberger's YF125ST. The fluid volume includes a pad stage yet to be determined. The stimulation will target zones 1 and 5 of the Nuiqsut reservoir in a 10 stage treatment using dynamic diversion (Bioballs). The expected surface treating pressure at a planned pump rate of 40 barrels per minute is 6800 psi. Maximum proppant concentration is 5 ppa per gallon. The Schlumberger YF125ST is a water based guar gel system with borate crosslinker. The chemical make-up of the YF125ST includes: Seawater base-983.75 gpt Clay Stabilizer-2 gpt Polymer-6.25 gpt Surfactant-2 gpt Crosslinker-6 gpt Oxidative Breaker-0.05 ppt 11. Remove SSSV sleeve and install wireline retrievable SSSV 12. Install live gaslift valves 13. Flowback well with gaslift. Alaska Oil & Gas Conservation Commission January 11, 2011 Page 3 of 3 Please find attached information for your review: 1) Form 10-403 Application for Sundry 2) A summary of drilling operations 3) Schematic 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.iohnsona.Dxd.com 2) Geologic Data and Logs Paul Daggett, Operations Geologist (20 AAC 25.071) (907) 343-2134 paul.daggett a(�.pxd.com Sincerely, WIPP- Alex Vaughan Operations Drilling Engineer Attachments: Form 10-403 Supporting information cc: ODSN-18 Well File ODSN-18 Frac String Completion - Proposed Casing Item# Item MD(ft) TVD(ft) A 16"Conductor 158 158 Well Head: 9-5/8",5K,VetcoGray 1 B 11-3/4"60#L-80 Hydril 521, 10.772" ID 3,600 3,309 Tree: 4-1/2",5K,Horizontal C 9-5/8"40#L-80 Hydril 521, 8.835"ID* 8,824 5,329 D 7"26#L-80 BTC-M,6.276" ID,Tieback 8,308 ' 5,150 E 7"26#L-80 Hydril 511,6.276" ID** 12,090 6,175 CI F 4-1/2" 12.6#Hydril 521 3.958" ID 16,679 6,229 G 4-1/2" 12.6#Hydril 521 3.958"ID 11,940 6,206 O ` *Planned TOC @ 7764'MD --Ill **Planned TOC @ 10,603'MD O 1 VetcoGray Tubing Hanger 34 34 4-1/2"XXO Safety Valve Landing Nipple w/Wireline 2 Retreivable ScSSSV @ 2000'MD/2000'TVD 2,024 2,000 3 GLM#1 Brou-1A GLM 4-1/2"x 1" 2,231 2,200 ® 4 GLM#2 Brou-1A GLM 4-1/2"x 1" 4,381 3,800 5 GLM#3 Brou-1A GLM 4-1/2"x 1" 7,300 4,800 6 4 1/2")W Nipple, 3.725" ID Nogo 7,380 4,826 7 4-1/2" ROC Gauge and Carrier 11,850 6,133 O O 8 4-1/2"Seal Assembly w/Muleshoe 11,925 6,277 End of Assembly 11,940 6,281 9 WFT PBR Tie Back Sleeve 15ft 11,925 6,277 10 WFT"NTH"Liner Top Pkr 11,940 6,281 C ��(-/ 11 WFT"PHR"Rotating Hyd Set Liner Hanger 11,942 6,281 �� P' 12 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,300 6,201 A-IS 5t.eur _j O 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,500 6,222 v 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 12,650 6,225 1)rr 0 0 13a Resman Tracer Pup 12,800 6,219 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,000 6,211 (-E- 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,150 6,208 ,L�-(v J 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,550 6,218 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,750 6,231 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 13,950 6,234 � 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,150 6,236 \"J-II 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,300 6,239 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,450 6,240 13b Resman Tracer Pup 14,700 6,237 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,850 6,238 NO M 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,050 6,244 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,250 6,242 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 14,450 6,240 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,650 6,251 7 O ' 13c Resman Tracer Pup 15,800 6,244 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 15,850 6,241 O4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,050 6,231 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes) 16,250 6,230 14 Float Shoe(PLUGGED) 16,400 6,233 0I:1 Q End of Assembly 16,402 6,233 TD 16,689 6,229 b..: O 12 0 40 1c y 00 c 00 c 00 c 00 00 - "° 00 Ecn ° 00 E@ 00 N@ 00 00 1 a N ,. �` �� 00 E: 00 ': i_ 00 I I- 00 00 't'4" TD 16689'MDrkb/6229'TVDrkb ,.. Date: ' Revision By: Comments PIONEER 01-11-2011 TWC Revised for Frac Completion ODSN-18 Frac String 01-12-2011 TWC Corrected Numbering/Lettering Completion - NATURAL RESOURCES ALAS , Well Schematic Page 1 of 1 Schwartz, Guy L (DOA) From: Johnson, Vern [Vern.Johnson©pxd.com] Sent: Thursday, January 06, 2011 10:38 AM To: Schwartz, Guy L(DOA) Cc: Hazzard, Vance; Campoamor, Kathy; Vaughan, Alex; Delmonico, Joe; Tirpack, Robert; OoogurukDrillingSupervisor Subject: ODSN-18 (PTD 210-142)-another Open Hole Sidetrack Guy, As discussed this morning,we are preparing to sidetrack ODSN-18 again. This will be a very similar operation to the one performed early this week. While drilling 6-1/8" hole in the Nuiqsut sands, due to faults and complex geology the well was drilled out of section into unstable shale from 13510'to 14483' MD. It was decided to pull back with the drilling BHA and perform an open hole sidetrack at approximately 13250' MD. The wellbore below the sidetrack point from 13250'to 14483' MD (ODSN-18PB5)will not have a liner installed when the well is completed and it is expected that it will collapse over time and not contribute to the production of the well. It is not planned to pump cement in the open hole section. Let me know if you have any questions or require further information. Vern Johnson Drilling Superintendent 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. 1/6/2011 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, January 04, 2011 9:31 AM To: 'Johnson, Vern' Cc: Vaughan, Alex; Campoamor, Kathy; Tirpack, Robert; Crumrine, Tim; OoogurukDrillingSupervisor Subject: RE: ODSN-18 (PTD 210-142) Vern, Thanks for the update.. as before data from this PB section should be included in the final 407 report. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Johnson, Vern [mailto:Vern.Johnson@pxd.com] Sent: Monday, January 03, 2011 4:41 PM To: Schwartz, Guy L (DOA) Cc: Vaughan, Alex; Campoamor, Kathy; Tirpack, Robert; Crumrine,Tim; OoogurukDrillingSupervisor Subject: RE: ODSN-18 (PTD 210-142) Guy, As discussed this afternoon,we are preparing to sidetrack ODSN-18 again. This will be a very similar operation to the one performed late last week. While drilling 6-1/8" hole in the Nuiqsut sands, successive faults were encountered and the well was drilled out of section into unstable shale at+/- 13650' MD. It was decided to pull back with the drilling BHA and perform an open hole sidetrack at approximately 13375' MD. The wellbore below the sidetrack point from 13375'to 13832' MD (ODSN-18PB4)will not have a liner installed when the well is completed and it is expected that it will collapse over time and not contribute to the production of the well. It is not planned to pump cement in the open hole section. Let me know if you have any questions or require further information. Vern Johnson Drilling Superintendent 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. 1/4/2011 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, December 30, 2010 2:45 PM To: 'Johnson, Vern' Cc: Hazzard, Vance; Tirpack, Robert; Vaughan, Alex; Orange, Vernon G.; Reed, Tim Subject: RE: ODSN-18 (PTD 210-142) Vern, Thanks for the update... Hope the new sidetrack section goes better. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Johnson, Vern [mailto:VernJohnson@pxd.com] Sent: Thursday, December 30, 2010 2:37 PM To: Schwartz, Guy L (DOA) Cc: Hazzard, Vance; Tirpack, Robert; Vaughan, Alex; Orange, Vernon G.; Reed,Tim Subject: ODSN-18 (PTD 210-142) Guy, As discussed this morning,we are preparing to sidetrack ODSN-18. While drilling 6-1/8" hole in the Nuiqsut sands, successive faults were encountered and the well was drilled out of section into unstable shale from 13118' MD to TD at 13920' MD. It was decided to pull back with the drilling BHA and perform an open hole sidetrack at approximately 12850' MD. The wellbore below the sidetrack point from 12850'to 13920' MD(ODSN-18PB3)will not have a liner installed when the well is completed and it is expected that it will collapse over time and not contribute to the production of the well. It is not planned to pump cement in the open hole section. Let me know if you have any questions or require further information. Vern Johnson Drilling Superintendent 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. 12/30/2010 Page 1 of/ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, December 27, 2010 10:18 AM To: Seamount, Dan T(DOA); Foerster, Catherine P(DOA) Subject: RE: ODSN-18 (210-142)Stuck BHA Recovered I was notified yesterday that Pioneer successfully recovered the entire stuck BHA. From: Maunder, Thomas E (DOA) Sent: Wednesday, December 22, 2010 12:26 PM To: Seamount, Dan T(DOA); Foerster, Catherine P (DOA) Subject: FW: ODSN-18 Stuck BHA C's, Just a heads up on the present situation with this well; bad news they have stuck 2 nuclear sources, but good news they aren't far out of casing and they are just starting fishing. Pioneer still has a lot of options open to them and any decision to abandon the sources is still a ways off but I wanted to apprise you before the long weekend gets underway. If they are unable to recover the fish, potential plugging should be pretty straight forward. I will make sure I get the latest information tomorrow afternoon and pass it on. Tom From: Tirpack, Robert [mailto:Robert.Tirpack@pxd.com] Sent: Wednesday, December 22, 2010 9:24 AM To: Maunder, Thomas E (DOA) Cc: Hazzard, Vance Subject: N-18 Stuck BHA Tom, As discussed on the phone, we are currently stuck on ODSN-18. While drilling out from the 7"shoe with the 6- 1/8" RSS assembly, it was decided to take a survey. With the bit 77' from the shoe,we were unable to pick up off bottom. Immediately after,the top drive stalled out at 15k ftlbs (max for connections in the BHA)with full circulation. From approximately 11pm last night we have been jarring with no success. Our plan forward is to run in hole with a string shot and back off with in the BHA. Then we will run in hole with fishing jars and an accelerator to resume jarring. Pertinent Depths are: Back off 12,003' MD CTN Source 12,078' MD 7" Shoe 12,090' MD ALD Source 12,093' MD Bit 12,167' MD I will contact you with any changes or progress updates. Regards, Rob Tirpack Sr Drilling Eng 2/24/2011 Page 1 of 3 Schwartz, Guy L (DOA) From: Franks, James [James.Franks@pxd.com] Sent: Monday, December 20, 2010 1:45 PM To: Schwartz, Guy L(DOA) Cc: Hazzard, Vance; Tirpack, Robert; Johnson, Vern Subject: RE: ODSN-18 PTSD 2_10-142), Plug back Z ? Thanks Guy. We will definitely capture this as a 'plug back' hole section...we may be up to PB2 due to the earlier sidetrack... Our well path TD is still the same and we are still planning to drill the additional lateral. Here is the designed plug placement information: 1. RIH w/2-7/8" 6.4#1-80 BTC-M Tbg t/1,516'. • 49 jts+ Mule Shoe. 2. RIH w/2-7/8"work string on 4" DP t/13,400'. 3. Circulate and condition mud for cement job. • Pump hi-vis sweep S/S • Mud logger to check lag stks&time. /41, I 4. Pump the first stage of the balanced plug to place the plug from 13,400'to^'12,670' ✓ • Pump^'16.6 bbls of spacer ahead of the cement plug • Pump"'32 bbls of cement • Chase with"'6 bbls of 11+ppg spacer • Pump mud to displace—under displace by 1 or 2 bbls to ensure fluid does not come back up the drill string= 121 bbls 1,430 stks. • Allow fluids to balance • POH at 3 to 5 minutes per stand to^'12,670' 5. Circulate the hole clean to remove any excess cement and get ready for the second stage cement plug • Reciprocate the pipe while circulating above 12,670'—ensure you don't go down past 12,670' i. Mark the pipe with a nogo"'5'to 10' of above 12,670' once you have circulation established L 6. Once ready, pump the second stage of the cement plug from your position above 12,670'to 11,940, "'150' inside the 7" casing • Pump^'16 bbls of spacer ahead of the cement plug • Pump^'31.6 bbls of cement • Chase with^'6 bbls of 11+ppg spacer • Pump mud to displace—under displace by 1 or 2 bbls to ensure fluid does not come back up the drill string= 114.5 bbls 1,353 stks. • Allow fluids to balance • POH at 3 to 5 minutes per stand to 11,700' i. This should clear the cement if we have a gauge hole 7. Circulate the hole clean to remove any excess cement • Reciprocate the pipe while circulating above 11,700'—ensure you don't go down past the top of the last cement plug i. Mark the pipe with a nogo^ 5'to 10' of above once you have circulation established 12/20/2010 Page 2 of 3 8. Once the hole is clean, POH standing back the 4" DP and LD the 2-7/8"stinger. 9. Test BOPE. Again,this is the plan, but we have not completed it yet. The next step is to pick up our rotary steerable assembly, KO and try again. Thanks for your time. james James Franks Pioneer Natural Resources Alaska 907.343.2179 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, December 20, 2010 1:28 PM To: Franks, James Cc: Hazzard, Vance; Tirpack, Robert; Johnson, Vern Subject: RE: ODSN-18 (PTD 210-142), Plug back James, A sundry is not required .. although a fish was left in the wellbore is it relatively minor in length and no sources were lost. As long as you stay with in 500' of the permitted wellpath you are good to go. The Plug back section should be named BP1 and (API# - 70 ) Could you send me a quick summary of the cement plug placement. I assume you are still planning on the additional lateral?? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Franks,James [mailto:James.Franks@pxd.com] Sent: Monday, December 20, 2010 11:32 AM To: Schwartz, Guy L(DOA) Cc: Hazzard, Vance; Tirpack, Robert; Johnson, Vern Subject: ODSN-18 (PTD 210-142), Plug back Guy, Over this weekend while drilling ODSN-18 we drilled out of zone in to a shale section below the zone of interest and found it to be unstable between ^'13400' and 13499' (max depth drilled to date). We tried to reclaim the hole and continue on, but were not able to get past 13400'. We decided to come out of the hole, plug it back to the 7"casing shoe and start again due to the unstable geology. One thing we found when we got the BHA out of the hole was that we left the bit and part of our rotary steerable section (-8') in the unstable shale-there are no radioactive sources in the part of the tool left in the hole. This does not change our course of action for the remainder of the well. I don't believe that you need a Sundry for this operation, but please correct me if I am incorrect on this. We are currently pumping the 1st stage of our 2 stage cement plug. Please advise if you need more information. 12/20/2010 Page 3 of 3 • Take care, James James Franks Pioneer Natural Resources Alaska 907.343.2179 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. 12/20/2010 Page 1 of i Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, December 27, 2010 10:18 AM To: Seamount, Dan T(DOA); Foerster, Catherine P (DOA) Subject: RE: ODSN-18(210-142)Stuck BHA Recovered I was notified yesterday that Pioneer successfully recovered the entire stuck BHA. From: Maunder, Thomas E (DOA) Sent: Wednesday, December 22, 2010 12:26 PM To: Seamount, Dan T(DOA); Foerster, Catherine P (DOA) Subject: FW: ODSN-18 Stuck BHA C's, Just a heads up on the present situation with this well; bad news they have stuck 2 nuclear sources, but good news they aren't far out of casing and they are just starting fishing. Pioneer still has a lot of options open to them and any decision to abandon the sources is still a ways off but I wanted to apprise you before the long weekend gets underway. If they are unable to recover the fish, potential plugging should be pretty straight forward. I will make sure I get the latest information tomorrow afternoon and pass it on. Tom From: Tirpack, Robert [mailto:Robert.Tirpack@pxd.com] Sent: Wednesday, December 22, 2010 9:24 AM To: Maunder, Thomas E (DOA) Cc: Hazzard, Vance Subject: N-18 Stuck BHA Tom, As discussed on the phone, we are currently stuck on ODSN-18. While drilling out from the 7" shoe with the 6- 1/8" RSS assembly, it was decided to take a survey. With the bit 77'from the shoe,we were unable to pick up off bottom. Immediately after,the top drive stalled out at 15k ftlbs (max for connections in the BHA)with full circulation. From approximately 11pm last night we have been jarring with no success. Our plan forward is to run in hole with a string shot and back off with in the BHA. Then we will run in hole with fishing jars and an accelerator to resume jarring. Pertinent Depths are: Back off 12,003' MD CTN Source 12,078' MD 7" Shoe 12,090' MD ALD Source 12,093' MD Bit 12,167' MD I will contact you with any changes or progress updates. Regards, Rob Tirpack Sr Drilling Eng 12/27/2010 Page 1 ofXl Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, November 30, 2010 4:55 PM To: 'Johnson, Vern' Subject: RE: ODSN-18 (PTD 210-142) Vern, As we discussed the plan below is still within scope of the recent 403 Sundry submitted (Change of approved plan) . You will be exiting the 9 5/8" casing instead of below the shoe as planned but the kickoff is less than 500 feet different. The directional and casing programs will change minimally also. The 9 5/8" bridge plug will need a pressure test to 1500 psi per 20 AAC 25.112 (g) (2) Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Johnson, Vern [mailto:Vern.Johnson@pxd.com] Sent: Tuesday, November 30, 2010 4:46 PM To: Schwartz, Guy L(DOA) Cc: Hazzard, Vance; Vaughan, Alex; OoogurukDrillingSupervisor; Tirpack, Robert Subject: ODSN-18 (PTD 210-142) Guy, As discussed we have been unable to pull our 7" liner free. We are continuing to jar on the liner section, but it is unlikely we will be successful. If we don't get the liner out of the hole tonight,we plan on releasing from the fish, and pulling out of hole. We will then run in and set a bridge plug above the 7" liner stub in the 9-5/8" liner(-8475' MD). It is planned to set a whipstock on the bridge plug and mill out of 9-5/8"casing and redrill the section. The directional plan will be similar to the previous sidetrack plan,with the exception of a higher kick off point. Let me know if you need further information. Regards, Vern Johnson Drilling Superintendent 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 11/30/2010 • 1 :: rc f Y A\ \1_\ 1 SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Vern Johnson Drilling Superintendent , � ) Pioneer Natural Resources Alaska, Inc. °� ( V 700 G Street, Suite 600 c°71.10 -- I 7�� Anchorage, AK 99501 Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-18 Sundry Number: 310-390 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. 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. 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HAHNOHHUHHOHU HIHU:NII IMT MINI gl 3 1aa o G it i 1 1 S 3a a 0 0 _ n3 1 .. .v: 7:tt._:::, iiii ip:O 3 •^ I Dm 1 m.r u ?-0 I •,N SAI ' I ;�, i _`v -'4 I I 1 it- ...... ... I .. +� .-:. \. Win.. .,...,,.: I 1 r -y"..d.i' Iv. i %... 'J i i (6o1oy 1n 1 s6umn3 A6oloyIn C angelaJdJaluI 0 Pal-H1d34 )'5z1.1. 00Ell 091.1.1. 001.1.1. OcOl cools oseol 0090.• 09801. 00801 1 i j 3.8 rS a g. - n �_ . _ r l - - A . W - n m '-'\')L i A ,_ , . ! 3 ' I '1 " l'' MWS Ho dwoo 8yaTg53 I 1 -8 ;Wn 1 I I I W'° I 1 I / - - N. ` r� - J s 11 I I I I _ _ HI 1 I PrONEEk NATURAL RESOURCES November 24, 2010 ;DECEIVE State of Alaska NOV 2 4 2010 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #1008Si 8 1l Ga Cons.Commission Anchorage, AK 99501 Anchorage RE: Application for Sundry, Proposed Plug Back for Side Track of ODSN-18 due to 7" Liner Stuck Off Bottom. Permit to Drill #210-142 Surface Location: 2935' FSL, 1177' FEL, Sec 11, T13N, R7E, UM X = 469821.18, Y = 6031051.27, ASP4 Pioneer Natural Resources, Alaska (PNRA) is submitting a plug back for a sidetrack proposal for AOGCC's review and approval for the ODSN-18 well. On November 22, 2010 after making a drill pipe connection running 7" liner, the liner became immovable at a depth of 11,203' MD. Multiple attempts to rotate and or release the pipe and continue running in hole to the proposed shoe depth of 11,890' MD were made. Plan forward as indicated below, entails cementing the liner in place, cutting and pulling the ' liner, pumping a balanced cement kick off plug, and drilling a new 8-1/2" x 9-1/2" intermediate hole. A directional wellbore will parallel the abandoned hole and TD in the Nuiqsut interval at approximately 11,970'MD /6,167' TVD. The final wellbore will be > 32' MD (based on the distance between the error ellipses around the stuck liner and the new well path —center to center distance is —80' MD) from the original hole. This specific request is focused on abandonment of the 9-1/2" hole interval from the top of the liner at 9074' MD to TD of the original hole at 11,890' MD. The proposed plan is as follows: Current Well Condition 1. 9-1/2" hole drilled and landed into Nuiqsut formation, @ 11,890' MD • 2. 7" H521 liner stuck off bottom, shoe at 11,203' MD • 3. 5" drillpipe from surface to liner hanger 4. 10.5 ppg mud in the hole Rig Activity: Abandon Liner String, Sidetrack Well Alaska Oil & Gas Conservation Commission November 24, 2010 Page 2 of 2 1. Release from liner. 2. Pump cement to cover 500' min above 7" liner shoe. TOC - 10,703' MD. KI-1-r-"' 3. POOH with drill pipe and the liner running tool. 4.. Pick up a mechanical casing cutter and run in hole on 4" drillpipe crossed over to 5" drillpipe. 5. Cut 7" casing at -9,074' MD (250'from the intermediate liner shoe depth) -- 6. Pull out of hole with cutter. 7. Spear casing and pull 7" casing stub to surface 8. Pick up a -500' tubing stinger and run in hole. 9. Attempt to enter the 7" casing stub. 10. Spot a hi vis pill with top @ 9,174' MD. 11. Pull up and spot a balanced cement plug from 9,174' MD to 8,724' MD. 12. Pull out of hole and lay down cement stinger. 13. Pick up drilling BHA to kick off cement plug and redrill well to within -100 ft of previous f targets. Please find attached information for your review: 1) Form 10-403 Application for Sundry 2) Updated directional plan, ODSN-18 • 3) Schematic of the well conditions following the planned cement plug . 4) Schematic of the sidetrack conditions and plan forward • 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.iohnson(a�pxd.com 2) Geologic Data and Logs Paul Daggett, Operations Geologist (20 AAC 25.071) (907) 343-2134 paul.daggettepxd.com Sin =ely, L Vern Johnson Drilling Superintendent Attachments: Form 10-403 Supporting information cc: ODSN-18 Well File ( ` I (7 •RECE 1V 4'° STATE OF ALASKA II NOV 2 4 2010 - ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVA 3skn Oil "a Cons.CcniCons.Coneasion 20 AAC 25.280 Ar.ct:crage 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program ❑✓ Suspend E Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Pioneer Natural Resourcs Alaska, Inc. Development 0 Exploratory ❑ 210-142 - 3.Address: 700 G Street,Suite 600 Stratigraphic E Service ❑ 6.API Number: Anchorage,AK 99501 50-703-20624-00-00/ 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 E No 2ODSN-18 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036�SS03? Oooguruk-Nuiqsut 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): 11,890' 6172' 11,202' 6046' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3557' 11-3/4" 3600' 3309' 5830 psi 3180 psi Intermediate 5504' 9-5/8" 3320'-8824' 3124'-5329' 5750 psi 3090 psi Production 3229 7" 7974'- 11203' 5028'-6046' 7240 psi 5410 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A Packers and SSSV Type: N/A Packers and SSSV MD(ft)and TVD(ft): N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch E Exploratory ❑ Development Q Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 11/24/2010 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 i Joe Delmonico,343-2182 Printed Name .em Johnson,343-2111 Title Drilling Superintendent Signature / Phony Date Prepared By:Kathy Campoamor,343-2183 // 2 y/le 11/24/2010 ��-' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31( ' .39 0 Plug Integrity ❑ BOP Test 1E/ Mechanical Integrity Test ❑ Location Clearance ❑ Other: * / k _ r 0 it z& i.,J p_rD CZ!o- /`./ .►,pp 41 . —Al-t-ern 0 1.`S Q l``,c,4`"4" 4:,pP ra+►-9 / Zo A,4G Z.S: l LZ CZ) Subsequent Form Required: s.,....4.,,,,. .t- cy - x(07 i /I APPROVED BY ApprRBDMS p NOV ,Ii COMMISSIONER THE COMMISSION Date: go 71ei f O . < _,, RIGINAL. 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O W \ a o pI Ea neo d u 8. 8 I\ a ° Z —o o - o r z7,m a 8 d` Z \ i - U. ~i on o '' c ,. mg W -_ '' < -6, \•. : \ \\ 2J i2O n - . - o- tf) -w 0 _ _ __ 5.f � 1rFF f - —00 n � T ' IIIIIIIIiiiiiiimiimiIIIIIIIIIII IIIIIIIIIIIIIIIIimi 0 < °do 0 0 0 0 0 0 0 0 0 0 0 0 0 0 [L o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 10 0 0 0 (n 0 10 0 10 0 10 0 0 0 0 �� D .- ,- N N 5') 5') V V \n U) (D CD N- ^ C, (u!/u 0006)Lndea Iea!Ian anal Halliburton Company - HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk ND Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 (ST) Design: ODSN-18 PN11 ST wp02 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 ODSN-18-Slot ODS-18 Well Position +N/-S 0.0 ft Northing: 6,031,051.27 ft Latitude: 70°29'45.254 N +EI-W 0.0 ft Easting: 469,821.18 ft Longitude: 150°14'48.375 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft Wellbore ODSN-18 PN11 (ST) Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-18 PN11 STwp02 Audit Notes: I Version: Phase: PLAN Tie On Depth: 8,869.2 Vertical Section: Depth From(ND) +N/-S +E/-W Direction I (ft) (ft) (ft) (?) 42.7 0.0 0.0 290.79 11/23/2010 4:56:35PM Page 2 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 (ST) Design: ODSN-18 PN11 ST wp02 Plan Sections Measured Vertical ND Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (?) (?) (ft) ft (ft) (ft) (?/100ft) (?/100ft) (?/100ft) (?) 8,869.2 68.90 258.44 5,345.3 5,289.1 -890.7 -5,788.1 0.00 0.00 0.00 0.00 8,924.0 68.93 258.70 5,365.1 5,308.9 -900.8 -5,838.2 0.45 0.05 0.47 83.00 9,014.0 66.00 256.44 5,399.5 5,343.3 -918.7 -5,919.4 4.00 -3.26 -2.51 -145.00 9,427.2 74.26 266.53 5,540.2 5,484.0 -975.2 -6,302.9 3.04 2.00 2.44 50.77 9,436.2 74.26 266.53 5,542.6 5,486.4 -975.7 -6,311.5 0.00 0.00 0.00 0.00 11,654.4 80.00 340.00 6,112.1 6,055.9 134.1 -7,972.2 3.22 0.26 3.31 95.51 11,954.4 80.00 340.00 6,164.2 6,108.0 411.7 -8,073.2 0.00 0.00 0.00 0.00 11,971.7 80.00 340.00 6,167.2 6,111.0 427.7 -8,079.0 0.00 0.00 0.00 0.00 12,149.4 79.12 345.98 6,199.4 6,143.2 594.7 -8,130.1 3.35 -0.50 3.37 99.07 12,177.0 79.12 345.98 6,204.7 6,148.5 621.1 -8,136.7 0.00 0.00 0.00 0.00 12,510.5 86.25 336.22 6,247.2 6,191.0 933.4 -8,243.9 3.61 2.14 -2.93 -54.35 12,635.5 90.00 336.22 6,251.3 6,195.1 1,047.7 -8,294.2 3.00 3.00 0.00 0.00 12,778.4 94.00 336.22 6,246.3 6,190.1 1,178.3 -8,351.8 2.80 2.80 0.00 0.00 12,904.9 94.04 332.41 6,237.4 6,181.2 1,292.0 -8,406.5 3.00 0.03 -3.01 -89.31 13,788.2 94.04 332.41 6,175.3 6,119.1 2,072.9 -8,814.5 0.00 0.00 0.00 0.00 13,917.3 94.00 328.53 6,166.2 6,110.0 2,184.9 -8,878.0 3.00 -0.03 -3.01 -90.41 14,060.1 90.00 328.53 6,161.2 6,105.0 2,306.7 -8,952.5 2.80 -2.80 0.00 180.00 14,208.3 86.00 325.57 6,166.4 6,110.2 2,430.9 -9,033.1 3.36 -2.70 -2.00 -143.49 14,261.8 87.29 324.60 6,169.5 6,113.3 2,474.7 -9,063.6 3.00 2.40 -1.80 -36.75 14,302.2 87.29 324.60 6,171.4 6,115.2 2,507.6 -9,087.0 0.00 0.00 0.00 0.00 15,006.7 86.00 302.27 6,213.2 6,157.0 2,988.1 -9,594.4 3.17 -0.18 -3.17 -93.93 15,140.0 90.00 302.27 6,217.9 6,161.7 3,059.2 -9,707.0 3.00 3.00 0.00 0.00 15,282.9 94.00 300.84 6,212.9 6,156.7 3,133.9 -9,828.6 2.97 2.80 -1.00 -19.64 15,321.3 93.88 299.70 6,210.2 6,154.0 3,153.2 -9,861.7 3.00 -0.31 -2.99 -95.89 16,237.0 93.88 299.70 6,148.2 6,092.0 3,605.8 -10,655.3 0.00 0.00 0.00 0.00 16,266.8 94.00 300.58 6,146.2 6,090.0 3,620.8 -10,681.0 3.00 0.40 2.98 82.33 16,400.1 90.00 300.58 6,141.5 6,085.3 3,688.5 -10,795.7 3.00 -3.00 0.00 180.00 16,543.0 86.00 302.01 6,146.5 6,090.3 3,762.7 -10,917.7 2.97 -2.80 1.00 160.36 16,715.0 86.99 307.08 6,157.1 6,100.9 3,860.0 -11,059.0 3.00 0.58 2.95 79.08 17,842.0 86.99 307.08 6,216.2 6,160.0 4,538.7 -11,956.9 0.00 0.00 0.00 0.00 11/23/2010 4:56:35PM Page 3 COMPASS 2003.16 Build 428 Halliburton Company - HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 (ST) Design: ODSN-18 PN11 ST wp02 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 5,289.14 8,869.2 68.90 258.44 5,345.3 5,289.1 -890.7 -5,788.1 6,030,184.20 464,030.10 0.56 5,095.28 ' Tie-in Survey:8869.2'MD,5345.3'TVD 8,900.0 68.92 258.59 5,356.4 5,300.2 -896.4 -5,816.3 6,030,178.59 464,001.91 0.45 5,119.58 8,924.0 68.93 258.70 5,365.1 5,308.9 -900.8 -5,838.2 6,030,174.27 463,979.94 0.45 5,138.54 Start Dir 4°/100':8924'MD,5365.1'TVD:145°LT TF 9,000.0 66.45 256.80 5,393.9 5,337.7 -915.7 -5,906.9 6,030,159.65 463,911.19 4.00 5,197.48 9,014.0 66.00 256.44 5,399.5 5,343.3 -918.7 -5,919.4 6,030,156.73 463,898.71 4.00 5,208.08 Start Dir 3.04°/100':9014'MD,5399.5'TVD 9,032.9 66.36 256.93 5,407.2 5,351.0 -922.7 -5,936.2 6,030,152.81 463,881.84 3.04 5,222.43 Torok Shale 1 9,100.0 67.67 258.63 5,433.4 5,377.2 -935.7 -5,996.6 6,030,140.00 463,821.46 3.04 5,274.20 9,200.0 69.64 261.11 5,469.8 5,413.6 -952.1 -6,088.3 6,030,124.01 463,729.72 3.04 5,354.11 9,300.0 71.66 263.53 5,502.9 5,446.7 -964.7 -6,181.7 6,030,111.80 463,636.19 3.04 5,437.05 9,400.0 73.70 265.89 5,532.7 5,476.5 -973.5 -6,276.8 6,030,103.40 463,541.12 3.04 5,522.79 9,427.2 74.26 266.53 5,540.2 5,484.0 -975.2 -6,302.9 6,030,101.78 463,515.03 3.04 5,546.56 End Dir:9424.3'MD,5539.2'TVD 9,436.2 74.26 266.53 5,542.7 5,486.5 -975.7 -6,311.5 6,030,101.29 463,506.38 0.01 5,554.46 Start Dir 3.22°/100':9432'MD,5541.3'TVD 9,500.0 74.07 268.66 5,560.1 5,503.9 -978.3 -6,372.8 6,030,098.96 463,445.06 3.23 5,610.88 9,600.0 73.82 272.01 5,587.7 5,531.5 -977.7 -6,468.9 6,030,099.91 463,348.99 3.22 5,700.90 9,700.0 73.62 275.36 5,615.8 5,559.6 -971.6 -6,564.7 6,030,106.46 463,253.24 3.22 5,792.63 9,800.0 73.48 278.72 5,644.1 5,587.9 -959.8 -6,659.9 6,030,118.59 463,158.14 3.22 5,885.77 9,900.0 73.38 282.08 5,672.6 5,616.4 -942.5 -6,754.1 6,030,136.27 463,063.96 3.22 5,980.03 10,000.0 73.35 285.45 5,701.3 5,645.1 -919.7 -6,847.2 6,030,159.44 462,971.01 3.22 6,075.11 10,100.0 73.36 288.81 5,729.9 5,673.7 -891.5 -6,938.7 6,030,188.02 462,879.59 3.22 6,170.71 10,125.5 73.37 289.67 5,737.2 5,681.0 -883.5 -6,961.8 6,030,196.15 462,856.60 3.22 6,195.09 Violet4 Fault 10,188.4 73.42 291.79 5,755.2 5,699.0 -862.1 -7,018.2 6,030,217.74 462,800.24 3.22 6,255.45 Top HRZ 10,200.0 73.43 292.18 5,758.5 5,702.3 -858.0 -7,028.5 6,030,221.92 462,789.99 3.22 6,266.52 10,300.0 73.56 295.54 5,786.9 5,730.7 -819.2 -7,116.1 6,030,261.05 462,702.48 3.22 6,362.25 10,400.0 73.73 298.89 5,815.1 5,758.9 -775.3 -7,201.5 6,030,305.26 462,617.35 3.22 6,457.58 10,500.0 73.97 302.24 5,842.9 5,786.7 -726.5 -7,284.2 6,030,354.43 462,534.87 3.22 6,552.23 10,600.0 74.25 305.58 5,870.3 5,814.1 -672.8 -7,364.0 6,030,408.40 462,455.29 3.22 6,645.88 10,662.7 74.45 307.67 5,887.2 5,831.0 -636.8 -7,412.4 6,030,444.59 462,407.02 3.22 6,703.92 Base HRZ 10,700.0 74.58 308.91 5,897.2 5,841.0 -614.5 -7,440.6 6,030,467.00 462,378.87 3.22 6,738.24 10,800.0 74.96 312.23 5,923.4 5,867.2 -551.8 -7,513.9 6,030,530.03 462,305.86 3.22 6,829.01 10,900.0 75.39 315.53 5,949.0 5,892.8 -484.8 -7,583.6 6,030,597.31 462,236.47 3.22 6,917.92 10,972.9 75.74 317.94 5,967.2 5,911.0 -433.4 -7,631.9 6,030,648.90 462,188.31 3.22 6,981.39 1 Kalubik Mkr 11,000.0 75.87 318.83 5,973.8 5,917.6 -413.7 -7,649.4 6,030,668.62 462,170.94 3.22 7,004.68 11,100.0 76.39 322.11 5,997.8 5,941.6 -338.9 -7,711.2 6,030,743.73 462,109.46 3.22 7,089.01 11,200.0 76.96 325.37 6,020.9 5,964.7 -260.4 -7,768.7 6,030,822.40 462,052.24 3.22 7,170.66 11/23/2010 4:56:35PM Page 4 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN 11 (ST) Design: ODSN-18 PN11 ST wp02 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 5,971.00 11,228.2 77.12 326.29 6,027.2 5,971.0 -237.7 -7,784.2 6,030,845.20 462,036.90 3.22 7,193.15 Top Kup C 1 11,237.2 77.18 326.58 6,029.2 5,973.0 -230.4 -7,789.0 6,030,852.52 462,032.08 3.22 7,200.28 LCU 11,300.0 77.56 328.62 6,042.9 5,986.7 -178.6 -7,821.9 6,030,904.39 461,999.45 3.22 7,249.35 11,400.0 78.20 331.85 6,063.9 6,007.7 -93.8 -7,870.4 6,030,989.44 461,951.27 3.22 7,324.83 11,500.0 78.88 335.06 6,083.8 6,027.6 -6.1 -7,914.2 6,031,077.27 461,907.84 3.22 7,396.88 11,600.0 79.60 338.26 6,102.5 6,046.3 84.1 -7,953.1 6,031,167.62 461,869.30 3.22 7,465.27 11,654.4 80.00 340.00 6,112.1 6,055.9 134.1 -7,972.2 6,031,217.72 461,850.43 3.22 7,500.86 11,654.5 80.00 340.00 6,112.1 6,055.9 134.2 -7,972.2 6,031,217.83 461,850.40 0.00 7,500.93 End Dir:11654.5'MD,6112.1'TVD i 11,683.7 80.00 340.00 6,117.2 6,061.0 161.3 -7,982.0 6,031,244.91 461,840.66 0.00 7,519.73 BCU 11,700.0 80.00 340.00 6,120.0 6,063.8 176.3 -7,987.5 6,031,259.97 461,835.25 0.00 7,530.19 11,800.0 80.00 340.00 6,137.4 6,081.2 268.8 -8,021.2 6,031,352.64 461,801.95 0.00 7,594.52 11,900.0 80.00 340.00 6,154.8 6,098.6 361.4 -8,054.9 6,031,445.31 461,768.64 0.00 7,658.85 11,953.6 80.00 340.00 6,164.1 6,107.9 411.0 -8,072.9 6,031,495.00 461,750.79 0.00 7,693.34 18PN11 v9 ST Geo Poly-18PN11 v9 T1 11,954.4 80.00 340.00 6,164.2 6,108.0 411.7 -8,073.2 6,031,495.73 461,750.52 0.00 7,693.85 Top Nuiqsut 11,970.5 80.00 340.00 6,167.0 6,110.8 426.7 -8,078.6 6,031,510.67 461,745.15 0.00 7,704.22 7" 11,971.7 80.00 340.00 6,167.2 6,111.0 427.7 -8,079.0 6,031,511.74 461,744.77 0.00 7,704.97 11,971.8 80.00 340.00 6,167.2 6,111.0 427.8 -8,079.1 6,031,511.84 461,744.73 0.00 7,705.04 Start Dir 3.35°/100':11971.8'MD,6167.2'TVD 12,000.0 79.85 340.95 6,172.2 6,116.0 454.0 -8,088.3 6,031,538.05 461,735.56 3.36 7,723.00 12,100.0 79.35 344.32 6,190.2 6,134.0 547.9 -8,117.7 6,031,632.01 461,706.59 3.35 7,783.75 12,149.4 79.12 345.98 6,199.4 6,143.2 594.7 -8,130.1 6,031,678.95 461,694.35 3.35 7,812.02 12,149.5 79.12 345.98 6,199.5 6,143.3 594.9 -8,130.2 6,031,679.06 461,694.32 0.00 7,812.08 End Dir:12149.5'MD,6199.4'TVD 12,177.0 79.12 345.98 6,204.7 6,148.5 621.1 -8,136.7 6,031,705.32 461,687.88 0.00 7,827.51 12,177.1 79.12 345.98 6,204.7 6,148.5 621.1 -8,136.7 6,031,705.38 461,687.87 0.00 7,827.55 Start Dir 3.61°/100':12177.1'MD,6204.7'TVD 12,200.0 79.60 345.30 6,208.9 6,152.7 643.0 -8,142.3 6,031,727.21 461,682.37 3.62 7,840.51 12,300.0 81.72 342.34 6,225.1 6,168.9 737.7 -8,169.8 6,031,822.06 461,655.26 3.61 7,899.84 12,400.0 83.86 339.42 6,237.7 6,181.5 831.4 -8,202.3 6,031,915.90 461,623.15 3.61 7,963.48 12,500.0 86.02 336.52 6,246.5 6,190.3 923.7 -8,239.7 6,032,008.36 461,586.17 3.61 8,031.17 12,510.5 86.25 336.22 6,247.2 6,191.0 933.4 -8,243.9 6,032,018.00 461,582.00 3.61 8,038.52 18PN11 v9 T2 12,510.6 86.25 336.22 6,247.2 6,191.0 933.4 -8,243.9 6,032,018.06 461,581.97 0.00 8,038.57 I Start Dir 3°/100':12510.6'MD,6247.2'TVD 12,600.0 88.93 336.22 6,251.0 6,194.8 1,015.2 -8,279.9 6,032,099.93 461,546.29 3.00 8,101.25 12,635.5 90.00 336.22 6,251.3 6,195.1 1,047.7 -8,294.2 6,032,132.49 461,532.09 3.00 8,126.18 12,635.6 90.00 336.22 6,251.3 6,195.1 1,047.7 -8,294.3 6,032,132.56 461,532.06 0.00 8,126.23 Start Dir 2.8°/100':12635.6'MD,6251.37VD • 11/23/2010 4:56:35PM Page 5 COMPASS 2003.16 Build 428 • Halliburton Company • HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 (ST) Design: ODSN-18 PN11 ST wp02 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Veil Section (ft) (?) (7) (ft) ft (ft) (ft) (ft) (ft) 6,195.09 12,638.3 90.07 336.22 6,251.3 6,195.1 1,050.2 -8,295.3 6,032,135.00 461,531.00 2.80 8,128.10 18PN11 v9 T3 12,700.0 91.81 336.22 6,250.3 6,194.1 1,106.7 -8,320.2 6,032,191.58 461,506.34 2.80 8,171.42 12,778.4 94.00 336.22 6,246.3 6,190.1 1,178.3 -8,351.8 6,032,263.33 461,475.06 2.80 8,226.36 12,778.5 94.00 336.22 6,246.3 6,190.1 1,178.4 -8,351.9 6,032,263.43 461,475.02 0.00 8,226.44 Start Dir 3°/100':12778.5'MD,6246.3'TVD 12,781.3 94.00 336.13 6,246.1 6,189.9 1,180.9 -8,353.0 6,032,265.95 461,473.91 3.02 8,228.37 18PN11 v9 T4 12,800.0 94.01 335.57 6,244.8 6,188.6 1,198.0 -8,360.6 6,032,283.04 461,466.33 3.02 8,241.58 12,900.0 94.04 332.56 6,237.8 6,181.6 1,287.7 -8,404.2 6,032,372.91 461,423.08 3.00 8,314.19 12,904.9 94.04 332.41 6,237.4 6,181.2 1,292.0 -8,406.5 6,032,377.23 461,420.85 3.00 8,317.83 12,905.0 94.04 332.41 6,237.4 6,181.2 1,292.1 -8,406.6 6,032,377.34 461,420.79 0.00 8,317.92 End Dir:12905'MD,6237.4'TVD 13,000.0 94.04 332.41 6,230.7 6,174.5 1,376.1 -8,450.4 6,032,461.50 461,377.25 0.00 8,388.76 I 13,100.0 94.04 332.41 6,223.7 6,167.5 1,464.5 -8,496.6 6,032,550.08 461,331.42 0.00 8,463.32 13,200.0 94.04 332.41 6,216.7 6,160.5 1,552.9 -8,542.8 6,032,638.67 461,285.58 0.00 8,537.89 13,300.0 94.04 332.41 6,209.6 6,153.4 1,641.3 -8,589.0 6,032,727.26 461,239.75 0.00 8,612.45 13,306.5 94.04 332.41 6,209.2 6,153.0 1,647.1 -8,592.0 6,032,733.03 461,236.76 0.00 8,617.31 Black 1 Fault 13,400.0 94.04 332.41 6,202.6 6,146.4 1,729.7 -8,635.2 6,032,815.85 461,193.92 0.00 8,687.02 13,500.0 94.04 332.41 6,195.5 6,139.3 1,818.1 -8,681.4 6,032,904.43 461,148.08 0.00 8,761.58 13,600.0 94.04 332.41 6,188.5 6,132.3 1,906.5 -8,727.6 6,032,993.02 461,102.25 0.00 8,836.15 13,700.0 94.04 332.41 6,181.5 6,125.3 1,994.9 -8,773.8 6,033,081.61 461,056.42 0.00 8,910.71 13,788.2 94.04 332.41 6,175.3 6,119.1 2,072.9 -8,814.5 6,033,159.70 461,016.01 0.00 8,976.44 13,788.3 94.04 332.41 6,175.2 6,119.0 2,073.0 -8,814.6 6,033,159.83 461,015.95 0.00 8,976.55 Start Dir 3°/100':13788.3'MD,6175.3'TVD 13,800.0 94.03 332.06 6,174.4 6,118.2 2,083.3 -8,820.0 6,033,170.18 461,010.55 3.04 8,985.30 I 13,900.0 94.01 329.05 6,167.4 6,111.2 2,170.2 -8,869.1 6,033,257.22 460,961.87 3.00 9,061.97 l 13,917.3 94.00 328.53 6,166.2 6,110.0 2,184.9 -8,878.0 6,033,272.00 460,953.00 3.00 9,075.55 I 18PN11 v9 T5 13,917.4 94.00 328.53 6,166.2 6,110.0 2,185.0 -8,878.1 6,033,272.10 460,952.94 0.00 9,075.65 I Start Dir 2.8°/100':13917.4'MD,6166.2'TVD 1 14,000.0 91.68 328.53 6,162.1 6,105.9 2,255.4 -8,921.2 6,033,342.63 460,910.16 2.80 9,140.88 14,060.1 90.00 328.53 6,161.2 6,105.0 2,306.6 -8,952.5 6,033,394.00 460,879.00 2.80 9,188.40 18PN11 v9 T6 14,060.2 90.00 328.53 6,161.2 6,105.0 2,306.7 -8,952.6 6,033,394.09 460,878.95 1.05 9,188.48 Start Dir 3.36°/100':14060.2'MD,6161.2'TVD 14,100.0 88.92 327.73 6,161.6 6,105.4 2,340.5 -8,973.6 6,033,427.97 460,858.07 3.37 9,220.12 14,200.0 86.22 325.73 6,165.8 6,109.6 2,424.0 -9,028.4 6,033,511.70 460,803.62 3.36 9,300.99 14,202.8 86.15 325.67 6,166.0 6,109.8 2,426.4 -9,030.0 6,033,514.04 460,802.04 3.36 9,303.30 i 18PN11 v9 T7 14,208.3 86.00 325.57 6,166.4 6,110.2 2,430.9 -9,033.1 6,033,518.55 460,798.98 3.36 9,307.77 14,208.4 86.00 325.57 6,166.4 6,110.2 2,431.0 -9,033.1 6,033,518.64 460,798.92 0.00 9,307.87 I Start Dir 3°/100':14208.4'MD,6166.4'TVD 14,261.8 87.29 324.60 6,169.5 6,113.3 2,474.7 -9,063.6 6,033,562.50 460,768.57 3.01 9,351.94 11/23/2010 4:56:35PM Page 6 COMPASS 2003.16 Build 428 Halliburton Company • HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 (ST) Design: ODSN-18 PN11 ST wp02 Planned Survey I 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) 6,113.32 1 14,261.9 87.29 324.60 6,169.5 6,113.3 2,474.8 -9,063.7 6,033,562.55 460,768.53 0.00 9,351.99 End Dir:14261.9'MD,6169.5'TVD 14,300.0 87.29 324.60 6,171.3 6,115.1 2,505.8 -9,085.7 6,033,593.66 460,746.61 0.00 9,383.61 14,302.2 87.29 324.60 6,171.4 6,115.2 2,507.6 -9,087.0 6,033,595.48 460,745.33 0.00 9,385.45 14,302.3 87.29 324.60 6,171.4 6,115.2 2,507.7 -9,087.1 6,033,595.54 460,745.29 0.00 9,385.52 Start Dir 3.17°/100':14302.3'MD,6171.4'TVD 14,400.0 87.08 321.51 6,176.2 6,120.0 2,585.6 -9,145.7 6,033,673.75 460,686.97 3.17 9,468.02 14,500.0 86.88 318.34 6,181.5 6,125.3 2,662.0 -9,210.0 6,033,750.40 460,623.00 3.17 9,555.23 14,600.0 86.68 315.17 6,187.1 6,130.9 2,734.8 -9,278.4 6,033,823.39 460,554.91 3.17 9,644.98 14,700.0 86.50 312.00 6,193.1 6,136.9 2,803.6 -9,350.7 6,033,892.49 460,482.90 3.17 9,736.99 14,800.0 86.32 308.83 6,199.3 6,143.1 2,868.3 -9,426.7 6,033,957.49 460,407.19 3.17 9,830.98 14,900.0 86.16 305.66 6,205.9 6,149.7 2,928.6 -9,506.1 6,034,018.19 460,328.02 3.17 9,926.67 15,000.0 86.01 302.48 6,212.7 6,156.5 2,984.5 -9,588.7 6,034,074.40 460,245.63 3.17 10,023.75 15,006.7 86.00 302.27 6,213.2 6,157.0 2,988.1 -9,594.4 6,034,078.00 460,240.00 3.17 10,030.30 18PN11 v9 T8 15,006.8 86.00 302.27 6,213.2 6,157.0 2,988.2 -9,594.4 6,034,078.05 460,239.91 0.00 10,030.40 I Start Dir 3°/100':15006.8'MD,6213.2'TVD 15,100.0 88.80 302.27 6,217.4 6,161.2 3,037.9 -9,673.2 6,034,128.08 460,161.41 3.00 10,121.63 15,140.0 90.00 302.27 6,217.9 6,161.7 3,059.2 -9,707.0 6,034,149.58 460,127.66 3.00 10,160.85 15,140.1 90.00 302.27 6,217.9 6,161.7 3,059.3 -9,707.1 6,034,149.62 460,127.60 0.00 10,160.92 Start Dir 2.97°/100':15140.1'MD,6217.9'TVD 15,140.8 90.02 302.26 6,217.9 6,161.7 3,059.7 -9,707.7 6,034,150.00 460,127.00 2.98 10,161.61 18PN11 v9 T9 15,200.0 91.68 301.67 6,217.0 6,160.8 3,091.0 -9,757.9 6,034,181.53 460,076.93 2.98 10,219.68 15,282.8 94.00 300.84 6,212.9 6,156.7 3,133.9 -9,828.5 6,034,224.71 460,006.45 2.97 10,300.95 18PN11 v9 T10 15,282.9 94.00 300.84 6,212.9 6,156.7 3,133.9 -9,828.6 6,034,224.77 460,006.34 2.97 10,301.08 15,283.0 94.00 300.84 6,212.9 6,156.7 3,134.0 -9,828.7 6,034,224.83 460,006.25 0.00 10,301.19 Start Dir 3°/100':15283'MD,6212.9'TVD 15,300.0 93.95 300.33 6,211.7 6,155.5 3,142.6 -9,843.3 6,034,233.51 459,991.68 3.02 10,317.90 15,321.3 93.88 299.70 6,210.2 6,154.0 3,153.2 -9,861.7 6,034,244.19 459,973.37 3.00 10,338.82 15,321.4 93.88 299.70 6,210.2 6,154.0 3,153.3 -9,861.8 6,034,244.27 459,973.24 0.00 10,338.97 End Dir:15321.4'MD,6210.2'TVD 15,400.0 93.88 299.70 6,204.9 6,148.7 3,192.2 -9,929.9 6,034,283.39 459,905.29 0.00 10,416.45 15,500.0 93.88 299.70 6,198.1 6,141.9 3,241.6 -10,016.6 6,034,333.16 459,818.83 0.00 10,515.01 15,600.0 93.88 299.70 6,191.4 6,135.2 3,291.0 -10,103.3 6,034,382.93 459,732.37 0.00 10,613.58 15,700.0 93.88 299.70 6,184.6 6,128.4 3,340.4 -10,189.9 6,034,432.70 459,645.91 0.00 10,712.15 I 15,800.0 93.88 299.70 6,177.8 6,121.6 3,389.9 -10,276.6 6,034,482.47 459,559.46 0.00 10,810.71 15,900.0 93.88 299.70 6,171.1 6,114.9 3,439.3 -10,363.3 6,034,532.25 459,473.00 0.00 10,909.28 16,000.0 93.88 299.70 6,164.3 6,108.1 3,488.7 -10,449.9 6,034,582.02 459,386.54 0.00 11,007.85 16,100.0 93.88 299.70 6,157.5 6,101.3 3,538.1 -10,536.6 6,034,631.79 459,300.08 0.00 11,106.41 16,200.0 93.88 299.70 6,150.8 6,094.6 3,587.6 -10,623.3 6,034,681.56 459,213.62 0.00 11,204.98 16,237.0 93.88 299.70 6,148.2 6,092.0 3,605.8 -10,655.3 6,034,699.98 459,181.63 0.00 11,241.45 16,237.1 93.88 299.70 6,148.2 6,092.0 3,605.9 -10,655.4 6,034,700.03 459,181.55 0.00 11,241.55 Start Dir 3°/100':16237.1'MD,6148.2'TVD 11/23/2010 4:56:35PM Page 7 COMPASS 2003.16 Build 428 Halliburton Company • HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk ND Reference: 42.7'+13.5(copy)@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 (ST) Design: ODSN-18 PN11 ST wp02 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 6,090.00 16,266.8 94.00 300.58 6,146.2 6,090.0 3,620.8 -10,681.0 6,034,715.00 459,156.00 3.01 11,270.77 18PN11 v9 T11 16,300.0 93.00 300.58 6,144.2 6,088.0 3,637.6 -10,709.6 6,034,731.98 459,127.53 3.00 11,303.44 16,399.7 90.01 300.58 6,141.5 6,085.3 3,688.3 -10,795.3 6,034,783.00 459,041.99 3.00 11,401.60 18PN11 v9 T12 1 16,400.0 90.00 300.58 6,141.5 6,085.3 3,688.5 -10,795.6 6,034,783.18 459,041.70 3.00 11,401.94 16,400.1 90.00 300.58 6,141.5 6,085.3 3,688.5 -10,795.7 6,034,783.24 459,041.60 3.00 11,402.05 16,400.2 90.00 300.58 6,141.5 6,085.3 3,688.6 -10,795.8 6,034,783.28 459,041.53 0.00 11,402.13 Start Dir 2.97°/100':16400.2'MD,6141.5'ND 16,500.0 87.20 301.58 6,144.0 6,087.8 3,740.1 -10,881.2 6,034,835.13 458,956.31 2.98 11,500.29 16,543.0 86.00 302.01 6,146.5 6,090.3 3,762.7 -10,917.7 6,034,857.88 458,919.95 2.97 11,542.39 18PN11 v9 T13 16,543.1 86.00 302.01 6,146.5 6,090.3 3,762.8 -10,917.8 6,034,857.94 458,919.84 0.09 11,542.52 Start Dir 3°/100':16543.1'MD,6146.5'TVD 16,600.0 86.33 303.69 6,150.3 6,094.1 3,793.6 -10,965.5 6,034,888.93 458,872.28 3.01 11,598.03 16,700.0 86.90 306.64 6,156.3 6,100.1 3,851.1 -11,047.1 6,034,946.75 458,790.93 3.00 11,694.72 16,715.0 86.99 307.08 6,157.1 6,100.9 3,860.0 -11,059.0 6,034,955.76 458,779.01 3.00 11,709.07 16,715.1 86.99 307.08 6,157.1 6,100.9 3,860.1 -11,059.2 6,034,955.84 458,778.90 0.00 11,709.21 1 End Dir:16715.1'MD,6157.1'ND 16,800.0 86.99 307.08 6,161.5 6,105.3 3,911.2 -11,126.8 6,035,007.24 458,711.48 0.00 11,790.58 1 16,900.0 86.99 307.08 6,166.8 6,110.6 3,971.4 -11,206.5 6,035,067.77 458,632.07 0.00 11,886.43 17,000.0 86.99 307.08 6,172.0 6,115.8 4,031.7 -11,286.1 6,035,128.30 458,552.66 0.00 11,982.28 1 17,100.0 86.99 307.08 6,177.3 6,121.1 4,091.9 -11,365.8 6,035,188.84 458,473.25 0.00 12,078.13 17,200.0 86.99 307.08 6,182.5 6,126.3 4,152.1 -11,445.4 6,035,249.37 458,393.84 0.00 12,173.98 17,300.0 86.99 307.08 6,187.8 6,131.6 4,212.3 -11,525.1 6,035,309.90 458,314.42 0.00 12,269.83 17,400.0 86.99 307.08 6,193.0 6,136.8 4,272.5 -11,604.8 6,035,370.43 458,235.01 0.00 12,365.68 17,500.0 86.99 307.08 6,198.3 6,142.1 4,332.7 -11,684.4 6,035,430.97 458,155.60 0.00 12,461.52 17,600.0 86.99 307.08 6,203.5 6,147.3 4,393.0 -11,764.1 6,035,491.50 458,076.19 0.00 12,557.37 17,700.0 86.99 307.08 6,208.7 6,152.5 4,453.2 -11,843.8 6,035,552.03 457,996.78 0.00 12,653.22 17,800.0 86.99 307.08 6,214.0 6,157.8 4,513.4 -11,923.4 6,035,612.57 457,917.37 0.00 12,749.07 17,842.0 86.99 307.08 6,216.2 6,160.0 4,538.7 -11,956.9 6,035,637.99 457,884.01 0.00 12,789.33 Total Depth:17842.0'MD,6216.2'ND-41/2"-18PN11 v9 T14 11/23/2010 4:56:35PM Page 8 COMPASS 2003.16 Build 428 Halliburton Company • HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 (ST) Design: ODSN-18 PN11 ST wp02 Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +N/-S +EI-W Northing Easting -Shape (?) (?) (ft) (ft) (ft) (ft) (ft) Black 1 Fault 0.00 0.00 6,151.7 1,898.0 -8,103.0 6,032,982.00 461,726.81 -plan misses by 552.7ft at 13306.5ft MD(6209.2 TVD, 1647.1 N,-8592.0 E) -Polygon Point 1 6,151.7 1,898.0 -8,103.0 6,032,982.00 461,726.81 Point 2 6,151.7 2,556.2 -8,564.7 6,033,642.00 461,267.83 Point 3 6,151.7 3,213.2 -9,324.5 6,034,302.02 460,510.78 Point 4 6,151.7 3,432.1 -9,598.8 6,034,522.00 460,237.40 Point 5 6,151.7 2,775.6 -8,727.7 6,033,862.04 461,105.74 Point 6 6,151.7 2,337.2 -8,304.1 6,033,421.97 461,527.51 Point7 6,151.7 1,898.4 -8,002.1 6,032,981.99 461,827.70 Point8 6,151.7 1,239.6 -7,692.3 6,032,322.00 462,134.79 Point9 6,151.7 581.1 -7,295.8 6,031,661.97 462,528.58 Point 10 6,151.7 142.5 -6,937.6 6,031,221.96 462,884.96 Point 11 6,151.7 -1,170.7 -5,237.1 6,029,902.00 464,579.94 Point 12 6,151.7 -2,923.2 -3,222.3 6,028,141.51 466,587.41 Point 13 6,151.7 -4,019.7 -2,314.2 6,027,041.45 467,490.96 Point 14 6,151.7 -4,458.6 -2,053.0 6,026,601.53 467,750.34 Point 15 6,151.7 -5,557.8 -1,826.2 6,025,501.53 467,972.66 Point 16 6,151.7 -5,997.1 -1,631.6 6,025,061.49 468,165.45 Point 17 6,151.7 -6,435.9 -1,330.1 6,024,621.52 468,465.14 Point 18 6,151.7 -7,312.9 -569.9 6,023,741.53 469,221.70 Point 19 6,151.7 -8,407.7 740.4 6,022,641.53 470,527.41 Point 20 6,151.7 -10,600.3 2,746.1 6,020,441.02 472,523.99 Point21 6,151.7 -11,916.2 3,795.4 6,019,121.01 473,567.83 Point22 6,151.7 -12,354.7 4,190.2 6,018,680.95 473,960.81 Point23 6,151.7 -12,573.9 4,377.1 6,018,461.02 474,146.80 Point 24 6,151.7 -13,231.9 4,889.8 6,017,801.01 474,656.77 Point 25 6,151.7 -14,109.3 5,565.0 6,016,920.96 475,328.34 Point 26 6,151.7 -14,547.5 6,014.0 6,016,480.99 475,775.51 Point 27 6,151.7 -14,766.4 6,281.0 6,016,261.03 476,041.59 Point 28 6,151.7 -15,204.8 6,692.5 6,015,821.01 476,451.27 Point 29 6,151.7 -15,861.4 7,566.1 6,015,160.93 477,322.11 Point 30 6,151.7 -16,519.2 8,245.8 6,014,500.44 477,999.06 Point 31 6,151.7 -16,958.0 8,554.7 6,014,060.44 478,306.15 Point 32 6,151.7 -17,397.4 8,699.0 6,013,620.50 478,448.65 Point 33 6,151.7 -17,836.8 8,855.2 6,013,180.51 478,603.05 Point 34 6,151.7 -18,495.4 9,232.4 6,012,520.45 478,977.53 Point 35 6,151.7 -17,837.0 8,825.0 6,013,180.44 478,572.85 Point 36 6,151.7 -17,178.1 8,530.3 6,013,840.46 478,280.85 Point 37 6,151.7 -16,739.3 8,221.2 6,014,280.47 477,973.57 Point 38 6,151.7 -15,862.0 7,395.0 6,015,161.03 477,151.02 Point 39 6,151.7 -15,205.0 6,661.4 6,015,820.93 476,420.17 Point40 6,151.7 -14,328.7 5,704.8 6,016,701.02 475,467.23 Point 41 6,151.7 -13,671.0 5,121.9 6,017,361.01 474,887.06 Point42 6,151.7 -12,793.5 4,495.7 6,018,240.96 474,264.49 Point43 6,151.7 -11,477.7 3,427.6 6,019,560.95 473,201.85 Point44 6,151.7 -10,819.7 2,915.3 6,020,220.96 472,692.28 Point45 6,151.7 -10,381.4 2,473.4 6,020,661.01 472,252.21 Point46 6,151.7 -9,943.7 1,910.9 6,021,100.94 471,691.55 Point47 6,151.7 -9,724.0 1,688.9 6,021,321.52 471,470.46 Point 48 6,151.7 -9,504.8 1,488.7 6,021,541.51 471,271.17 Point 49 6,151.7 -8,627.4 835.0 6,022,421.47 470,621.11 Point 50 6,151.7 -8,189.4 326.2 6,022,861.48 470,114.14 Point 51 6,151.7 -7,532.7 -509.2 6,023,521.50 469,281.50 Point 52 6,151.7 -6,875.1 -1,109.7 6,024,181.47 468,683.73 Point 53 6,151.7 -6,217.0 -1,604.5 6,024,841.51 468,191.66 Point 54 6,151.7 -5,777.9 -1,844.6 6,025,281.53 467,953.37 11/23/2010 4:56:35PM Page 9 COMPASS 2003.16 Build 42B • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 (ST) Design: ODSN-18 PN11 ST wp02 Point 55 6,151.7 -5,338.4 -1,962.7 6,025,721.46 467,837.06 Point 56 6,151.7 -4,678.7 -2,071.4 6,026,381.53 467,731.05 Point 57 6,151.7 -4,239.6 -2,302.0 6,026,821.52 467,502.26 Point 58 6,151.7 -3,800.9 -2,624.6 6,027,261.48 467,181.48 Point 59 6,151.7 -2,923.9 -3,400.9 6,028,141.54 466,408.82 Point 60 6,151.7 -2,266.9 -4,141.5 6,028,801.47 465,670.97 Point 61 6,151.7 -1,609.1 -4,835.7 6,029,462.02 464,979.52 Point 62 6,151.7 -952.4 -5,649.1 6,030,121.95 464,168.87 Point 63 6,151.7 -296.3 -6,634.9 6,030,781.98 463,185.84 Point64 6,151.7 141.8 -7,124.7 6,031,222.02 462,697.87 Point65 6,151.7 580.5 -7,454.8 6,031,662.01 462,369.59 Point66 6,151.7 1,458.7 -7,921.5 6,032,542.01 461,906.51 Point67 6,151.7 1,898.0 -8,103.0 6,032,982.00 461,726.81 18PN11 v9 ST Geo Poly 0.00 0.00 6,164.2 438.3 -7,997.8 6,031,522.00 461,826.00 -plan misses by 79.9ft at 11953.6ft MD(6164.1 TVD,411.0 N,-8072.9 E) -Polygon Point 1 6,164.2 298.2 -8,118.5 6,031,382.41 461,704.74 Point2 6,164.2 378.4 -8,163.6 6,031,462.78 461,659.97 Point 3 6,164.2 394.3 -8,169.7 6,031,478.70 461,653.94 Point4 6,164.2 598.2 -8,226.9 6,031,682.81 461,597.57 Point 5 6,164.2 880.2 -8,338.4 6,031,965.23 461,487.23 Point 6 6,164.2 1,061.2 -8,421.8 6,032,146.55 461,404.57 Point 7 6,164.2 1,236.5 -8,511.5 6,032,322.20 461,315.60 Point 8 6,164.2 1,582.8 -8,699.7 6,032,669.22 461,128.82 Point 9 6,164.2 1,933.3 -8,890.3 6,033,020.46 460,939.67 Point 10 6,164.2 2,111.7 -8,996.6 6,033,199.27 460,834.10 Point 11 6,164.2 2,340.9 -9,149.1 6,033,429.07 460,682.55 Point 12 6,164.2 2,420.5 -9,208.4 6,033,508.90 460,623.58 Point 13 6,164.2 2,679.4 -9,461.4 6,033,768.80 460,371.66 Point 14 6,164.2 2,838.4 -9,688.0 6,033,928.70 460,145.73 Point 15 6,164.2 2,977.4 -9,921.2 6,034,068.63 459,913.12 Point 16 6,164.2 3,079.6 -10,108.0 6,034,171.58 459,726.75 Point 17 6,164.2 3,271.0 -10,458.2 6,034,364.38 459,377.37 Point 18 6,164.2 3,432.3 -10,753.4 6,034,526.86 459,082.85 Point 19 6,164.2 3,514.1 -10,897.8 6,034,609.24 458,938.80 Point20 6,164.2 3,685.4 -11,169.1 6,034,781.62 458,668.23 Point 21 6,164.2 4,214.7 -11,897.5 6,035,313.82 457,942.06 Point 22 6,164.2 4,356.8 -12,093.2 6,035,456.70 457,746.95 Point 23 6,164.2 4,390.7 -12,140.0 6,035,490.78 457,700.30 Point 24 6,164.2 4,415.5 -12,174.0 6,035,515.72 457,666.40 Point 25 6,164.2 4,822.3 11,869.1 6,035,921.24 457,972.92 Point 26 6,164.2 4,796.3 -11,836.0 6,035,895.11 458,005.91 Point 27 6,164.2 4,760.6 -11,790.6 6,035,859.22 458,051.16 1 Point28 6,164.2 4,611.0 -11,600.5 6,035,708.87 458,240.63 Point 29 6,164.2 4,064.7 -10,905.6 6,035,159.81 458,933.24 Point 30 6,164.2 3,956.7 -10,749.1 6,035,051.18 459,089.28 Point 31 6,164.2 3,836.2 -10,554.9 6,034,929.91 459,282.97 Point 32 6,164.2 3,702.0 -10,329.3 6,034,794.81 459,508.00 Point 33 6,164.2 3,498.0 -9,986.1 6,034,589.44 459,850.34 Point 34 6,164.2 3,343.7 -9,726.6 6,034,434.10 460,109.18 Point 35 6,164.2 3,231.4 -9,551.9 6,034,321.10 460,283.41 Point 36 6,164.2 3,040.1 -9,289.3 6,034,128.76 460,545.20 Point 37 6,164.2 2,713.1 -8,986.5 6,033,800.57 460,846.64 Point 38 6,164.2 2,542.9 -8,871.1 6,033,629.92 460,961.34 Point 39 6,164.2 2,355.5 -8,758.8 6,033,442.08 461,072.87 Point 40 6,164.2 2,158.4 -8,652.5 6,033,244.57 461,178.35 Point 41 6,164.2 1,812.1 -8,478.8 6,032,897.60 461,350.63 Point 42 6,164.2 1,455.5 -8,299.7 6,032,540.31 461,528.26 Point43 6,164.2 1,244.4 -8,203.2 6,032,328.85 461,623.89 Point44 6,164.2 997.8 -8,099.1 6,032,081.85 461,726.98 Point45 6,164.2 679.9 -8,003.1 6,031,763.60 461,821.68 Point46 6,164.2 502.1 -7,950.4 6,031,585.60 461,873.65 Point47 6,164.2 478.4 -7,941.3 6,031,561.87 461,882.66 11/23/2010 4:56:35PM Page 10 COMPASS 2003.16 Build 428 Halliburton Company ' HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 (ST) Design: ODSN-18 PN11 ST wp02 Point48 6,164.2 462.4 -7,935.8 6,031,545.85 461,888.09 Point49 6,164.2 411.6 -7,918.2 6,031,494.98 461,905.48 18PN11 v9T14 0.00 0.00 6,216.2 4,538.7 -11,956.9 6,035,638.00 457,884.00 -plan hits target -Point 18PN11 v9 T5 0.00 0.00 6,166.2 2,184.9 -8,878.0 6,033,272.00 460,953.00 -plan hits target -Point 18PN11 v9 T13 0.00 0.00 6,146.2 3,762.8 -10,917.6 6,034,858.00 458,920.00 -plan hits target -Point 18PN11 v9 T2 0.00 0.00 6,247.2 933.4 -8,243.9 6,032,018.00 461,582.00 -plan hits target -Point 18PN11 v9 T8 0.00 0.00 6,213.2 2,988.1 -9,594.4 6,034,078.00 460,240.00 -plan hits target -Point 18PN11 v9 T1 0.00 0.00 6,164.2 438.3 -7,997.8 6,031,522.00 461,826.00 -plan misses by 79.9ft at 11953.6ft MD(6164.1 TVD,411.0 N,-8072.9 E) -Point I 18PN11 v9 T9 0.00 0.00 6,218.2 3,059.7 -9,707.7 6,034,150.00 460,127.00 -plan hits target -Point 18PN11 v9 T6 0.00 0.00 6,161.2 2,306.6 -8,952.5 6,033,394.00 460,879.00 -plan hits target -Point 18PN11 v9 T10 0.00 0.00 6,213.2 3,133.2 -9,829.0 6,034,224.00 460,006.00 -plan hits target -Point 18PN11 v9 T7 0.00 0.00 6,166.2 2,426.3 -9,030.0 6,033,514.00 460,802.00 -plan hits target -Point 18PN11 v9T12 0.00 0.00 6,141.2 3,688.3 -10,795.3 6,034,783.00 459,042.00 -plan hits target -Point 18PN11 v9 T3 0.00 0.00 6,251.2 1,050.2 -8,295.3 6,032,135.00 461,531.00 -plan hits target -Point 18PN11 v9T11 0.00 0.00 6,146.2 3,620.8 -10,681.0 6,034,715.00 459,156.00 -plan hits target -Point 18PN11 v9 T4 0.00 0.00 6,246.2 1,181.0 -8,352.9 6,032,266.00 461,474.00 -plan hits target -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 3,566.4 3,288.0 11 3/4" 11.750 13.500 8,824.0 5,329.2 9 5/8" 9.625 11.750 8.500 11,970.5 6,167.0 7" 7.000 17,842.0 6,216.2 4 1/2" 4.500 6.125 11/23/2010 4:56:35PM Page 11 COMPASS 2003.16 Build 42B Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'(copy)@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 (ST) Design: ODSN-18 PN11 ST wp02 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (?) (?) 11,228.2 6,027.2 Top Kup C 0.00 11,683.7 6,117.2 BCU 0.00 1,679.1 1,666.2 Base of Permafrost 0.00 10,125.5 5,737.2 Violet4 Fault 0.00 3,477.2 3,230.2 Hue2 tuff 0.00 5,687.7 4,270.2 Brook 2B 0.00 9,032.9 5,407.2 Torok Shale 1 0.00 I 11,237.2 6,029.2 LCU 0.00 2,319.6 2,286.2 Top West Sak 0.00 10,662.7 5,887.2 Base HRZ 0.00 11,954.4 6,164.2 Top Nuiqsut 0.00 10,972.9 5,967.2 Kalubik Mkr 0.00 10,188.4 5,755.2 Top HRZ 0.00 7,849.0 4,988.2 Top Torok Sand 0.00 8,564.4 5,239.2 Base Torok Sand 0.00 I 3,081.5 2,946.2 Tuffaceous Shales 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 8,869.2 5,345.3 -890.7 -5,788.1 Tie-in Survey:8869.2'MD,5345.3'TVD 8,924.0 5,365.1 -900.8 -5,838.2 Start Dir 4°/100':8924'MD,5365.1'TVD: 145°LT TF 9,014.0 5,399.5 -918.7 -5,919.4 Start Dir 3.04°/100':9014'MD,5399.5'TVD 9,427.2 5,540.2 -975.2 -6,302.9 End Dir:9424.3'MD,5539.2'TVD 9,436.2 5,542.7 -975.7 -6,311.5 Start Dir 3.22°/100':9432'MD,5541.3'TVD 11,654.5 6,112.1 134.2 -7,972.2 End Dir: 11654.5'MD,6112.1'TVD 11,971.8 6,167.2 427.8 -8,079.1 Start Dir 3.35°/100': 11971.8'MD,6167.2'TVD 12,149.5 6,199.5 594.9 -8,130.2 End Dir: 12149.5'MD,6199.4'TVD 12,177.1 6,204.7 621.1 -8,136.7 Start Dir 3.61°/100': 12177.1'MD,6204.7'TVD 12,510.6 6,247.2 933.4 -8,243.9 Start Dir 3°/100': 12510.6'MD,6247.2'TVD 12,635.6 6,251.3 1,047.7 -8,294.3 Start Dir 2.8°/100':12635.6'MD,6251.3'TVD 12,778.5 6,246.3 1,178.4 -8,351.9 Start Dir 3°/100': 12778.5'MD,6246.3'TVD 12,905.0 6,237.4 1,292.1 -8,406.6 End Dir: 12905'MD,6237.4'TVD 13,788.3 6,175.2 2,073.0 -8,814.6 Start Dir 3°/100':13788.3'MD,6175.3'TVD 13,917.4 6,166.2 2,185.0 -8,878.1 Start Dir 2.8°/100':13917.4'MD,6166.2'TVD 14,060.2 6,161.2 2,306.7 -8,952.6 Start Dir 3.36°/100': 14060.2'MD,6161.2'TVD 14,208.4 6,166.4 2,431.0 -9,033.1 Start Dir 3°/100': 14208.4'MD,6166.4'TVD 14,261.9 6,169.5 2,474.8 -9,063.7 End Dir: 14261.9'MD,6169.5'TVD 14,302.3 6,171.4 2,507.7 -9,087.1 Start Dir 3.17°/100': 14302.3'MD,6171.4'TVD 15,006.8 6,213.2 2,988.2 -9,594.4 Start Dir 3°/100': 15006.8'MD,6213.2'TVD 15,140.1 6,217.9 3,059.3 -9,707.1 Start Dir 2.97°/100': 15140.1'MD,6217.9'TVD 15,283.0 6,212.9 3,134.0 -9,828.7 Start Dir 3°/100': 15283'MD,6212.9'TVD 15,321.4 6,210.2 3,153.3 -9,861.8 End Dir: 15321.4'MD,6210.2'TVD 16,237.1 6,148.2 3,605.9 -10,655.4 Start Dir 3°/100': 16237.1'MD,6148.2'TVD 16,400.2 6,141.5 3,688.6 -10,795.8 Start Dir 2.97°/100': 16400.2'MD,6141.5'TVD 16,543.1 6,146.5 3,762.8 -10,917.8 Start Dir 3°/100': 16543.1'MD,6146.5'TVD 16,715.1 6,157.1 3,860.1 -11,059.2 End Dir:16715.1'MD,6157.1'TVD 17,842.0 6,216.2 4,538.7 -11,956.9 Total Depth: 17842.0'MD,6216.2'TVD 11/23/2010 4:56:35PM Page 12 COMPASS 2003.16 Build 428 ODSN-18 Well P&A Well Head: 9-5/8",5K,VetcoGray Tree: 3-1/2",5K,Horizontal Casing Item# Item MD(ft) TVD(ft) OB A 16"Conductor 158 158 B 11-3/4"60#L-80 Hydril 521, 10.772"ID 3,600 3309 C 9-5/8"40#L-80 Hydril 521,8.835"ID* 8,824 5329 O Balanced cement plug from 8724'-9174'MD 7"liner top cut at 9074'MD Ili Hi-Vis pill,top of pill @ 9174'MD Cement—500'above 7" liner shoe,TOC 10703' MD Top Kuparuk 11,110'MD 7"stuck Liner shoe @ 5 e_ 11203'MD {`� Top Nuigsut 11,808'MD 9'/2'Original Hole TD @11890'MD Date: Revision By: Comments 11/23/2010 JAD P&A—Stuck Liner t ;..: ODSN-18 Well Schematic— P&A PIONEER NATURAL RESOURCES ODSN-18 Well P&A and Sidetrack Well Head: 9-5/8",5K,VetcoGray Tree: 3-1/2",5K,Horizontal Casing Item# Item MD(ft) TVD(ft) OB A 16"Conductor 158 158 11-3/4"60#L-80 Hydril 521, 10.772"ID _ 3,600 3309 C 9-5/8"40#L-80 Hydril 521,8.835"ID* 8,824 5329 The kick off of the cement plug will be made keeping 150' of cement between the sidetrack point and the stuck liner. The sidetrack will be drilled to keep a minimum center to center distance of 80' MD from the stuck liner and original hole. O8-'h"x 9-W Intermediate Balanced cement plug 2 sidetrack kickoff point from 8724'-9174'MD 8924'MD/5365'TVD 7"liner top cut at 9074'MD Hi Vis pill,top of pill @ 9174'MD Cement—500'above 7" .p Kupar k 11,110'MD liner shoe,TOC 10703' MD 7"stuck Liner shoe @ 8-'/z'x 9-W Intermediate 2 11203'MD Top N iqsut 11,:$8'MD sidetrack TD 11970'MD/6167' TVD 9-'/z'Original Hole TD @ 11890'MD Date: Revision By: Comments 11/23/2010 JAD P&A and Sidetrack—Stuck Liner ODSN-18 Well Schematic— P&A and Sidetrack PIONEER • NATURAL RESOURCES Page 1 of 2 Schwartz, Guy L (DOA) From: Johnson, Vern [Vern.Johnson@pxd.com] Sent: Monday, November 08, 2010 11:35 AM To: Schwartz, Guy L(DOA) Cc: Hazzard, Vance; OoogurukDrillingSupervisor; Vaughan, Alex; Delmonico, Joe; Franks, James; Campoamor, Kathy; Daggett, Paul Subject: ODSN-18 (PTD 210-142) intermediate 1 drilling liner Attachments: odsn-18_torok_section.pptx Guy As discussed this weekend we have had problems running and cementing our 9-5/8" drilling liner on ODSN-18. We did not reach planned TD with the liner, and in the process of working the liner down we backed off 4 joints below the liner hanger. Wellbore Details: 11-3/4" Casing Shoe is set @ 3600' MD top joint of 9-5/8" liner is @ 3321' MD Casing Shoe @ 8824' MD open hole TD @ 9139' MD at the base of the Torok shale The 9-5/8" liner shoe is uncemented. Cement was not pumped across the liner top but,there is the potential for cement to have swapped with mud and covered some of the liner top. There is no liner hanger or liner top packer in place, and the liner stub is not believed to be in good enough condition to provided a seal if we screwed into it. Our plan is to clean out the liner(current rig operation), set a drillable squeeze packer, circulate or squeeze cement at the liner shoe, confirm liner pressure integrity, and squeeze cement at the liner top. After squeezing, we plan to test the liner top to 1500 psi for 30 min. We should then be ready to pick up a drilling BHA, cleanout and continue with our program for ODSN-18. This plan does not cover the Torok sand with cement. See the attached log of the Torok interval. It is expected that the top and bottom will be isolated. Also, bear in mind that the Torok is not expected flow without fracture stimulation. If the liner does not test, or we have significant problems, we will start working a contingency plan to cut and pull casing, then sidetrack and redrill the section. If you need a more detailed description of our forward plan, let me know. Vern Johnson Drilling Superintendent Pioneer Natural Resources Alaska 907-343-2111 office 907-575-9430 cell 11/8/2010 Page 2 of 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. Page 1 ofd 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, November 04, 2010 2:09 PM To: 'Crumrine, Tim' Subject: RE: Pioneer Oooguruk ODSN-18 Completion Design Question (PTD 210-142) Tim, Per our conversation.. go ahead with the planned PWD measurement for initial BHP. I would also try to get a minimal FBHP with the pump on as low as possible to see if the values come out close ( as they should) ... I would think the last pressure seen just as the FSV closes would be very close to the reservoir pressure as long as the drawndown is minimal. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Crumrine, Tim [mailto:Tim.Crumrine@pxd.com] Sent: Thursday, November 04, 2010 1:43 PM To: Schwartz, Guy L (DOA) Subject: Pioneer Oooguruk ODSN-18 Completion Design Question Hey Guy, Our completion design for ODSN-18 includes running a formation saver valve below the ESP completion. This was included on our PTD for the well. The valve will allow us to recomplete the well with no fluid loss to the formation during a potential ESP change out. After installation, the valve will not allow us to take a bottom hole pressure reading without turning on the pump. The Nuiqsut Pool Rules require a bottom-hole pressure survey be taken on each well prior to initial production. Because we cannot get a static bottom hole pressure after the completion is run, we have internally discussed taking a PWD measurement while pulling out of the hole and before swapping to heavy 10.0 ppg completion brine. We would take the pressure with the assistance of our MPD process with 7.1 ppg OBM in the hole. We believe we can get an accurate measurement this way. We would like to get clearance from the state to use this pressure in our reporting. Please let me know, if you would like further clarification, or further discuss our plans. Sincerely, Tim Crumrine, P.E. Staff Completions Engineer Pioneer Natural Resources Alaska, Inc. tim.crumrine@pxd.com Office: 907-343-2184 Cell: 907-240-4295 The United States Constitution(c) 1791.All Rights Reserved. We the People of the United States,in Order to form a more perfect Union, establish Justice,insure domestic Tranquility,provide for the common defence, promote the general Welfare,and secure the Blessings of Liberty to ourselves and our Posterity,do ordain and establish this Constitution for the United States of America. 11/4/2010 i -1 - . +.---11 v I } _. _ I , . �.. G) 70 i IJ . LI t II Pifer►4r r EA. 1 "A 1 ...iiiiil h ,IMINEIMMIIIIL i�� ^lz 1 I!•ism m!lrft Ui •. I . d I n � , I I � , ; Z 5450 5.400 5350 5300 5250 5200 5150 5100 5050 *000 4050 • -a N. 70 m . N Q 0 cu 0 N oocn0 wN -1 � � -I 0 00 LO..) U100 000 0 NJ N < 0 0) 3 < 0Vn < 3• v) v) I Q. aq N r Co C —I 0 0 —IC v 0 arca Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, November 12, 2010 10:43 AM To: 'Johnson, Vern' Subject: RE: ODSN-18 (PTD 210-142) intermediate 1 drilling liner Vern, Thanks for the update... you are clear to move forward and remove BOP stack to install multibowl adaptor. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Johnson, Vern [mailto:Vern.Johnson@pxd.com] Sent: Friday, November 12, 2010 10:40 AM To: Schwartz, Guy L(DOA) Cc: Vaughan, Alex; Delmonico, Joe; Franks, James; OoogurukDrillingSupervisor; Hazzard, Vance; Campoamor, Kathy Subject: ODSN-18 (PTD 210-142) intermediate 1 drilling liner Guy, Subsequent to our discussions yesterday and this morning, we have successfully tested the 11-3/4" casing, 9- 5/8" liner top and 11-3/4"x 9-5/8" liner lap to 2500 psi for 30 min. Per our discussion, we are going to proceed with removing the BOP stack and drilling spool to facilitate installing and testing the multibowl wellhead and BOP stack. Let me know if you need further information or want to discuss. Regards, Vern Johnson Drilling Superintendent 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. 11/12/2010 .4 3 311 i ' 'I ... L 11 3 ° G 3 � r1 G � fi iv . 1 v ---...? 7100 -1-6 Rog75-oA ` `'U S' nip NEr . / ,l s '' c K9z Y' Mn , iTo sir 37 rib . Z.;Ii-o-4.. 3DB` g 0..,,.. Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, November 08, 2010 4:16 PM To: 'Johnson, Vern' Cc: Hazzard, Vance; OoogurukDrillingSupervisor; Vaughan, Alex; Delmonico, Joe; Franks, James; Campoamor, Kathy; Daggett, Paul Subject: RE: ODSN-18 (PTD 210-142) intermediate 1 drilling liner Vern, Commission staff looked at the Torok sand OH logs( as well as offset wells)and determined that they are not a significant hydrocarbon zone in this area. Additionally there are no other significant hydrocarbon zones in the 11 3/" OH section. As stated below your proposed cementing procedure for the 9 5/8" drilling liner is approved. . Hopefully, circulation can be established once stung into the retainer but if not placing cement at the 9 5/8"shoe and down squeezing through the liner lap will isolate the zone sufficiently. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Johnson, Vern [mailto:Vern.Johnson@pxd.com] Sent: Monday, November 08, 2010 11:35 AM To: Schwartz, Guy L (DOA) Cc: Hazzard, Vance; OoogurukDrillingSupervisor; Vaughan, Alex; Delmonico, Joe; Franks, James; Campoamor, Kathy; Daggett, Paul Subject: ODSN-18 (PTD 210-142) intermediate 1 drilling liner Guy As discussed this weekend we have had problems running and cementing our 9-5/8" drilling liner on ODSN-18. We did not reach planned TD with the liner, and in the process of working the liner down we backed off 4 joints below the liner hanger. Wellbore Details: 11-3/4" Casing Shoe is set @ 3600' MD top joint of 9-5/8" liner is @ 3321' MD Casing Shoe @ 8824' MD open hole TD @ 9139' MD at the base of the Torok shale The 9-5/8" liner shoe is uncemented. Cement was not pumped across the liner top but,there is the potential for cement to have swapped with mud and covered some of the liner top. There is no liner hanger or liner top packer in place, and the liner stub is not believed to be in good enough condition to provided a seal if we screwed into it. Our plan is to clean out the liner(current rig operation), set a drillable squeeze packer, circulate or squeeze cement at the liner shoe, confirm liner pressure integrity, and squeeze cement at the liner top. After squeezing, we plan to test the liner top to 1500 psi for 30 min. We should then be ready to pick 11/8/2010 Page 2 of 2 up a drilling BHA, cleanout and continue with our program for ODSN-18. This plan does not cover the Torok sand with cement. See the attached log of the Torok interval. It is expected that the top and bottom will be isolated. Also, bear in mind that the Torok is not expected flow without fracture stimulation. If the liner does not test, or we have significant problems, we will start working a contingency plan to cut and pull casing,then sidetrack and redrill the section. If you need a more detailed description of our forward plan, let me know. Vern Johnson Drilling Superintendent 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. 11/8/2010 Page 1 of 2 Schwartz, Guy L (DOA) From: Johnson,Vern [Vern.Johnson@pxd.com] Sent: Monday, November 08, 2010 11:35 AM To: Schwartz, Guy L(DOA) Cc: Hazzard, Vance; OoogurukDrillingSupervisor; Vaughan, Alex; Delmonico, Joe; Franks, James; Campoamor, Kathy; Daggett, Paul Subject: ODSN-18 (PTD 210-142) intermediate 1 drilling liner Attachments: odsn-18_torok_section.pptx Guy As discussed this weekend we have had problems running and cementing our 9-5/8" drilling liner on ODSN-18. We did not reach planned TO with the liner, and in the process of working the liner down we backed off 4 joints below the liner hanger. Wellbore Details: 11-3/4" Casing Shoe is set @ 3600' MD top joint of 9-5/8" liner is @ 3321' MD Casing Shoe @ 8824' MD open hole TD @ 9139' MD at the base of the Torok shale The 9-5/8" liner shoe is uncemented. Cement was not pumped across the liner top but, there is the potential for cement to have swapped with mud and covered some of the liner top. There is no liner hanger or liner top packer in place, and the liner stub is not believed to be in good enough condition to provided a seal if we screwed into it. Our plan is to clean out the liner(current rig operation), set a drillable squeeze packer, circulate or squeeze cement at the liner shoe, confirm liner pressure integrity, and squeeze cement at the liner top. After squeezing, we plan to test the liner top to 1500 psi for 30 min. We should then be ready to pick up a drilling BHA, cleanout and continue with our program for ODSN-18. This plan does not cover the Torok sand with cement. See the attached log of the Torok interval. It is expected that the top and bottom will be isolated. Also, bear in mind that the Torok is not expected flow without fracture stimulation. If the liner does not test, or we have significant problems, we will start working a contingency plan to cut and pull casing,then sidetrack and redrill the section. If you need a more detailed description of our forward plan, let me know. Vern Johnson Drilling Superintendent Pioneer Natural Resources Alaska 907-343-2111 office 907-575-9430 cell 11/Q/7n1 n Page 2 of 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. 11/8/2010 O CI I— Y 0 L O C CO J Z • j TT j N 2E V N1 N}+o 0 0 1°— Zr, M rn co O Zn o0 0LA G Ln N in L co H 03 O CO a N i N LIJ ki Z - 0960 000 0409 0019 09L9 0029 0924 00£5 05£5 01 0909 F , 1 � !I k I I L 1.lnl•1■ 0 I I , I -r ! - - a-4 - - - -L ' - Oagem 0-1 o CL o .././4: co ua p r CD ID N .1" / CSIr T 1 cc Nr o o Z ll {- O s r ,t: 7y .,4 %, XV F N W o ti r_ —J co , �� Tio Lo ? h4 do /� J Zo N 5 O N • �•� f J N ❑ o 3! / • - -.- co Q Y ....., 0) 8 ._.l'illook,.. . : a....,.. o rk .. 9 /is : , /cn, u g in I /Z//'&' / - M f +; m 0 C? j Y cv2.1„,1,-/V 3 c� o CO / iii N oo J r 6 N Cf} 4,- cr / ZO0 N d. • NQ / 0l 0r , .7 / // // / / ! r(1-...--) ICN Up 07 NM / gt g o a / Ci T... CV f Z 4 N 'n O o / Q T ScgIATIE Ll nEASEA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMJHSSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Alex Vaughan Operations Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-18 Pioneer Natural Resources Alaska, Inc. Permit No: 210-142 Surface Location: 2935' FSL, 1177' FEL, SEC. 11, T13N, R7E, UM Bottomhole Location: 2186' FSL, 2572' FEL, SEC. 4, T13N, R7E, UM Dear Mr. Vaughan: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, O'lDaniel T. Seamount, Jr. r4ay Chair DATED this S of October, 2010. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA Fi'Zg SIV+ ' AL A OIL AND GAS CONSERVATION COME. ION SEP 2 2 2010 PERMIT TO DRILL 20 AAC 25.005 Al2sita ft&sai cat c•• le Zone la.Type of Work: 1b.Proposed Well Class: Development-Oil Q . Service- Winj ❑ Single Zone ❑ .. ic.Specioposed or: Drill Q . Redrill ❑ Stratigraphic Test ❑ Development-Gas 9 Service-Supply 9 Multiple 9 Coalbed as s Hydrates Re-entry 9 Exploratory 0 Service- WAG ❑ Service-Disp 0 Shale Gas 0 2.Operator Name: 5. Bond: Blanket 9 Single Well 9 11.Well Name and Number: Pioneer Natural Resources Alaska, Inc. Bond No. 103655283 ' ODSN-18 ' 3.Address: 700 G Street,Suite 600 6.Proposed Depth: 12.Field/Pool(s): Anchorage,AK 99501 MD: 17,682' TVD: 6206' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Oooguruk- Nuiqsut Oil Pool . Surface: 2935'FSL, 1177'FEL,Sec. 11,T13N, R7E, UM ADL 355036./ADL 355037 - Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 3158'FSL,3788'FEL,Sec. 10,T13N, R7E, UM 417497 October 12,2010 Total Depth: 9.Acres in Properly: 14.Distance to Nearest Property: 2186'FSL,2572'FEL,Sec.4,T13N, R7E, UM 5760/5724 3093' 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-469821.18 y-6031051.27 Zone-ASP 4 GL Elevation above MSL: to Same Pool: ODSN-40 is 1334' 13.5 feet away 16.Deviated wells: Kickoff depth: 300 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 94.24 degrees Downhole: 3163 Surface: 2480 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 14-1/2" 11-3/4" 60# L-80 Hyd 521 3455' Surface Surface 3498' 3240' 455 sx PF'L'; 407 sx Class'D' 11-3/4" 9-5/8" 40# L-80 Hyd 521 5500' 3348' 3138' 8848' 5348' 398 sx Class'G' _ 8-1/2" 7" 26# L-80 BTC-M 11,512' Surface Surface 11,555' 6122 160 sx Class'G' 6-1/8" 4-1/2" 12.6# L-80 Hyd 521 5978' 11,704' 6143' 17,682' 6206' 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 Surface Intermediatel -Drlg Liner Intermediate 2 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat 9 BOP Sketch 9 Drilling Program 9 Time v.Depth Plot 9 Shallow Hazard Analysis9 Diverter Sketch❑ Seabed Report 9 Drilling Fluid Program 9 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 Alex Vaughan Title Operations Drilling Engineer Signatur� = Phone 343-2186 Date 9/22/2010 Commission Use Only Permit to Drill /J API Number: Permit Approval See cover letter for other Number: Zf(>� `7 / 50-7C3-2,66-,z4/ Ix Date: i b ) 0 requirements. Conditions of approval: If box is checked,we ay not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: a Other: q 5V 5t 13O( �c $7 Samples req'd: Yes 9 No2/1/ Mud log req'd: Yes 9 No El" . Z50o ns` A.-.........14.. es f--Cy..,,,,) H2S measures: Yes 9 No[ Directional svy req'd: Yes ['No 0 - .Dimer x- WAi1C-I , 20Ai4c.. 2-5•0350164) Hc APPROVED BY THE COMMISSION J D DATE: ,COMMISSIONER ORIGINAL ,.4. ra•s•' �_ p. z'' ,o Form 10-401(Revised 7/2009) Thispermit is valid for 24 months from the date of approval(20 AAC 25.005 S ��`C (e„! pp (g)) Submit in Duplicate CD 4-18 & N-18L1 Propos : Completion Design I ED Casing O Item# Item MD(ft) TVD(ft) A 16" Conductor 158 158 ♦"- Z3 B 11-3/4"60#L-80 Hydril 521, 10.772" ID 3,498 3240 C 9-5/8"40#L-80 Hydril 521, 8.835" ID* 8,848 5348 D 7"26#L-80 BTC-M, 6.276" ID** 11,555 6122 E 4-1/2" 12.6#Hydril 521 3.958" ID 19,098 6146 F 4-1/2" 12.6#Hydril 521 3.958" ID 17,682 6206 G 2-7/8" 6.5#L-80 IBT-M 11,273 G ' * Planned TOC @ 7764'MD 33Z� a�? ** Planned TOC @ 10,603'MD Pri 749 1 VetcoGray Tubing Hanger 34 34 i�` 2 2-7/8"Wellstar Tubing Retreivable ScSSSV 2,023 2,000 3 GLM#1 -2-7/8"x 1-1/2" (min. 3 jts above top X nipple) 2,350 2,316 ATOP 2-7/8"X Nipple 2.313" I.D. (min. 2 jts above Gas Vent 4 Valve Packer) 2,470 2,428 CI {/ 5 WFT 7"x 2-7/8" Gas Vent Valve Packer(max. TVD 2500') 2,550 2,500 S „•�7 '� 6 GLM#2-2-7/8"x 1-1/2" (min. 2 jts above X nipple) 9,660 5,632 8 2-7/8"X Nipple, 2.313" ID(max. incl. 70 deg)w/ RHC-M 7 Plug Body 9,700 5,645 8 Automatic Divert Valve(ADV) 11,202 6,061 O it,r,+L' 9 ESP (Pump, Motor, and Jewelry) 11,212 6,062 End of Assembly 11,273 6,073 F 0 / ''i 10 WFT 7"x 3-1/2" Retrievable Packer 11,323 6082 \ O / ��tbL� 11 WFT 3-1/2"Sliding Sleeve 11,348 6,,086 12 WFT 3-1/2" Formation Saver Valve 11,373 6,090 WLEG 11,383 6,092 End of Assembly 11,388 6,093 N-18 LI Item# Item MD(ft) TVD(ft) V 13 WFT PBR Tie Back Sleeve 51t 11,388 6,093 0 jJ M a 14 WFT"NTH" Liner Top Pkr 1 1,403 6,096 15 WFT"PHR" Rotating Hyd Set Liner Hanger 11,405 6,096 Weatherford Sliding Sleeve(6)1/2" ports (-across from 16 aluminum billet) 11,705 6,143 17 Oil Swell Packer(approx. 3 joints below side track point) 11,825 6,157 ED18 Resman Tracer Pup(heel location) 11,745 6,148 0 .....it 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes), (4...----N...--I 19 spaced every 200'. t 20 Resman Tracer Pup(midlateral location) 15,250 6,138 21 Resman Tracer Pup(toe location) 19,066 6,145 GI �� 21,..'"Ati 22 Liner Shoe(PLUGGED)w/4-1/2" Hydril 521 19,086 6,146 End of Assembly 19,088 6,146 • O O ® „..... Item# Item ,. MD(ft) _ _TVD(ft). CI 23 Weatherford Aluminum Billet 11,705 6,143 24 Resman Tracer Pup(heel location) 11,745 6,147 4-1/2" 12.60#L-80 Hydril Pupjt 4ft(Ported w/6 1/2 holes), ® CO 25 spaced every 200'. 26 Resman Tracer Pup(midlateral location) 14,700 6,186 27 Resman Tracer Pup(toe location) 17,650 6,204 28 Liner Shoe(PLUGGED)w/4-1/2" Hydril 521 17,670 6,205 OD End of Assembly 17,672 6,205 ' ResMan Produced Oil&Water Markers (OD Aluminum Kick-Off Billet ® �•' •• •• •• •• •• •• 1s 2a •• •• c-rji •• 0 •• •• •• 00 III Sliding Sleeve •• •• •• •• •• •• O •• •• IS II •• ••• •• O 17 5.75"x4-W Oil 0 •• ( 19 •• •• 0 •• •• •• ®® Base Swell IS IS IS IS •• •• Packer Date: Revision By: Comments N-18 & N-18L1 PIONEER 9/7/2010 JAD Dual Lateral Revision Proposed NATURAL RESOORCESALAS(A Completion Design PIONEER NATURAL RESOURCES ALASKA Pioneer Natural Resources Alaska, Inc. 700 G Street,Suite 600 RECEIEI Anchorage,Alaska 99501 VED Tel:(907)277-2700 Fax:(907)343-2190 SEP 222010 September 22nd, 2010 Alaska QN&6osCom Coviskesion Anchorage State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Permit to Drill ODSN-18 & ODSN-18L1 Surface Location: 2935' FSL, 1177' FEL, Sec 11, T13N, R7E, UM X = 469821.18, Y= 6031051.27, 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 multi-lateral well in the Oooguruk-Nuiqsut formation. PNRA requests the Permit to Drill based on approved Pool Rules. As indicated in the attachments, the drillingand well construction program includes the P g following: • Surface Hole: o Drill 14-1/2" to -3,498' MD/3,240'TVD and set 11-3/4" casing. • Intermediate Hole 1: o Drill 10-5/8" and under-ream while drilling (UWD) to 11-3/4" to -8,848' MD / 5,348' TVD. Run and set a 9-5/8" Drilling Liner. • Intermediate Hole 2: o Drill 8-1/2" to -11,555' MD /6,122' TVD and set a 7" Intermediate casing into the top of the Oooguruk-Nuiqsut formation. • ODSN-18 Production Hole: o Drill 6-1/8" horizontally to -17,682' MD / 6,206' TVD and set a 4-1/2" plop-&-drop solid liner with perforated pups. • ODSN-18L1 Production Hole: o Kick off ODSN-18 lateral @ -11,704' MD /6,143' TVD o Drill 6-1/8" horizontally to -19,098' MD / 6,146' TVD and set a 4-1/2" solid liner with perforated pups. • Completion: o 2-7/8" tubing ESP completion string with packer, SSSV & GLM. Alaska Oil & Gas Conservation Commission September 22nd, 2010 Page 2 of 3 PNRA will implement Managed Pressure Drilling technology (MPD) while drilling the Intermediate 2 and Production hole sections of ODSN-18 & ODSN-18L1 as outlined below. • 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 • Nuiqsut Sands, -9.8 ppg Pore Pressure • • From the Intermediate 2 Shoe to ODSN-18 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 • From the Intermediate 2 Shoe to ODSN-18L1 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 September 22nd, 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 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 October 12th, 2010. If you have any questions or require further information, please contact Alex Vaughan at 907.343.2186. Sincerely, jr Alex Vaughan Operations Drilling Engineer Attachments: Form 10-401 Supporting permit information cc: ODSN-18 & ODSN-18L1 Well File Permit to Drill Well Plan Summary ODSN-18 Oooguruk — Nuiqsut Multi-Lateral Production Well Surface TD @ 3,498' MD / 3,240' TVD Drilling Liner TD @ 8,848' MD / 5,348' TVD Intermediate TD @ 11 ,555' MD / 6,122' TVD ODSN-18 Lateral TD @ 17,682' MD / 6,206' TVD ODSN-18L1 Lateral Kickoff @ 11 ,704' MD / 6,143' TVD' ODSN-18L1 Lateral TD @ 19,098' MD / 6,146' TVD Surface Location: 2935' FSL, 1177' FEL, Sec. 11,T13N, R7E, UM ASP 4(NAD27) projection X=469821.18 Y=6031051.27 Target: Oooguruk-Nuiqsut 3158' FSL, 3788' FEL, Sec. 10,T13N, R7E, Umiat X=461932. Y=6031310. 6122' TVDrkb Bottom Hole Location ODSN-18 2186' FSL, 2572' FEL, Sec.4,T13N, R7E, Umiat X =457882.02 Y=6035639.99 6206' TVDrkb Bottom Hole Location ODSN-18L1 2818' FSL, 3987' FEL, Sec. 4,T13N, R7E, Umiat X =456469.03 Y=6036279.98 6146' TVDrkb AFE Number: TBA Est. Start Date: Oct 12th, 2010 Rig: Nabors 19AC Operating days: 49 days to Drill and Complete Objective &Well Type Nuiqsut Development Well Well Design: Modified Slimhole (11-3/4"x 9-5/8" liner x 7"x 4-1/2" liner) Multi-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:September 22"d,2010 ODSN-18 Permit To Drill Page 1 of 12 Well Control: Well Section Pressure Depth psi TVD Basis 14-1/2" Surface Section Maximum anticipated BHP 1449 3240 Based on seawater gradient of 0.4472 psi/f Maximum surface pressure 1093 Surface (Based on BHP and a full column of gas from TD @ 0.11 psi/ft) 10-5/8" x 11-3/4" Drilling Liner Hole Section Maximum anticipated BHP 2392 5348 (Based on seawater gradient of 0.4472 psi/ft) • Maximum surface pressure 1803 Surface Based on BHP and a full column of gas from TD @ 0.11 psi/ft) 8-1/2" Intermediate Casing Hole Section Maximum anticipated BHP 3120 6122 Based on 9.8 ppg Oooguruk-Kuparuk pore pressure) Maximum surface pressure 2446 Surface Based on BHP and a full column of gas from TD @ 0.11 psi/ft) 6-1/8" ODSN-18 Production Liner Hole Section Maximum anticipated BHP 3163 6206 Based on 9.8 ppg Oooguruk-Nuiqsut pore pressure) Maximum surface pressure 2480 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 0,/ Diverter(see attached schematic)—Note: Requesting Diverter Exemption on a Well by Well Basis): v✓ 4 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 Pioneer Natural Resources Last Revised: September 22nd,2010 ODSN-18 Permit To Drill Page 2 of 12 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: 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 Drilling Liner 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 Intermediate Hole Mud Properties: 8-1/2" 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: September 22"d,2010 ODSN-18 Permit To Drill Page 3 of 12 Formation Markers: Pore Press. EMW Formation Tops MD(ft) TVDrkb(ft) (psi) (PPComments Base of Permafrost 1666 Top West Sak 2320 2286 1028 8.65 Base of fluvial sands Tuffaceous Shales 3083 2946 Hue2 tuff 3483 3230 11-3/4"casing point 3236 Brook 2B 5754 4270 1921 8.65 Top Torok Sand 7814 4988 Base Torok Sand 8537 5239 Torok Shale 1 9071 5425 9-5/8"casing point 5429 Top HRZ 10202 5809 Base HRZ 10613 5927 Kalubik Mkr 10770 5967 Top Kup C 11103 6041 3078 9.8 LCU 11133 6047 BCU 11343 6085 Top Nuiqsut 11553 6121 3119 9.8 Production Zone 7"casing point 11555 6122 ODSN-18 TD 17682 6207 Pioneer Natural Resources Last Revised: September 22nd,2010 ODSN-18 Permit To Drill Page 4 of 12 Logging Program: 14-1/2" Section: Drilling: Dir/GR Open Hole: N/A Cased Hole: N/A 10-5/8" x 11-3/4" Section: Drilling: Dir/GR Open Hole: N/A Cased Hole: N/A 8-1/2" Section: Drilling: _ Dir/GR/Res ' Open Hole: N/A Cased Hole: ODSN-18 6-1/8"Section:— Drilling: Mud logging Dir/GR/Res/AzDens/Neut /Dens/PWD • Open Hole: N/A Cased Hole: N/A Pioneer Natural Resources Last Revised:September 22nd,2010 ODSN-18 Permit To Drill Page 5 of 12 ODSN-18 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 3455 Surface 3498 3240 11-3/4" 9-5/8" 40# L-80 Hydril 521 5500 3348 8848 5348 8-1/2" 7" 26# L-80 BTC-M 11512 Surface 11555 6122 6-1/8" 4-1/2" 12.6# L-80 Hydril 521 5978 11704 17682 6206 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:September 22nd,2010 ODSN-18 Permit To Drill Page 6 of 12 Cement Calculations: Casing Size: 11-3/4" 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: 30% excess, plus 85' shoe track Tail TOC: 2,655' MD Total Cement Volume: Preflush 10 bbl water Spacer 60 bbl 10.0 ppg Dual Spacer Lead 336 bbls/455.s of 10.92 ppg Type "L" Permafrost Cement. 4.15 cf/sk, 20.0 gps water req. Tail 86 bbls/4Q7_sx_of 15.9 ppg Premium "G" + adds. 1.19 cf/sk, 5.23 gps water req. Displ 374 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. Casing Size: 9-5/8" Intermediate 1 - Drilling Liner-single stage Basis: TOC: 7764' MD-The greater of 500' MD of open hole or 50' 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 83 bbls/ 39 sx Premium "G"+adds. 1.17 cf/sk Displ 470 bbls mud _ Temp BHST - 135° F, BHCT -110° F Casing Size: 7" Intermediate 2-single stage Basis: TOC: -10603'MD-500' MD above the top of the Kuparuk 40%excess, plus 85' shoe track Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl,12.5 ppg Dual Spacer Primary 33 bbls/ 160 sx Premium "G"+adds. 1.17 cf/sk Displ 439 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 Injection: 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:September 22nd,2010 ODSN-18 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. Rig Activity: Drill and Complete 1. MIRU Nabors 19AC over pre-installed 16"conductor casing. 2. Nipple up spacer spools and riser. Ne Ditmer'-Cr 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" surface casing. 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 Riser, NU Drilling Spool and BOPE and test. Test BOPE to 250/4500 psi - Notify AOGCC 48.E hours in advance of test. 7. 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). 8. RIH and cleanout casing to landing collar. Displace well over to Intermediate 1 drilling fluid. - 9. Drill through surface shoe, rathole +20' of new hole and perform LOT to a minimum of 12.5 ppg.• 10. Drill 10-5/8"x 11-3/4" Intermediate 1 to casing point. • 11. Change one set of pipe rams to 9-5/8"and test BOPE as required. - 12. Run 9-5/8"drilling liner on 5" DP. Set liner hanger, release from liner and cement. - 13. Bump the plug, increase pressure to 3500 psi and hold pressure for 5 minutes • 't o t,4 • This will provide a quick integrity test of the 9-5/8" liner • Note the pressure test in the morning report 14. Release pressure and ensure floats are holding - �C • This will check the integrity of the floats to ensure there isn't a flow path through the liner shoe 15. 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 Note: The surface casing was pressure tested to 3500 psi for 30 minutes prior to drilling out the surface casing shoe 16. POOH w/5" DP. 17. ND BOPE, NQ Drillings o�ol: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 -K test prior to performing this step 18. MU 8-1/2" RSS, MWD/LWD on 5" DP. RU MPD trip nipple. ' 19. RIH and cleanout casing to landing collar. 20. 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. 21. Drill through drilling liner shoe +20' of new hole and perform FIT to 13.5 ppg, 22. RD MPD trip nipple and RU bearing assembly. Drill 8-1/2" Intermediate 2 to casing point. Pioneer Natural Resources Last Revised: September 22",2010 ODSN-18 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" long string or as a 7" liner with a VV"-- 7"tieback string to surface depending on drilling conditions. Both options have been provided below: Option#1: 7" Longstrinq 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. LD 5" DP Option#2: 7" Liner with Tie-Back Option t/ 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: September 22nd,2010 ODSN-18 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" plop& drop solid production liner w/perforated pups below an aluminum billet for kicking off to drill ODSN-18L1. Kickoff and liner string will run from 11,704'to ODSN-18 TD. 51. Release from plop& drop liner and aluminum billet. 52. POH to intermediate shoe and set heavy weight balance brine pill. RU MPD trip nipple and POH to surface. 53. Drill ODSN-18L1 See included application for ODSN-18L1 Permit to Drill. Pioneer Natural Resources Last Revised:September 22"d,2010 ODSN-18 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: September 22nd,2010 ODSN-18 Permit To Drill Page 11 of 12 ODSN-18 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 2392 12.5 ppg (LOT) 10-5/8"x 11-3/4" 9-5/8" Drilling Liner/ Infinite 9.8-10.5 ppg 3120 13.5 ppg (FIT), 8-1/2" (12.5 EMW w/MPD) ODSN-18 7.2-8.2 ppg 7" Intermediate/ Infinite (g g_10.2 EMW w/MPD) 3163 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 H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Faults • Four seismic faults with expected throws of 20-35' may be encountered around 9,400' - 17,700' MD. Losses may be associated with these faults. • Consult the ODS data sheet for additional information (still in development) Pioneer Natural Resources Last Revised:September 22nd,2010 ODSN-18 Permit To Drill Page 12 of 12 ___ X CI 0 > v..I Z. CL. CO Z ..—I 0- Z ul , o z o 0 ...i 8 -I 2 2 G.0_ 4 8 8 , r 0 bl 4J 43 +13 V 02 002o . 4 f A : ci) ' A " P " 7 ' . : A ! A ' 0 : 1 1 e. lit : e : N4 bi / 1 E 1 + 1 ... NI a : Mil aliJ , .W. SS 0 i il I •A, __-- ., ----- • k I_ > 2, a _ , . mr., al _ ___, Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-18 - Slot ODS-18 ODSN-18 PN11 Plan: ODSN-18 PN11 wp08 Standard Proposal Report 14 September, 2010 HALLIBURTON • • Sperry Drilling Services - — 1 d .10,40111110.Zilk .11-1.2Z1.11.0‘. i / NM NV II 'V MEM 074:1;i211IrgIlii;: Z 11 \ F IIIII 6 'iliir,"\v-q`- '7 i!II%-4` 01U1111 Ad111 . 111111V ,-.- NIIMIka.. II/! 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(uo-10056) *ea ponnA anal u Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) " Project: Oooguruk Development MD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True , Well: ODSN-18 Survey Calculation Method: Minimum Curvature"- Wellbore: urvatureWellbore: ODSN-18 PN11 Design: ODSN-18 PN11 wp08 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 ODSN-18-Slot ODS-18 Well Position +N/-S 0.0 ft Northing: 6,031,051.27 ft Latitude: 70°29'45.254 N +EI-W 0.0 ft Easting: 469,821.18 ft - Longitude: 150°14'48.375 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft Wellbore ODSN-18 PN11 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1 (?) (?) (nT) I G R F 2 0 0510 10/15/2010 Design ODSN-18 PN11 wp08 Audit Notes: Version: Phase: PLAN Tie On Depth: 42.5 Vertical Section: Depth From(TVD) +N/•S +E/-W Direction (ft) (ft) (ft) (?) 42.5 0.0 0.0 290.79 9/14/2010 9:08:33AM Page 2 COMPASS 2003.16 Build 428 Halliburton Company I-IALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.5+13.5'@ 56.0ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.5+13.5'@ 56.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 Design: ODSN-18 PN11 wp08 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +NI-S +El-W Rate Rate Rate Tool Face (ft) (?) (?) (ft) ft (ft) (ft) (?/100ft) (?/100ft) (?/100ft) (?) 42.5 0.00 0.00 42.5 -13.5 0.0 0.0 0.00 0.00 0.00 0.00 300.0 0.00 0.00 300.0 244.0 0.0 0.0 0.00 0.00 0.00 0.00 600.0 3.00 275.23 599.9 543.9 0.7 -7.8 1.00 1.00 0.00 275.23 800.6 5.01 275.23 800.0 744.0 2.0 -21.8 1.00 1.00 0.00 0.00 1,662.8 13.63 275.23 1,650.0 1,594.0 14.7 -160.6 1.00 1.00 0.00 0.00 1,765.7 13.63 275.23 1,750.0 1,694.0 16.9 -184.8 0.00 0.00 0.00 0.00 2,065.7 13.63 275.23 2,041.6 1,985.6 23.4 -255.2 0.00 0.00 0.00 -90.00 2,165.7 13.63 275.23 2,138.7 2,082.7 25.5 -278.6 0.00 0.00 0.00 0.00 3,154.9 43.08 266.37 3,000.0 2,944.0 14.5 -742.2 3.00 2.98 -0.90 -12.27 4,970.3 69.63 258.92 3,997.8 3,941.8 -192.2 -2,224.0 1.50 1.46 -0.41 -15.41 8,957.8 69.63 258.92 5,386.1 5,330.1 -910.7 -5,892.3 0.00 0.00 0.00 0.00 11,254.9 80.00 330.00 6,069.9 6,013.9 -29.1 -7,743.2 3.00 0.45 3.09 93.17 11,554.9 80.00 330.00 6,122.0 6,066.0 226.7 -7,891.0 0.00 0.00 0.00 0.00 11,828.9 87.06 334.24 6,152.9 6,096.9 467.2 -8,018.1 3.00 2.58 1.55 31.07 12,500.8 87.06 334.24 6,187.3 6,131.3 1,071.5 -8,309.8 0.00 0.00 0.00 0.00 12,594.7 86.00 336.85 6,193.0 6,137.0 1,156.8 -8,348.6 3.00 -1.13 2.78 112.19 12,728.0 90.00 336.85 6,197.7 6,141.7 1,279.3 -8,400.9 3.00 3.00 0.00 0.00 12,861.4 94.00 336.85 6,193.0 6,137.0 1,401.8 -8,453.3 3.00 3.00 0.00 0.00 13,059.1 93.15 330.97 6,180.7 6,124.7 1,578.9 -8,540.0 3.00 -0.43 -2.97 -98.08 13,717.2 93.15 330.97 6,144.5 6,088.5 2,153.5 -8,858.9 0.00 0.00 0.00 0.00 13,773.9 94.00 329.50 6,141.0 6,085.0 2,202.6 -8,887.0 3.00 1.50 -2.60 -59.88 13,907.2 90.00 328.83 6,136.3 6,080.3 2,317.0 -8,955.3 3.04 -3.00 -0.50 -170.54 14,067.2 86.00 325.63 6,141.9 6,085.9 2,451.4 -9,041.8 3.20 -2.50 -2.00 -141.36 14,919.6 86.27 300.00 6,200.3 6,144.3 3,024.5 -9,660.5 3.00 0.03 -3.01 -90.28 15,043.9 90.00 300.00 6,204.4 6,148.4 3,086.6 -9,768.0 3.00 3.00 0.00 0.00 15,177.2 94.00 300.00 6,199.7 6,143.7 3,153.2 -9,883.4 3.00 3.00 0.00 0.00 15,193.3 94.24 300.42 6,198.6 6,142.6 3,161.3 -9,897.2 3.00 1.51 2.60 59.70 16,067.6 94.24 300.42 6,133.9 6,077.9 3,602.8 -10,649.2 0.00 0.00 0.00 0.00 16,107.9 94.00 299.23 6,131.0 6,075.0 3,622.8 -10,684.1 3.00 -0.60 -2.95 -101.54 16,395.2 86.33 304.19 6,130.2 6,074.2 3,773.6 -10,928.2 3.18 -2.67 1.73 147.09 16,408.0 86.33 304.19 6,131.0 6,075.0 3,780.7 -10,938.7 0.00 0.00 0.00 0.00 16,494.5 86.64 306.77 6,136.3 6,080.3 3,830.9 -11,009.1 3.00 0.36 2.98 83.19 17,682.3 86.64 306.77 6,206.0 6,150.0 4,540.7 -11,958.9 0.00 0.00 0.00 0.00 I I I 9/14/2010 9:08:33AM Page 3 COMPASS 2003.16 Build 428 Halliburton Company 1-I1-IALLIBURTClie Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.5+13.5 @ 56.0ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 Design: ODSN-18 PN11 wp08 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 42.5 0.00 0.00 42.5 -13.5 0.0 0.0 6,031,051.27 469,821.18 0.00 0.00 , 100.0 0.00 0.00 100.0 44.0 0.0 0.0 6,031,051.27 469,821.18 0.00 0.00 200.0 0.00 0.00 200.0 144.0 0.0 0.0 6,031,051.27 469,821.18 0.00 0.00 300.0 0.00 0.00 300.0 244.0 0.0 0.0 6,031,051.27 469,821.18 0.00 0.00 KOP Begin Directional 1.00 300.0'MD 400.0 1.00 275.23 400.0 344.0 0.1 -0.9 6,031,051.35 469,820.31 1.00 0.84 500.0 2.00 275.23 500.0 444.0 0.3 -3.5 6,031,051.60 469,817.70 1.00 3.36 600.0 3.00 275.23 599.9 543.9 0.7 -7.8 6,031,052.02 469,813.36 1.00 7.56 700.0 4.00 275.23 699.7 643.7 1.3 -13.9 6,031,052.60 469,807.29 1.00 13.45 800.0 5.00 275.23 799.4 743.4 2.0 -21.7 6,031,053.35 469,799.48 1.00 21.00 800.6 5.01 275.23 800.0 744.0 2.0 -21.8 6,031,053.35 469,799.42 1.00 21.06 900.0 6.00 275.23 898.9 842.9 2.9 -31.3 6,031,054.26 469,789.94 1.00 30.24 1,000.0 7.00 275.23 998.3 942.3 3.9 -42.5 6,031,055.34 469,778.67 1.00 41.14 1,100.0 8.00 275.23 1,097.4 1,041.4 5.1 -55.5 6,031,056.58 469,765.68 1.00 53.72 1,200.0 9.00 275.23 1,196.3 1,140.3 6.4 -70.2 6,031,057.99 469,750.97 1.00 67.96 I 1,300.0 10.00 275.23 1,294.9 1,238.9 7.9 -86.7 6,031,059.56 469,734.54 1.00 83.86 1,400.0 11.00 275.23 1,393.3 1,337.3 9.6 -104.8 6,031,061.30 469,716.40 1.00 101.41 1,500.0 12.00 275.23 1,491.2 1,435.2 11.4 -124.7 6,031,063.19 469,696.56 1.00 120.62 1,600.0 13.00 275.23 1,588.9 1,532.9 13.4 -146.2 6,031,065.26 469,675.01 1.00 141.47 1,662.8 13.63 275.23 1,650.0 1,594.0 14.7 -160.6 6,031,066.63 469,660.62 1.00 155.40 End Directional 1662.8'MD 1,700.0 13.63 275.23 1,686.1 1,630.1 15.5 -169.4 6,031,067.47 469,651.89 0.00 163.84 1,765.7 13.63 275.23 1,750.0 1,694.0 16.9 -184.8 6,031,068.94 469,636.48 0.00 178.76 1,800.0 13.63 275.23 1,783.3 1,727.3 17.7 -192.8 6,031,069.71 469,628.44 0.00 186.54 1,900.0 13.63 275.23 1,880.5 1,824.5 19.8 -216.3 6,031,071.96 469,604.99 0.00 209.24 2,000.0 13.63 275.23 1,977.7 1,921.7 22.0 -239.8 6,031,074.20 469,581.54 0.00 231.94 2,065.7 13.63 275.23 2,041.6 1,985.6 23.4 -255.2 6,031,075.67 469,566.12 0.00 246.86 2,100.0 13.63 275.23 2,074.9 2,018.9 24.1 -263.2 6,031,076.44 469,558.08 0.00 254.64 2,165.7 13.63 275.23 2,138.7 2,082.7 25.5 -278.6 6,031,077.92 469,542.68 0.00 269.55 Begin Directional DLS 3.00 2165.7'MD 2,200.0 14.63 274.37 2,172.0 2,116.0 26.2 -287.0 6,031,078.65 469,534.33 3.00 277.60 2,300.0 17.59 272.40 2,268.1 2,212.1 27.8 -314.7 6,031,080.36 469,506.65 3.00 304.06 2,400.0 20.55 270.98 2,362.6 2,306.6 28.7 -347.3 6,031,081.42 469,474.01 3.00 334.91 2,500.0 23.52 269.91 2,455.2 2,399.2 29.0 -384.8 6,031,081.85 469,436.50 3.00 370.08 2,600.0 26.50 269.07 2,545.9 2,489.9 28.6 -427.1 6,031,081.63 469,394.23 3.00 409.46 2,700.0 29.48 268.39 2,634.1 2,578.1 27.6 -474.0 6,031,080.76 469,347.31 3.00 452.95 2,800.0 32.47 267.82 2,719.9 2,663.9 25.9 -525.5 6,031,079.25 469,295.88 3.00 500.42 2,900.0 35.46 267.33 2,802.8 2,746.8 23.5 -581.3 6,031,077.11 469,240.06 3.00 551.76 3,000.0 38.45 266.92 2,882.7 2,826.7 20.5 -641.3 6,031,074.33 469,180.03 3.00 606.81 I 3,100.0 41.44 266.55 2,959.4 2,903.4 16.8 -705.4 6,031,070.93 469,115.93 3.00 665.42 3,154.9 43.08 266.37 3,000.0 2,944.0 14.5 -742.2 6,031,068.80 469,079.07 3.00 699.06 Start DLS 1.50 'MD 3,200.0 43.73 266.11 3,032.8 2,976.8 12.5 -773.2 6,031,066.90 469,048.15 1.50 727.25 3,300.0 45.18 265.56 3,104.1 3,048.1 7.4 -843.0 6,031,062.09 468,978.28 1.50 790.75 3,400.0 46.63 265.03 3,173.7 3,117.7 1.5 -914.6 6,031,056.48 468,906.69 1.50 855.57 9/14/2010 9:08:33AM Page 4 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 Design: ODSN-18 PN11 wp08 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) 3,184.00 3,497.8 48.06 264.54 3,240.0 3,184.0 -5.0 -986.2 6,031,050.22 468,835.03 1.50 920.22 11 3/4" 3,500.0 48.09 264.52 3,241.5 3,185.5 -5.2 -987.9 6,031,050.08 468,833.42 1.50 921.67 3,600.0 49.54 264.04 3,307.3 3,251.3 -12.7 -1,062.7 6,031,042.88 468,758.51 1.50 989.02 3,700.0 51.00 263.58 3,371.2 3,315.2 -21.0 -1,139.2 6,031,034.90 468,682.03 1.50 1,057.55 3,800.0 52.46 263.14 3,433.2 3,377.2 -30.1 -1,217.2 6,031,026.14 468,604.02 1.50 1,127.23 3,900.0 53.92 262.72 3,493.1 3,437.1 -39.9 -1,296.6 6,031,016.61 468,524.54 1.50 1,198.01 4,000.0 55.38 262.31 3,550.9 3,494.9 -50.6 -1,377.5 6,031,006.31 468,443.64 1.50 1,269.84 4,100.0 56.85 261.91 3,606.7 3,550.7 -62.0 -1,459.7 6,030,995.25 468,361.37 1.50 1,342.66 4,200.0 58.31 261.53 3,660.3 3,604.3 -74.1 -1,543.2 6,030,983.43 468,277.80 1.50 1,416.44 4,300.0 59.78 261.16 3,711.7 3,655.7 -87.0 -1,628.0 6,030,970.87 468,192.98 1.50 1,491.11 4,400.0 61.24 260.80 3,760.9 3,704.9 -100.7 -1,714.0 6,030,957.57 468,106.97 1.50 1,566.64 4,500.0 62.71 260.45 3,807.9 3,751.9 -115.0 -1,801.1 6,030,943.55 468,019.83 1.50 1,642.96 4,600.0 64.18 260.11 3,852.6 3,796.6 -130.1 -1,889.2 6,030,928.80 467,931.61 1.50 1,720.02 4,700.0 65.65 259.78 3,895.0 3,839.0 -146.0 -1,978.4 6,030,913.35 467,842.38 1.50 1,797.77 4,800.0 67.12 259.45 3,935.1 3,879.1 -162.5 -2,068.5 6,030,897.21 467,752.20 1.50 1,876.17 4,900.0 68.59 259.14 3,972.8 3,916.8 -179.7 -2,159.6 6,030,880.37 467,661.13 1.50 1,955.14 4,970.3 69.63 258.92 3,997.8 3,941.8 -192.2 -2,224.0 6,030,868.13 467,596.61 1.50 2,010.98 End Directional 4970.3 4970.3'MD 5,000.0 69.63 258.92 4,008.2 3,952.2 -197.5 -2,251.4 6,030,862.89 467,569.27 0.00 2,034.63 5,100.0 69.63 258.92 4,043.0 3,987.0 -215.6 -2,343.4 6,030,845.25 467,477.21 0.00 2,114.23 5,200.0 69.63 258.92 4,077.8 4,021.8 -233.6 -2,435.3 6,030,827.61 467,385.15 0.00 2,193.84 5,300.0 69.63 258.92 4,112.6 4,056.6 -251.6 -2,527.3 6,030,809.96 467,293.09 0.00 2,273.45 5,400.0 69.63 258.92 4,147.4 4,091.4 -269.6 -2,619.3 6,030,792.32 467,201.03 0.00 2,353.06 5,500.0 69.63 258.92 4,182.3 4,126.3 -287.6 -2,711.3 6,030,774.68 467,108.98 0.00 2,432.67 5,600.0 69.63 258.92 4,217.1 4,161.1 -305.7 -2,803.3 6,030,757.03 467,016.92 0.00 2,512.28 5,700.0 69.63 258.92 4,251.9 4,195.9 -323.7 -2,895.3 6,030,739.39 466,924.86 0.00 2,591.89 5,800.0 69.63 258.92 4,286.7 4,230.7 -341.7 -2,987.3 6,030,721.75 466,832.80 0.00 2,671.50 5,900.0 69.63 258.92 4,321.5 4,265.5 -359.7 -3,079.3 6,030,704.10 466,740.74 0.00 2,751.11 6,000.0 69.63 258.92 4,356.3 4,300.3 -377.7 -3,171.3 6,030,686.46 466,648.68 0.00 2,830.71 6,100.0 69.63 258.92 4,391.1 4,335.1 -395.7 -3,263.3 6,030,668.82 466,556.62 0.00 2,910.32 6,200.0 69.63 258.92 4,426.0 4,370.0 -413.8 -3,355.3 6,030,651.17 466,464.56 0.00 2,989.93 6,300.0 69.63 258.92 4,460.8 4,404.8 -431.8 -3,447.3 6,030,633.53 466,372.50 0.00 3,069.54 6,400.0 69.63 258.92 4,495.6 4,439.6 -449.8 -3,539.3 6,030,615.88 466,280.45 0.00 3,149.15 6,500.0 69.63 258.92 4,530.4 4,474.4 -467.8 -3,631.3 6,030,598.24 466,188.39 0.00 3,228.76 6,600.0 69.63 258.92 4,565.2 4,509.2 -485.8 -3,723.3 6,030,580.60 466,096.33 0.00 3,308.37 6,700.0 69.63 258.92 4,600.0 4,544.0 -503.9 -3,815.3 6,030,562.95 466,004.27 0.00 3,387.98 6,800.0 69.63 258.92 4,634.9 4,578.9 -521.9 -3,907.3 6,030,545.31 465,912.21 0.00 3,467.59 6,900.0 69.63 258.92 4,669.7 4,613.7 -539.9 -3,999.3 6,030,527.67 465,820.15 0.00 3,547.19 7,000.0 69.63 258.92 4,704.5 4,648.5 -557.9 -4,091.3 6,030,510.02 465,728.09 0.00 3,626.80 7,100.0 69.63 258.92 4,739.3 4,683.3 -575.9 -4,183.3 6,030,492.38 465,636.03 0.00 3,706.41 7,200.0 69.63 258.92 4,774.1 4,718.1 -594.0 -4,275.3 6,030,474.74 465,543.97 0.00 3,786.02 7,300.0 69.63 258.92 4,808.9 4,752.9 -612.0 -4,367.3 6,030,457.09 465,451.92 0.00 3,865.63 7,400.0 69.63 258.92 4,843.7 4,787.7 -630.0 -4,459.3 6,030,439.45 465,359.86 0.00 3,945.24 7,500.0 69.63 258.92 4,878.6 4,822.6 -648.0 -4,551.2 6,030,421.81 465,267.80 0.00 4,024.85 9/14/2010 9:08:33AM Page 5 COMPASS 2003.16 Build 428 Halliburton Company HALLI B U RTO'i V Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 Design: ODSN-18 PN11 wp08 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVOss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 4,857.37 7,600.0 69.63 258.92 4,913.4 4,857.4 -666.0 -4,643.2 6,030,404.16 465,175.74 0.00 4,104.46 7,700.0 69.63 258.92 4,948.2 4,892.2 -684.0 -4,735.2 6,030,386.52 465,083.68 0.00 4,184.07 7,800.0 69.63 258.92 4,983.0 4,927.0 -702.1 -4,827.2 6,030,368.87 464,991.62 0.00 4,263.67 7,900.0 69.63 258.92 5,017.8 4,961.8 -720.1 -4,919.2 6,030,351.23 464,899.56 0.00 4,343.28 8,000.0 69.63 258.92 5,052.6 4,996.6 -738.1 -5,011.2 6,030,333.59 464,807.50 0.00 4,422.89 8,100.0 69.63 258.92 5,087.4 5,031.4 -756.1 -5,103.2 6,030,315.94 464,715.45 0.00 4,502.50 8,200.0 69.63 258.92 5,122.3 5,066.3 -774.1 -5,195.2 6,030,298.30 464,623.39 0.00 4,582.11 8,300.0 69.63 258.92 5,157.1 5,101.1 -792.2 -5,287.2 6,030,280.66 464,531.33 0.00 4,661.72 8,400.0 69.63 258.92 5,191.9 5,135.9 -810.2 -5,379.2 6,030,263.01 464,439.27 0.00 4,741.33 8,500.0 69.63 258.92 5,226.7 5,170.7 -828.2 -5,471.2 6,030,245.37 464,347.21 0.00 4,820.94 I 8,600.0 69.63 258.92 5,261.5 5,205.5 -846.2 -5,563.2 6,030,227.73 464,255.15 0.00 4,900.55 8,700.0 69.63 258.92 5,296.3 5,240.3 -864.2 -5,655.2 6,030,210.08 464,163.09 0.00 4,980.15 8,800.0 69.63 258.92 5,331.2 5,275.2 -882.3 -5,747.2 6,030,192.44 464,071.03 0.00 5,059.76 8,848.4 69.63 258.92 5,348.0 5,292.0 -891.0 -5,791.7 6,030,183.90 464,026.49 0.00 5,098.28 9 5/8" 8,900.0 69.63 258.92 5,366.0 5,310.0 -900.3 -5,839.2 6,030,174.80 463,978.97 0.00 5,139.37 8,957.8 69.63 258.92 5,386.1 5,330.1 -910.7 -5,892.4 6,030,164.60 463,925.76 0.00 5,185.39 Begin Directional DLS 3.00 8957.8'MD 9,000.0 69.56 260.27 5,400.8 5,344.8 -917.8 -5,931.3 6,030,157.61 463,886.84 3.00 5,219.22 9,100.0 69.45 263.47 5,435.8 5,379.8 -931.1 -6,024.0 6,030,144.74 463,794.08 3.00 5,301.19 9,200.0 69.40 266.67 5,471.0 5,415.0 -939.1 -6,117.2 6,030,137.08 463,700.80 3.00 5,385.52 9,300.0 69.40 269.88 5,506.2 5,450.2 -941.9 -6,210.8 6,030,134.64 463,607.25 3.00 5,471.97 9,400.0 69.47 273.08 5,541.3 5,485.3 -939.5 -6,304.4 6,030,137.44 463,513.69 3.00 5,560.32 9,500.0 69.59 276.28 5,576.3 5,520.3 -931.9 -6,397.7 6,030,145.46 463,420.38 3.00 5,650.31 9,600.0 69.77 279.47 5,611.0 5,555.0 -919.0 -6,490.6 6,030,158.69 463,327.56 3.00 5,741.70 9,700.0 70.01 282.66 5,645.4 5,589.4 -901.0 -6,582.7 6,030,177.08 463,235.50 3.00 5,834.24 9,800.0 70.31 285.83 5,679.4 5,623.4 -877.9 -6,673.9 6,030,200.59 463,144.45 3.00 5,927.68 9,900.0 70.66 288.99 5,712.8 5,656.8 -849.7 -6,763.8 6,030,229.16 463,054.66 3.00 6,021.75 10,000.0 71.06 292.14 5,745.6 5,689.6 -816.5 -6,852.3 6,030,262.70 462,966.36 3.00 6,116.21 10,100.0 71.52 295.27 5,777.7 5,721.7 -778.4 -6,939.0 6,030,301.12 462,879.82 3.00 6,210.79 10,200.0 72.03 298.38 5,808.9 5,752.9 -735.5 -7,023.7 6,030,344.32 462,795.25 3.00 6,305.23 10,300.0 72.59 301.48 5,839.3 5,783.3 -688.0 -7,106.3 6,030,392.18 462,712.90 3.00 6,399.28 10,400.0 73.20 304.55 5,868.7 5,812.7 -635.9 -7,186.4 6,030,444.57 462,632.99 3.00 6,492.68 10,500.0 73.85 307.60 5,897.1 5,841.1 -579.5 -7,263.9 6,030,501.35 462,555.74 3.00 6,585.17 10,600.0 74.54 310.64 5,924.4 5,868.4 -518.8 -7,338.5 6,030,562.35 462,481.35 3.00 6,676.49 10,606.2 74.59 310.82 5,926.0 5,870.0 -514.9 -7,343.0 6,030,566.26 462,476.85 3.00 6,682.10 Base HRZ 10,700.0 75.28 313.65 5,950.4 5,894.4 -454.0 -7,410.1 6,030,627.41 462,410.05 3.00 6,766.40 10,800.0 76.06 316.64 5,975.1 5,919.1 -385.3 -7,478.4 6,030,696.36 462,342.01 3.00 6,854.66 10,900.0 76.87 319.61 5,998.6 5,942.6 -312.9 -7,543.3 6,030,769.00 462,277.43 3.00 6,941.01 11,000.0 77.71 322.56 6,020.6 5,964.6 -237.0 -7,604.6 6,030,845.13 462,216.48 3.00 7,025.22 11,100.0 78.59 325.49 6,041.1 5,985.1 -157.8 -7,662.0 6,030,924.56 462,159.33 3.00 7,107.07 11,200.0 79.49 328.41 6,060.1 6,004.1 -75.6 -7,715.6 6,031,007.05 462,106.14 3.00 7,186.32 11,254.9 80.00 330.00 6,069.9 6,013.9 -29.1 -7,743.2 6,031,053.56 462,078.67 3.00 7,228.65 End Directional 11254.9'MD 9/14/2010 9:08:33AM Page 6 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 Design: ODSN-18 PN11 wp08 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) 6,021.74 11,300.0 80.00 330.00 6,077.7 6,021.7 9.3 -7,765.4 6,031,092.11 462,056.62 0.00 7,263.06 11,400.0 80.00 330.00 6,095.1 6,039.1 94.6 -7,814.7 6,031,177.59 462,007.73 0.00 7,339.37 11,500.0 80.00 330.00 6,112.5 6,056.5 179.9 -7,863.9 6,031,263.06 461,958.84 0.00 7,415.68 11,554.9 80.00 330.00 6,122.0 6,066.0 226.7 -7,891.0 6,031,310.00 461,932.00 0.00 7,457.58 Begin Directional DLS 3.00 11554.9'MD-Top nuiqsut-7"-18PN11 v7 T1 11,600.0 81.16 330.71 6,129.4 6,073.4 265.4 -7,913.0 6,031,348.74 461,910.16 3.00 7,491.87 11,700.0 83.74 332.26 6,142.5 6,086.5 352.5 -7,960.3 6,031,436.02 461,863.20 3.00 7,567.02 11,800.0 86.32 333.79 6,151.2 6,095.2 441.3 -8,005.5 6,031,524.97 461,818.38 3.00 7,640.77 11,828.9 87.06 334.24 6,152.9 6,096.9 467.2 -8,018.1 6,031,550.96 461,805.85 3.00 7,661.80 End Directional 11828.9'MD 11,900.0 87.06 334.24 6,156.5 6,100.5 531.1 -8,049.0 6,031,615.02 461,775.25 0.00 7,713.35 12,000.0 87.06 334.24 6,161.6 6,105.6 621.1 -8,092.4 6,031,705.13 461,732.21 0.00 7,785.86 12,100.0 87.06 334.24 6,166.8 6,110.8 711.0 -8,135.8 6,031,795.24 461,689.17 0.00 7,858.37 12,200.0 87.06 334.24 6,171.9 6,115.9 801.0 -8,179.2 6,031,885.34 461,646.13 0.00 7,930.87 12,300.0 87.06 334.24 6,177.0 6,121.0 890.9 -8,222.6 6,031,975.45 461,603.09 0.00 8,003.38 12,400.0 87.06 334.24 6,182.1 6,126.1 980.8 -8,266.0 6,032,065.56 461,560.05 0.00 8,075.89 12,500.0 87.06 334.24 6,187.3 6,131.3 1,070.8 -8,309.4 6,032,155.67 461,517.01 0.00 8,148.40 12,500.8 87.06 334.24 6,187.3 6,131.3 1,071.5 -8,309.8 6,032,156.39 461,516.67 0.00 8,148.98 Begin Directional DLS 3.00 12500.8'MD 12,579.8 86.17 336.44 6,192.0 6,136.0 1,143.1 -8,342.7 6,032,228.15 461,484.07 3.00 8,205.16 18PN11 v7 T2 12,594.7 86.00 336.85 6,193.0 6,137.0 1,156.8 -8,348.6 6,032,241.85 461,478.22 3.00 8,215.53 12,600.0 86.16 336.85 6,193.4 6,137.4 1,161.7 -8,350.6 6,032,246.72 461,476.16 3.00 8,219.20 12,700.0 89.16 336.85 6,197.4 6,141.4 1,253.5 -8,389.9 6,032,338.73 461,437.26 3.00 8,288.53 12,728.0 90.00 336.85 6,197.7 6,141.7 1,279.3 -8,400.9 6,032,364.55 461,426.35 3.00 8,307.98 12,800.0 92.16 336.85 6,196.3 6,140.3 1,345.5 -8,429.2 6,032,430.81 461,398.34 3.00 8,357.90 12,861.4 94.00 336.85 6,193.0 6,137.0 1,401.8 -8,453.3 6,032,487.25 461,374.48 3.00 8,400.43 12,900.0 93.84 335.70 6,190.4 6,134.4 1,437.1 -8,468.8 6,032,522.59 461,359.12 3.00 8,427.44 13,000.0 93.41 332.73 6,184.0 6,128.0 1,526.9 -8,512.2 6,032,612.61 461,316.08 3.00 8,499.92 13,059.1 93.15 330.97 6,180.7 6,124.7 1,579.0 -8,540.1 6,032,664.73 461,288.46 3.00 8,544.41 End Directional 13059.1'MD 13,100.0 93.15 330.97 6,178.4 6,122.4 1,614.7 -8,559.9 6,032,700.52 461,268.79 0.00 8,575.61 13,200.0 93.15 330.97 6,172.9 6,116.9 1,702.0 -8,608.3 6,032,788.01 461,220.69 0.00 8,651.90 13,300.0 93.15 330.97 6,167.4 6,111.4 1,789.3 -8,656.8 6,032,875.50 461,172.60 0.00 8,728.19 13,400.0 93.15 330.97 6,161.9 6,105.9 1,876.6 -8,705.2 6,032,963.00 461,124.51 0.00 8,804.47 13,500.0 93.15 330.97 6,156.5 6,100.5 1,963.9 -8,753.7 6,033,050.49 461,076.42 0.00 8,880.76 13,600.0 93.15 330.97 6,151.0 6,095.0 2,051.2 -8,802.1 6,033,137.98 461,028.32 0.00 8,957.05 13,700.0 93.15 330.97 6,145.5 6,089.5 2,138.5 -8,850.6 6,033,225.47 460,980.23 0.00 9,033.34 13,717.2 93.15 330.97 6,144.5 6,088.5 2,153.5 -8,858.9 6,033,240.52 460,971.96 0.00 9,046.46 Begin Directional DLS 3.00 13717.2'MD 13,750.8 93.65 330.10 6,142.5 6,086.5 2,182.7 -8,875.4 6,033,269.78 460,955.59 3.00 9,072.24 18PN11 v7 T5 13,773.9 94.00 329.50 6,141.0 6,085.0 2,202.6 -8,887.0 6,033,289.73 460,944.08 3.00 9,090.14 13,800.0 93.22 329.37 6,139.4 6,083.4 2,225.1 -8,900.3 6,033,312.23 460,930.91 3.04 9,110.51 13,900.0 90.22 328.86 6,136.4 6,080.4 2,310.8 -8,951.6 6,033,398.20 460,879.96 3.04 9,188.91 9/14/2010 9:08:33AM Page 7 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 Design: ODSN-18 PN11 wp08 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) 6,080.35 13,907.2 90.00 328.83 6,136.3 6,080.3 2,317.0 -8,955.3 6,033,404.38 460,876.26 3.04 9,194.59 14,000.0 87.68 326.97 6,138.2 6,082.2 2,395.6 -9,004.6 6,033,483.16 460,827.29 3.20 9,268.57 I 14,067.2 86.00 325.63 6,141.9 6,085.9 2,451.4 -9,041.8 6,033,539.13 460,790.29 3.20 9,323.19 14,100.0 86.00 324.64 6,144.2 6,088.2 2,478.3 -9,060.5 6,033,566.04 460,771.70 3.00 9,350.20 14,200.0 85.99 321.64 6,151.2 6,095.2 2,558.1 -9,120.4 6,033,646.08 460,712.20 3.00 9,434.46 14,300.0 86.00 318.63 6,158.2 6,102.2 2,634.6 -9,184.3 6,033,722.89 460,648.58 3.00 9,521.41 14,400.0 86.01 315.62 6,165.2 6,109.2 2,707.7 -9,252.2 6,033,796.25 460,581.02 3.00 9,610.80 14,500.0 86.04 312.61 6,172.1 6,116.1 2,777.2 -9,323.8 6,033,865.97 460,509.70 3.00 9,702.40 14,600.0 86.08 309.61 6,179.0 6,123.0 2,842.7 -9,398.9 6,033,931.86 460,434.81 3.00 9,795.94 14,700.0 86.13 306.60 6,185.8 6,129.8 2,904.3 -9,477.4 6,033,993.73 460,356.57 3.00 9,891.18 14,800.0 86.19 303.59 6,192.5 6,136.5 2,961.7 -9,559.1 6,034,051.41 460,275.19 3.00 9,987.85 14,900.0 86.26 300.59 6,199.1 6,143.1 3,014.7 -9,643.6 6,034,104.76 460,190.89 3.00 10,085.69 14,919.6 86.27 300.00 6,200.3 6,144.3 3,024.5 -9,660.5 6,034,114.68 460,174.06 3.00 10,104.96 15,000.0 88.68 300.00 6,203.9 6,147.9 3,064.7 -9,730.0 6,034,155.13 460,104.66 3.00 10,184.26 15,043.9 90.00 300.00 6,204.4 6,148.4 3,086.6 -9,768.0 6,034,177.22 460,066.76 3.00 10,227.57 15,100.0 91.68 300.00 6,203.6 6,147.6 3,114.7 -9,816.6 6,034,205.47 460,018.28 3.00 10,282.96 15,177.2 94.00 300.00 6,199.7 6,143.7 3,153.2 -9,883.4 6,034,244.29 459,951.66 3.00 10,359.08 15,193.3 94.24 300.42 6,198.6 6,142.6 3,161.3 -9,897.3 6,034,252.42 459,937.83 2.99 10,374.91 End Directional 15193.3'MD 15,200.0 94.24 300.42 6,198.1 6,142.1 3,164.7 -9,903.0 6,034,255.82 459,932.08 0.00 10,381.50 15,300.0 94.24 300.42 6,190.7 6,134.7 3,215.2 -9,989.0 6,034,306.66 459,846.29 0.00 10,479.82 15,400.0 94.24 300.42 6,183.3 6,127.3 3,265.7 -10,075.0 6,034,357.49 459,760.51 0.00 10,578.14 15,500.0 94.24 300.42 6,175.9 6,119.9 3,316.2 -10,161.0 6,034,408.33 459,674.72 0.00 10,676.46 15,600.0 94.24 300.42 6,168.5 6,112.5 3,366.7 -10,247.0 6,034,459.16 459,588.94 0.00 10,774.78 15,700.0 94.24 300.42 6,161.1 6,105.1 3,417.2 -10,333.0 6,034,509.99 459,503.15 0.00 10,873.10 15,800.0 94.24 300.42 6,153.7 6,097.7 3,467.6 -10,419.0 6,034,560.83 459,417.37 0.00 10,971.43 15,900.0 94.24 300.42 6,146.3 6,090.3 3,518.1 -10,505.0 6,034,611.66 459,331.58 0.00 11,069.75 16,000.0 94.24 300.42 6,138.9 6,082.9 3,568.6 -10,591.0 6,034,662.50 459,245.80 0.00 11,168.07 16,067.6 94.24 300.42 6,133.9 6,077.9 3,602.8 -10,649.2 6,034,696.86 459,187.81 0.00 11,234.54 Begin Directional DLS 3.00 16067.6'MD 16,100.0 94.05 299.46 6,131.6 6,075.6 3,618.9 -10,677.2 6,034,713.10 459,159.87 3.00 11,266.44 16,107.9 94.00 299.23 6,131.0 6,075.0 3,622.8 -10,684.1 6,034,717.00 459,153.00 3.00 11,274.25 18PN11 v7 T11 16,200.0 91.54 300.82 6,126.5 6,070.5 3,668.8 -10,763.7 6,034,763.33 459,073.57 3.18 11,365.02 16,300.0 88.87 302.54 6,126.2 6,070.2 3,721.3 -10,848.8 6,034,816.19 458,988.71 3.18 11,463.21 16,395.2 86.33 304.19 6,130.2 6,074.2 3,773.6 -10,928.2 6,034,868.82 458,909.47 3.18 11,556.07 16,400.0 86.33 304.19 6,130.5 6,074.5 3,776.3 -10,932.2 6,034,871.51 458,905.55 0.00 11,560.69 16,408.0 86.33 304.19 6,131.0 6,075.0 3,780.7 -10,938.7 6,034,876.00 458,899.00 0.00 11,568.42 18PN11 v7 T13 16,494.5 86.64 306.77 6,136.3 6,080.3 3,830.9 -11,009.1 6,034,926.41 458,828.87 3.00 11,651.97 End Directional 16494.5'MD 16,500.0 86.64 306.77 6,136.6 6,080.6 3,834.2 -11,013.5 6,034,929.72 458,824.49 0.01 11,657.25 16,600.0 86.64 306.77 6,142.5 6,086.5 3,893.9 -11,093.4 6,034,989.79 458,744.77 0.00 11,753.22 16,700.0 86.64 306.77 6,148.4 6,092.4 3,953.7 -11,173.4 6,035,049.87 458,665.06 0.00 11,849.19 16,800.0 86.64 306.77 6,154.2 6,098.2 4,013.4 -11,253.4 6,035,109.94 458,585.34 0.00 11,945.16 9/14/2010 9:08:33AM Page 8 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 Design: ODSN-18 PN11 wp08 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) 6,104.10 16,900.0 86.64 306.77 6,160.1 6,104.1 4,073.2 -11,333.3 6,035,170.02 458,505.63 0.00 12,041.13 17,000.0 86.64 306.77 6,166.0 6,110.0 4,132.9 -11,413.3 6,035,230.09 458,425.91 0.00 12,137.10 17,100.0 86.64 306.77 6,171.8 6,115.8 4,192.7 -11,493.3 6,035,290.17 458,346.20 0.00 12,233.07 17,200.0 86.64 306.77 6,177.7 6,121.7 4,252.5 -11,573.2 6,035,350.24 458,266.48 0.00 12,329.04 17,300.0 86.64 306.77 6,183.6 6,127.6 4,312.2 -11,653.2 6,035,410.32 458,186.77 0.00 12,425.01 17,400.0 86.64 306.77 6,189.4 6,133.4 4,372.0 -11,733.2 6,035,470.39 458,107.05 0.00 12,520.98 17,500.0 86.64 306.77 6,195.3 6,139.3 4,431.7 -11,813.1 6,035,530.47 458,027.34 0.00 12,616.95 17,600.0 86.64 306.77 6,201.2 6,145.2 4,491.5 -11,893.1 6,035,590.54 457,947.62 0.00 12,712.92 17,682.3 86.64 306.77 6,206.0 ' 6,150.0 4,540.7 -11,958.9 6,035,639.99 457,882.02 0.00 12,791.91 TD at 17682.3'MD-18PN11 v7 714 9/14/2010 9:08:33AM Page 9 COMPASS 2003.16 Build 428 Halliburton Company HHALLIBURTOle Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.5+13.5'@ 56.0ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.5+13.5'@ 56.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 Design: ODSN-18 PN11 wp08 Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +NI-S +E/-W Northing Easting -Shape (?) (?) (ft) (ft) (ft) (ft) (ft) PN11 v2 T3 0.00 0.00 6,056.0 4,206.7 -11,452.5 6,035,304.00 458,387.00 -plan misses by 119.6ft at 17069.0ft MD(6170.0 TVD,4174.2 N,-11468.5 E) -Point 18PN11 v7T13 0.00 0.00 6,131.0 3,780.7 -10,938.7 6,034,876.00 458,899.00 -plan hits target -Point 18PN11 v5 T1 0.00 0.00 6,129.0 -3.2 -7,631.0 6,031,079.00 462,191.00 -plan misses by 127.3ft at 11230.8ft MD(6065.7 TVD,-49.6 N,-7731.2 E) -Point 18PN11 v7 T2 0.00 0.00 6,193.0 1,166.2 -8,291.8 6,032,251.00 461,535.00 -plan misses by 55.8ft at 12580.9ft MD(6192.1 TVD,1144.1 N,-8343.1 E) -Point 18PN11 v7 T6 0.00 0.00 6,136.0 2,316.7 -8,942.6 6,033,404.00 460,889.00 -plan misses by 10.7ft at 13900.3ft MD(6136.4 TVD,2311.1 N,-8951.7 E) -Point 18PN11 v7 T14 0.00 0.00 6,206.0 4,540.7 -11,958.9 6,035,640.00 457,882.00 -plan hits target -Point 18PN11 v7 T12 0.00 0.00 6,126.0 3,696.2 -10,815.4 6,034,791.00 459,022.00 -plan misses by 3.4ft at 16258.4ft MD(6125.8 TVD,3699.1 N,-10813.6 E) -Point 18PN11 v7 T8 0.00 0.00 6,201.0 3,015.7 -9,686.5 6,034,106.00 460,148.00 -plan misses by 20.6ft at 14937.7ft MD(6201.4 TVD,3033.6 N,-9676.2 E) -Point 18PN11 v7 T10 0.00 0.00 6,201.0 3,198.8 -9,922.2 6,034,290.00 459,913.00 1 -plan misses by 20.4ft at 15233.5ft MD(6195.6 TVD,3181.6 N,-9931.9 E) 1 -Point 18PN11 v7 T3 0.00 0.00 6,198.0 1,304.0 -8,351.4 6,032,389.00 461,476.00 -plan misses by 55.3ft at 12731.2ft MD(6197.6 TVD,1282.2 N,-8402.2 E) -Point 18PN11 v5 Nuiq Poly 0.00 0.00 6,127.0 -3.2 -7,631.0 6,031,079.00 462,191.00 -plan misses by 126.3ft at 11230.4ft MD(6065.6 TVD,-50.0 N,-7731.1 E) -Polygon Point 1 6,127.0 -4.3 -7,523.2 6,031,077.46 462,298.78 Point 2 6,127.0 -41.6 -7,663.7 6,031,040.74 462,158.15 Point3 6,127.0 622.1 -8,339.0 6,031,707.11 461,485.62 Point4 6,127.0 923.5 -7,893.9 6,032,006.67 461,931.89 Points 6,127.0 75.1 -7,535.8 6,031,156.90 462,286.51 Point 6 6,127.0 75.1 -7,535.8 6,031,156.90 462,286.51 Point 7 6,127.0 75.1 -7,535.8 6,031,156.90 462,286.51 18PN11 v7 T5 0.00 0.00 6,141.0 2,188.0 -8,866.0 6,033,275.00 460,965.00 -plan misses by 10.9ft at 13750.8ft MD(6142.5 TVD,2182.7 N,-8875.4 E) -Point 18PN11 v7-11 0.00 0.00 6,131.0 3,622.8 -10,684.1 6,034,717.00 459,153.00 I -plan hits target -Point PN11 v2 71 0.00 0.00 6,098.0 -201.6 -7,458.2 6,030,880.00 462,363.00 -plan misses by 163.5ft at 10954.3ft MD(6010.7 TVD,-272.2 N,-7577.0 E) -Point 18PN11 v7 T7 0.00 0.00 6,141.0 2,435.3 -9,034.1 6,033,523.00 460,798.00 -plan misses by 2.6ft at 14049.5ft MD(6140.8 TVD,2436.8 N,-9031.9 E) 9/14/2010 9:08:33AM Page 10 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTOI ii Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 Design: ODSN-18 PN11 wp08 -Point 18PN11 v5 HRZ Poly 0.00 0.00 5,921.2 -3.2 -7,631.0 6,031,079.00 462,191.00 -plan misses by 177.8ft at 11187.8ft MD(6057.9 TVD,-85.8 N,-7709.3 E) -Polygon Point 1 5,921.2 -831.0 -7,391.1 6,030,250.32 462,427.51 Point 2 5,921.2 233.7 -7,602.8 6,031,315.76 462,220.16 Point 3 5,921.2 864.4 -7,860.0 6,031,947.43 461,965.55 Point 4 5,921.2 749.9 -8,208.4 6,031,834.36 461,616.72 Point 5 5,921.2 166.4 -7,932.6 6,031,249.81 461,890.12 Point 6 5,921.2 -860.3 -7,655.0 6,030,222.09 462,163.52 18PN11 v7 T1 0.00 0.00 6,122.0 226.7 -7,891.0 6,031,310.00 461,932.00 -plan hits target -Point 18PN11 v7 T4 0.00 0.00 6,193.0 1,436.7 -8,420.9 6,032,522.00 461,407.00 -plan misses by 43.6ft at 12880.2ft MD(6191.7 TVD,1419.1 N,-8460.8 E) -Point 18PN11 v7 T9 0.00 0.00 6,206.0 3,114.3 -9,798.9 6,034,205.00 460,036.00 -plan misses by 8.8ft at 15084.4ft MD(6204.0 TVD,3106.9 N,-9803.1 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 3,497.8 3,240.0 11 3/4" 11.750 14.500 8,848.4 5,348.0 9 5/8" 9.625 11.750 11,554.9 6,122.0 7" 7.000 8.500 17,791.5 4 1/2" 4.500 6.125 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (?) (') 11,554.9 6,122.0 Top nuiqsut 0.00 10,606.2 5,926.0 Base HRZ 0.00 9/14/2010 9:08:33AM Page 11 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTO`v Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-18 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-18 PN11 Design: ODSN-18 PN11 wp08 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W III (ft) (ft) (ft) (ft) Comment 300.0 300.0 0.0 0.0 KOP Begin Directional 1.00 300.0'MD 1,662.8 1,650.0 0.7 -7.8 End Directional 1662.8'MD 2,165.7 2,138.7 2.0 -21.8 Begin Directional DLS 3.00 2165.7'MD 3,154.9 3,000.0 14.7 -160.6 Start DLS 1.50 'MD 4,970.3 3,997.8 16.9 -184.8 End Directional 4970.3 4970.3'MD 8,957.8 5,386.1 23.4 -255.2 Begin Directional DLS 3.00 8957.8'MD 11,254.9 6,069.9 25.5 -278.6 End Directional 11254.9'MD 11,554.9 6,122.0 14.5 -742.2 Begin Directional DLS 3.00 11554.9'MD 11,828.9 6,152.9 -192.2 -2,224.0 End Directional 11828.9'MD 12,500.8 6,187.3 -910.7 -5,892.3 Begin Directional DLS 3.0012500.8'MD 13,059.1 6,180.7 -29.1 -7,743.2 End Directional 13059.1 'MD 13,717.2 6,144.5 226.7 -7,891.0 Begin Directional DLS 3.00 13717.2'MD 15,193.3 6,198.6 467.2 -8,018.1 End Directional 15193.3'MD 16,067.6 6,133.9 1,071.5 -8,309.8 Begin Directional DLS 3.00 16067.6'MD 16,494.5 6,136.3 1,156.8 -8,348.6 End Directional 16494.5'MD 17,682.3 6,206.0 1,279.3 -8,400.9 TD at 17682.3'MD 9/14/2010 9:08:33AM Page 12 COMPASS 2003.16 Build 428 0 U c E.D. n 9 EE d M M Z Z O '_ i 4.. ° 0 as C) to o G Yf-I-, - - � �` �oa s `s s sss� ��� \ � $,r f .r ir .i1ik' a7 : ri:' i 1, 1' ��--1 o oo�ryimma-o do ; m 0o C y b/,•�r ;'� i ,711..' 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M �/ii0*el�.`rriV.4�� ,� �Vi ffei �% . ° d O c wo R' u 0..co 00 00 00 0o M �„ac4.�a.�,, a�'��®��z Ii �I11/ h % '. ° LL 3 v m v a .o CA "Z.Z Z Z Z lo��1_y��'s�e;t .•A. 44- .141.,,A; ►. a alter v0 w u u u u Ti N of .'.rn.nrnrn \�. , = 'Sfrf, �l t> X s zw E e Q rn •o Nl9�`4_4-41.0.4$1' _'r�i6r , ar= hu. d d m c z r N For;ao N ♦ ♦S �A. i�f, z g,-o j��-��Tti1 Nu y U o ♦����� O E•1,0.0 a a N >N d O •• • O fn t1.R 00•a k 0 O o k, ovoo v, Z a N M00^ +O n. o p N Halliburton Company Anticollision Summary Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.5+13.5'@ 56.0ft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Site Error: 0.0ft North Reference: True Reference Well: ODSN-18 Survey Calculation Method: Minimum Curvature Well Error: 0.Oft Output errors are at 2.00 sigma Reference Wellbore ODSN-18 PN11 Database: .Pioneer Alaska Reference Design: ODSN-18 PN11 wp08 Offset ND Reference: Offset Datum Reference ODSN-18 PN11 wp08 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.0ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,964.0ft Error Surface: Elliptical Conic Warning Levels Evaluated at: 0.00 Sigma Survey Tool Program Date 9/14/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description 42.5 2,000.0 ODSN-18 PN11 wp08(ODSN-18 PN11) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 2,000.0 3,497.8 ODSN-18 PN11 wp08(ODSN-18 PN11) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 3,497.8 8,848.4 ODSN-18 PN11 wp08(ODSN-18 PN11) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 8,848.4 11,554.9 ODSN-18 PN11 wp08(ODSN-18 PN11) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11,554.9 17,682.3 ODSN-18 PN11 wp08(ODSN-18 PN11) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/14/2010 9:00:14AM Page 2 COMPASS 2003.16 Build 428 Halliburton Company Anticollision Summary Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.5+13.5'@ 56.0ft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.5+13.5'@ 56.0ft(Nabors 19AC) Site Error: 0.0ft North Reference: True Reference Well: ODSN-18 Survey Calculation Method: Minimum Curvature Well Error: 0.0ft Output errors are at 2.00 sigma Reference Wellbore ODSN-18 PN11 Database: .Pioneer Alaska Reference Design: ODSN-18 PN11 wp08 Offset TVD Reference: Offset Datum Summary Reference Offset Distance Measured Measured Between Between Site Name Depth Depth Centres Ellipses Separation Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Factor Warning Ooguruk Offset Wells Kalubik#1-Kalubik#1-Kalubik#1 6,362.0 4,475.0 255.6 113.8 1.802 CC,ES,SF Oooguruk Drill Site ODSDW1-44-ODSDWI-44 Disposal-ODSDW1-44 Dis 474.6 475.0 40.2 32.0 4.918 CC ODSDW1-44-ODSDWI-44 Disposal-ODSDW1-44 Dis 674.1 675.0 41.6 30.1 3.616 ES,SF ODSK-13i-KUP C lateral PKI-ODSK-13 PK1 wp14 349.6 350.0 33.9 27.5 5.306 CC ODSK-13i-KUP C lateral PK1-ODSK-13 PK1 wp14 449.2 450.0 34.6 26.6 4.328 ES,SF li ODSK-13i-ODSK-13i KupH-ODSK-13 PK1 PH wp06 349.6 350.0 33.9 27.5 5.306 CC ODSK-13i-ODSK-13i KupH-ODSK-13 PK1 PH wp06 449.2 450.0 34.6 26.6 4.328 ES,SF ODSK-13i-ODSK-13i KupH-ODSK-13i KupH 349.6 350.0 33.9 27.5 5.306 CC ODSK-13i-ODSK-13i KupH-ODSK-13i KupH 449.2 450.0 34.6 26.6 4.328 ES,SF ODSK-14-ODSK-14-ODSK-14 KupB 299.8 300.0 27.1 21.4 4.806 CC ODSK-14-ODSK-14-ODSK-14 KupB 399.5 400.0 27.9 20.5 3.758 ES,SF ODSK-14-ODSK-14 PBI-ODSK-14 PB1 KupB 299.8 300.0 27.1 21.4 4.806 CC ODSK-14-ODSK-14 PB1-ODSK-14 PB1 KupB 399.5 400.0 27.9 20.5 3.758 ES,SF ODSK-14-ODSK-14 PB2-ODSK-14 PB2 KupB 299.8 300.0 27.1 21.4 4.806 CC ODSK-14-ODSK-14 PB2-ODSK-14 PB2 KupB 399.5 400.0 27.9 20.5 3.758 ES,SF ODSK-33-ODSK-33 KupA-ODSK-33 KupA 2,248.0 2,275.0 75.8 29.3 1.629 CC ODSK-33-ODSK-33 KupA-ODSK-33 KupA 2,296.8 2,325.0 76.4 28.9 1.608 ES,SF ODSK-33-ODSK-33 PB1 KupA-ODSK-33 PB1 KupA 2,248.0 2,275.0 75.8 29.3 1.629 CC ODSK-33-ODSK-33 PB1 KupA-ODSK-33 PB1 KupA 2,296.8 2,325.0 76.4 28.9 1.608 ES,SF ODSK-35Ai-ODSK-35 KupB-ODSK-35 KupB Surveys 149.8 150.0 68.0 65.3 24.955 CC ODSK-35Ai-ODSK-35 KupB-ODSK-35 KupB Surveys 398.7 400.0 69.3 62.3 9.924 ES,SF ODSK-35Ai-ODSK-35Ai-ODSK-35Ai KupH Surveys 149.8 150.0 68.0 65.3 24.955 CC ODSK-35Ai-ODSK-35Ai-ODSK-35Ai KupH Surveys 398.7 400.0 69.3 62.3 9.924 ES,SF ODSK-38i-ODSK-38i KupD-ODSK-38i KupD Surveys 348.1 350.0 41.7 35.5 6.669 CC ODSK-38i-ODSK-38i KupD-ODSK-38i KupD Surveys 397.8 400.0 42.2 35.0 5.922 ES,SF ODSK-41-ODSK-41 KupF-ODSK-41 KupF Surveys 323.4 325.0 32.2 26.2 5.385 CC ODSK-41-ODSK-41 KupF-ODSK-41 KupF Surveys 398.0 400.0 32.8 25.6 4.531 ES,SF ODSK-41-ODSK-41 PB1 KupF-ODSK-41 PB1 KupF 323.4 325.0 32.2 26.1 5.306 CC ODSK-41-ODSK-41 PB1 KupF-ODSK-41 PB1 KupF 398.0 400.0 32.8 25.5 4.476 ES,SF ODSK-42i-ODSK-42Ai-ODSK-42Ai 324.7 325.0 31.6 25.6 5.294 CC ODSK-42i-ODSK-42Ai-ODSK-42Ai 424.3 425.0 32.4 24.7 4.189 ES,SF ODSK-42i-ODSK-42i KupG-ODSK-42i KupG 324.7 325.0 31.6 25.6 5.258 CC ODSK-42i-ODSK-42i KupG-ODSK-42i KupG 424.3 425.0 32.4 24.6 4.166 ES,SF ODSN-1 -ODSN-1 -ODSDW2-1 Disposal wp05 299.8 300.0 141.0 135.4 25.332 CC ODSN-1-ODSN-1 -ODSDW2-1 Disposal wp05 349.0 350.0 141.3 134.9 21.918 ES,SF ODSN-10-ODSN-10 PS12-ODSN-10 PS12 wp11 -6K 299.8 300.0 67.0 61.3 11.847 CC ODSN-10-ODSN-10 PS12-ODSN-10 PS12 wp11 -6K 448.7 450.0 68.2 59.9 8.213 ES,SF ODSN-11i-ODSN-11i IS11 -ODSN-11i IS11 wp09 299.8 300.0 60.0 54.4 10.775 CC ODSN-11i-ODSN-11i IS11 -ODSN-11i IS11 wp09 523.3 525.0 62.0 52.5 6.556 ES,SF ODSN-12-ODSN-12 PS10-ODSN-12 PS10 wp13-8K 299.8 300.0 53.0 47.3 9.439 CC ODSN-12-ODSN-12 PS10-ODSN-12 PS10 wp13-8K 473.7 475.0 54.6 45.9 6.291 ES,SF ODSN-15i-ODSN-15i-ODSN-15i IN12 274.8 275.0 19.6 14.3 3.745 CC ODSN-15i-ODSN-15i-ODSN-15i IN12 349.6 350.0 20.3 13.7 3.082 ES,SF ODSN-16-ODSN-16-ODSN-16 PN13 Surveys 324.7 325.0 13.1 7.2 2.195 CC ODSN-16-ODSN-16-ODSN-16 PN13 Surveys 374.7 375.0 13.6 6.8 1.983 ES,SF ODSN-16-ODSN-16-ODSN-16 PN13 wp11 324.7 325.0 13.1 7.2 2.195 CC , ODSN-16-ODSN-16-ODSN-16 PN13 wp11 374.7 375.0 13.6 6.8 1.983 ES,SF ODSN-16-ODSN-16L1 -ODSN-16L1 PN13 324.7 325.0 13.1 7.2 2.195 CC ODSN-16-ODSN-16L1-ODSN-16L1 PN13 374.7 375.0 13.6 6.8 1.983 ES,SF ODSN-16-ODSN-16L1-ODSN-16L1 PN13 wp10 324.7 325.0 13.1 7.2 2.195 CC ODSN-16-ODSN-16L1-ODSN-16L1 PN13 wp10 374.7 375.0 13.6 6.8 1.983 ES,SF CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/14/2010 9:00:14AM Page 3 COMPASS 2003.16 Build 428 Halliburton Company Anticollision Summary Report Company: Well Planning-Pioneer-000guruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: 000guruk Development TVD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Reference Site: 000guruk Drill Site MD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Site Error: 0.0ft North Reference: True Reference Well: ODSN-18 Survey Calculation Method: Minimum Curvature Well Error: 0.0ft Output errors are at 2.00 sigma Reference Wellbore ODSN-18 PN11 Database: .Pioneer Alaska Reference Design: ODSN-18 PN11 wp08 Offset TVD Reference: Offset Datum Summary Reference Offset Distance Measured Measured Between Between Site Name Depth Depth Centres Ellipses Separation Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Factor Warning 000guruk Drill Site ODSN-17-ODSN-17 PN13 mid-ODSN-17 PN13 mid 42.5 42.7 7.0 5.9 6.404 CC ODSN-17-ODSN-17 PN13 mid-ODSN-17 PN13 mid 349.7 350.0 9.7 3.2 1.499 ES,SF ODSN-17-ODSN-17 PN13 mid-ODSN-17 PN13 mid w 199.8 200.0 7.0 3.2 1.852 CC ODSN-17-ODSN-17 PN13 mid-ODSN-17 PN13 mid w 349.7 350.0 7.6 1.3 1.205 ES,SF ODSN-17-ODSN-17 PN13 mid L1-ODSN-17 PN13 mi 199.8 200.0 7.0 3.2 1.852 CC ODSN-17-ODSN-17 PN13 mid L1-ODSN-17 PN13 mi 349.7 350.0 7.6 1.3 1.205 ES,SF ODSN-18-ODSN-18 PN11 L1 -ODSN-18 PN11 L1 wp0 11,724.8 11,725.0 0.3 -0.2 0.599 CC,ES,SF ODSN-19-ODSDW2-19 Disposal-ODSDW2-19 Dispos 224.8 225.0 18.0 13.8 4.320 CC ODSN-19-ODSDW2-19 Disposal-ODSDW2-19 Dispos 801.1 800.0 21.7 7.2 1.495 ES,SF ODSN-2-ODSN-2 PS1-ODSN-2 PS1 wp08 299.8 300.0 134.0 128.3 23.697 CC ODSN-2-ODSN-2 PS1-ODSN-2 PS1 wp08 423.0 425.0 134.9 127.0 17.177 ES,SF ODSN-20-ODSN-20i SW3-ODSN-20i SW3 wp01 249.8 250.0 25.0 20.3 5.300 CC ODSN-20-ODSN-20i SW3-ODSN-20i SW3 wp01 299.8 300.0 25.5 19.9 4.539 ES,SF ODSN-21-ODSN-21 PS13-ODSN-21 PS13 wp07 TES 700.7 700.0 27.9 15.4 2.222 CC ODSN-21-ODSN-21 PS13-ODSN-21 PS13 wp07 TES 825.8 825.0 29.0 14.2 1.959 ES,SF ODSN-22i-ODSN-22i IS14-ODSN-22i IS14 wp02 299.8 300.0 39.0 33.4 6.906 CC ODSN-22i-ODSN-22i IS14-ODSN-22i IS14 wp02 827.0 825.0 43.6 28.7 2.923 ES,SF ODSN-23i-ODSN-23i IS16-ODSN-23i IS16 wp02 299.8 300.0 46.1 40.4 8.147 CC ODSN-23i-ODSN-23i IS16-ODSN-23i IS16 wp02 651.6 650.0 48.2 36.6 4.150 ES,SF ODSN-25-ODSN-25-ODSN-25 NE4 wp02 298.5 300.0 144.7 139.1 25.695 CC ODSN-25-ODSN-25-ODSN-25 NE4 wp02 347.5 350.0 145.1 138.6 22.410 ES,SF ODSN-26-ODSN-26 PN1 -ODSN-26 PN1 wp06 299.8 300.0 137.9 132.2 24.390 CC ODSN-26-ODSN-26 PN1-ODSN-26 PN1 wp06 397.9 400.0 138.6 131.1 18.685 ES,SF ODSN-27i-ODSN-27i IN2-ODSN-27i IN2 wp06 299.8 300.0 131.1 125.4 23.184 CC ODSN-27i-ODSN-27i IN2-ODSN-27i IN2 wp06 422.5 425.0 132.1 124.3 16.830 ES,SF ODSN-28-ODSN-28 PN3-ODSN-28 PN3 wp07.a 299.8 300.0 124.3 118.7 21.994 CC ODSN-28-ODSN-28 PN3-ODSN-28 PN3 wp07.a 348.9 350.0 124.7 118.2 19.222 ES,SF ODSN-29i-ODSN-29i IN4-ODSN-29i IN4 wp06 299.8 300.0 117.6 112.0 20.806 CC ODSN-29i-ODSN-29i IN4-ODSN-29i IN4 wp06 398.1 400.0 118.3 110.9 15.950 ES,SF ODSN-30-ODSN-30 PN5-ODSN-30 PN5 wp05 299.8 300.0 110.9 105.2 19.616 CC ODSN-30-ODSN-30 PN5-ODSN-30 PN5 wp05 422.8 425.0 112.0 104.1 14.260 ES,SF ODSN-31-ODSN-31-ODSN-31 PN6 Surveys 299.8 300.0 93.6 87.9 16.687 CC ODSN-31-ODSN-31-ODSN-31 PN6 Surveys 373.8 375.0 94.1 87.3 13.842 ES,SF ODSN-31 -ODSN-31 PB1 -ODSN-31 PB1 PN6 Surveys 299.8 300.0 93.6 87.9 16.687 CC ODSN-31-ODSN-31 PB1 -ODSN-31PB1 PN6 Surveys 373.8 375.0 94.1 87.3 13.842 ES,SF ODSN-32i-ODSN-32i IN7-ODSN-32i IN7 Surveys 149.8 150.0 86.9 84.1 31.334 CC ODSN-32i-ODSN-32i IN7-ODSN-32i IN7 Surveys 423.1 425.0 87.9 80.3 11.589 ES,SF ODSN-32i-ODSN-32iPB1 IN7-ODSN-32iPB1 IN7 149.8 150.0 86.9 84.1 31.334 CC ODSN-32i-ODSN-32iPB1 IN7-ODSN-32iPB1 IN7 423.1 425.0 87.9 80.3 11.589 ES,SF ODSN-34i-ODSN-34 IN9-ODSN-34i IN9 Surveys 299.8 300.0 73.0 67.4 13.075 CC ODSN-34i-ODSN-34 IN9-ODSN-34i IN9 Surveys 373.9 375.0 73.5 66.7 10.852 ES,SF ODSN-34i-ODSN-34i PB2-ODSN-34iPB2 IN9 299.8 300.0 73.0 67.4 13.075 CC ODSN-34i-ODSN-34i PB2-ODSN-34iPB2 IN9 373.9 375.0 73.5 66.7 10.852 ES,SF ODSN-34i-ODSN-34i PB3-ODSN-34iPB3 IN9 299.8 300.0 73.0 67.4 13.075 CC ODSN-34i-ODSN-34i PB3-ODSN-34iPB3 IN9 373.9 375.0 73.5 66.7 10.852 ES,SF ODSN-34i-ODSN-34iPB1-ODSN-34iPB1 IN9 299.8 300.0 73.0 67.4 13.075 CC ODSN-34i-ODSN-34iPB1-ODSN-34iPB1 IN9 373.9 375.0 73.5 66.7 10.852 ES,SF ODSN-36-ODSN-36 PB1 -ODSN-36 PB1 PN10 124.8 125.0 62.2 59.9 27.135 CC ODSN-36-ODSN-36 PB1 -ODSN-36 PB1 PN10 324.5 325.0 62.7 57.0 10.935 ES,SF ODSN-36-ODSN-36 PB2-ODSN-36 PB2 PN10 124.8 125.0 62.2 59.9 27.135 CC ODSN-36-ODSN-36 PB2-ODSN-36 PB2 PN10 324.5 325.0 62.7 57.0 10.935 ES,SF ODSN-36-ODSN-36 PN10-ODSN-36 PN10 Surveys 124.8 125.0 62.2 59.9 27.135 CC ODSN-36-ODSN-36 PN10-ODSN-36 PN10 Surveys 324.5 325.0 62.7 57.0 10.935 ES,SF CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/14/2010 9:00:14AM Page 4 COMPASS 2003.16 Build 428 Halliburton Company Anticollision Summary Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.5'+13.5'@ 56.0ft(Nabors 19AC) Site Error: 0.0ft North Reference: True Reference Well: ODSN-18 Survey Calculation Method: Minimum Curvature Well Error: 0.0ft Output errors are at 2.00 sigma Reference Wellbore ODSN-18 PN11 Database: .Pioneer Alaska Reference Design: ODSN-18 PN11 wp08 Offset TVD Reference: Offset Datum Summary Reference Offset Distance Measured Measured Between Between Site Name Depth Depth Centres Ellipses Separation Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Factor Warning Oooguruk Drill Site ODSN-37-ODSN-37-ODSN-37 PN8 349.4 350.0 46.6 40.3 7.320 CC ODSN-37-ODSN-37-ODSN-37 PN8 399.0 400.0 47.0 39.9 6.556 ES,SF ODSN-3i-ODSDW-2 Wp01-ODSDW-2 wp01 224.8 225.0 127.0 123.0 32.149 CC ODSN-3i-ODSDW-2 Wp01-ODSDW-2 wp01 349.1 350.0 128.0 121.8 20.521 ES,SF ODSN-3i-ODSN-3i IS2-ODSN-3i IS2 wp08 299.8 300.0 127.0 121.3 22.460 CC ODSN-3i-ODSN-3i IS2-ODSN-3i IS2 wp08 447.7 450.0 128.2 119.9 15.457 ES,SF ODSN-4-ODSN-4 PS3-ODSN-4 PS3 wp07 299.8 300.0 120.0 114.3 21.228 CC ODSN-4-ODSN-4 PS3-ODSN-4 PS3 wp07 398.5 400.0 121.0 113.6 16.304 ES,SF ODSN-40-ODSN-40 PN12-ODSN-40 PN12 Surveys 298.5 300.0 35.1 29.6 6.319 CC ODSN-40-ODSN-40 PN12-ODSN-40 PN12 Surveys 348.2 350.0 35.6 29.2 5.533 ES,SF ODSN-40-ODSN-40PB1 PN12-ODSN-40PB1 PN12 298.5 300.0 35.1 29.7 6.421 CC ODSN-40-ODSN-40PB1 PN12-ODSN-40PB1 PN12 348.2 350.0 35.6 29.3 5.610 ES,SF ODSN-40-ODSN-40PB2 PN12-ODSN-40PB2 PN12 298.5 300.0 35.1 29.6 6.319 CC ODSN-40-ODSN-40PB2 PN12-ODSN-40PB2 PN12 348.2 350.0 35.6 29.2 5.533 ES,SF ODSN-43-ODSN-43 PS15-ODSN-43 PS15 wp04 224.8 225.0 37.3 33.1 8.780 CC ODSN-43-ODSN-43 PS15-ODSN-43 PS15 wp04 324.7 325.0 38.1 32.2 6.453 ES,SF ODSN-45-ODSN-45A-ODSN-45A Surveys 42.5 42.7 45.7 44.7 41.805 CC ODSN-45-ODSN-45A-ODSN-45A Surveys 324.8 325.0 48.1 41.9 7.783 ES,SF ODSN-45-ODSN-45i PB1 IN13-ODSN-45i PB1 IN13 42.5 42.7 45.7 44.7 41.805 CC ODSN-45-ODSN-45i PB1 IN13-ODSN-45i PB1 IN13 324.8 325.0 48.1 41.9 7.783 ES,SF ODSN-48-ODSN-48i IN14-ODSN-48i IN14 wp07 224.8 225.0 62.3 58.1 14.658 CC I ODSN-48-ODSN-48i IN14-ODSN-48i IN14 wp07 324.8 325.0 63.0 57.1 10.621 ES,SF I ODSN-5i-ODSN-5i IS4-ODSN-5i IS4 wp08 299.8 300.0 113.0 107.3 19.984 CC ODSN-5i-ODSN-5i IS4-ODSN-5i IS4 wp08 423.2 425.0 113.8 106.0 14.485 ES,SF ODSN-6-ODSN-6 PS5-ODSN-6 PS5 wp09 299.8 300.0 106.0 100.3 18.748 CC ODSN-6-ODSN-6 PS5-ODSN-6 PS5 wp09 398.6 400.0 106.8 99.4 14.403 ES,SF ODSN-7i-ODSN-7i IS7-ODSN-7i IS7 wp08 299.8 300.0 88.0 80.3 11.513 CC ODSN-7i-ODSN-7i IS7-ODSN-7i IS7 wp08 522.5 525.0 90.8 77.2 6.651 ES,SF ODSN-8-ODSN-8 PS8-ODSN-8 PS8 wp08-8K'Horiz 299.8 300.0 81.0 75.4 14.551 CC ODSN-8-ODSN-8 PS8-ODSN-8 PS8 wp08-8K'Horiz 448.4 450.0 82.3 74.1 10.021 ES,SF ODSN-9i-ODSN-9i IS9-ODSN-9i IS9 wp11 -8K'Horiz 299.8 300.0 73.9 67.8 12.068 CC ODSN-9i-ODSN-9i IS9-ODSN-9i IS9 wp11 -8K'Horiz 473.4 475.0 75.6 66.0 7.840 ES,SF ODST-39-ODSN-39i IN11-ODSN-39i IN11 124.8 125.0 38.9 36.6 16.970 CC ODST-39-ODSN-39i IN11-ODSN-39i!Nil 349.5 350.0 39.5 33.1 6.166 ES,SF ODST-39-ODST-39i Torok D-ODST-39 Torok D wp08 124.8 125.0 38.9 36.6 16.970 CC ODST-39-ODST-39i Torok D-ODST-39 Torok D wp08 349.5 350.0 39.5 33.1 6.166 ES,SF ODST-46i-ODST-46i Torok C-ODST-46i Torok C wp03 149.8 150.0 50.9 48.1 18.131 CC ODST-46i-ODST-46i Torok C-ODST-46i Torok C wp03 199.8 200.0 51.2 47.4 13.666 ES,SF ODST-47-ODST-47 Torok B-ODST-47 Torok B wp11 174.8 175.0 56.5 53.3 17.260 CC ODST-47-ODST-47 Torok B-ODST-47 Torok B wp11 224.8 225.0 57.1 52.9 13.551 ES,SF CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/14/2010 9:00:14AM Page 5 COMPASS 2003.16 Build 428 Halliburton Company Anticollision Summary Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.5+13.5 @ 56.0ft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.5+13.5 @ 56.0ft(Nabors 19AC) Site Error: 0.0ft North Reference: True Reference Well: ODSN-18 Survey Calculation Method: Minimum Curvature Well Error: 0.0ft Output errors are at 2.00 sigma Reference Wellbore ODSN-18 PN11 Database: .Pioneer Alaska Reference Design: ODSN-18 PN11 wp08 Offset ND Reference: Offset Datum Reference Depths are relative to 42.5'+13.5 @ 56.Oft(Nabors 19AC) Coordinates are relative to:ODSN-18-Slot ODS-18 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:-0.23? Ladder Plot 1 2000 '� I ;'1 / -- .\ I 111 w1 / is III r 1 i t ,�' / ,/• 0,4 i ::: 1 fi ,/ rl Ij i�' I A '' /4 ; 0 ii f , hiffr,cAlor. z, o ,li ', /4:0 • 44 yt: ,, 500 • {� 1 arae! '3 4, 1 '4 I rte_. ILEGEND _ 1 J . J A ;" ODSN-16,ODS -16L1,ObSN-16L PN13 wp10 VO 1 OsSN-36,ODSN-36 P3' 9W1-44 Disp s.__ . "• ' ODSN-17,ODS -17 PN13 mid,OD N-17 PN13 mid V'. -X- OcISN-36,ODS'4-36 P3: 8- <1 wp14 VO 0 3009)DSN-17,OD X1,7 PN13 mid L N13 mid, � DSN-P7 PN13N13 lm:l L I wpO2rfVO i�U ODSN-37, -37, OC FH wp06 VO tiDSN-17,OD 'N�7 1n��i r�t{ ❑❑t}hh )H VO -4- ODSN-18,ODSN-18 PN11 L'Te81l=18"PfVT9'L1 wp02 VO -6- ODSN-3i, ODSDW-2 Wp .40. nncia_ic nncnW9-1Q nicp oo1,nn9nln/9--19 r" 'w-,na v l c n$N-3c nncN-Zi IS: urB VO -0- ODSN-2, ODSN-2 PS1,ODSN-2 PS1 wp08 VO -0- ODSN-4,ODSN-4 PS3, ur B VO ODSN-20,ODSN-20i SW3,ODSN-20i SW3 wp01 VO $ ODSN-40,ODSN-40 PN' .\,0 -X- ODSN-21,ODSN-21 PS13,ODSN-21 PS13 wp07 TEST VO -F ODSN-40,ODSN-40PB1 'B1 KupA VO -6- ODSN-22i,ODSN-22i 1S14,ODSN-22i IS14 wp02 VO $- ODSN-40,ODSN-40PB2 )E Surveys VO 44- ODSN-23i,ODSN-23i IS16,ODSN-23i IS16 wp02 VO $ ODSN-43,ODSN-43 PS' Surveys VO $ ODSN-25,ODSN-25,ODSN-25 NE4 wp02 VO ODSN-45,ODSN-45A,C ID Surveys V0 ner ODSN-26,ODSN-26 PN1,ODSN-26 PN1 wp06 VO -9- ODSN-45,ODSN-45i F B aurveys VO ODSN-27i,ODSN-27i 1N2,ODSN-27i 1N2 wp06 VO w ODSN-48,ODSN-48i1N1 'B1 KupF VO $ ODSN-28,ODSN-28 PN3,ODSN-28 PN3 wp07.a VO -X- ODSN-5i,ODSN-5i 154, $ ODSN-29i,ODSN-29i 1N4,ODSN-29i 1N4 wp06 VO -S- ODSN-6, ODSN-6 PS5, )O VO >E ODCN 30,ODSN 30 rNS, ODCN 30 r N5 wp05 VI _--• ', o-- • - ( CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 9/14/2010 9:00:14AM Page 6 COMPASS 2003.16 Build 42B p i- ---a N -J s > 'T -'�.._....-.45 • 0 a:2-y � .V o 0 ` -;____,.,__-1:-. - - ticE ! . s !4:1-• o - l'-' 4 f1/4 ft,I\NAI t ..rli; • -.:4::::-. '', w .... 0 s • a0.� t▪ i wJ- ', �yf 3 c 0 0 Q'f .Y ••t y4- m V i 0R t: — J /�•f • v� • 1�e1 c 0 _� d :. ' t �Q�... 1'� a d▪ z , a- O ?' t. Z :,`20 m o c. S'es tr4..%. et‘: ."<,, ° ���\d� c o z o Oe. °s 0 0 ! 0 F ° o �� d Y 0 o. Ff+ (n —,..« 7 il S ° ° FS ` ,zw°v_ ol A 0 F `- an Q a Y v a• L O 0 2 2,f, P p 2 0 P 3 cc j 0 0 �F` 00 p1-- C a s 0 sa- 0 0- ° �f' 0 z ° " z o ° Q O 1---- 0- 4,, F! o z Q U 6 0 m 0 0 ! s, 0 0 Yic O-J JO LLI0 9! 0 ° 9Y 0 s! ° € oz M t� ° .`�. £ ° o LN I �� c ^$ O O o O � •Va 0 d m O O`n C C ON Q 'n O g OZ ^l C W 0 V 2 —0 y O 0 -� 0 c�a 8 • 3 \ ar=cc �.. I, f I I w•Disirict�Boon dry i t SE Corner of \\OOOGURUK 97E Protracted Section"11 . �: -it it Coordinates LI i 1N 6028111.04 m �� I E 470989.01 I \ u i I PI-254 `\ '• Ref. AK BLM ' 1, , ccS `• '\ ; Harrison: Bay Troct; "A" 1 P1-24\ \..\,<(' 11/4\ \"4'''',4,,a �,`, L R��rg Drawing � �� * , ti ° a 33 u1 ' �.,PliR s 9'• 1 'a p7,C71d 4%• 1 !P12) -- K" ��..'.°7----P pf !f} ¢ylore Iceroad=5.99 1JHes 1 "- Near Short korai/J=3_82 ~ I.'P1-13 PJ 20 to Daogvruk • �` PI 7 to Pi 20 • J �� 33 m , N>, a I\ 18 __ v I x '0 `• P.1-23` I /' PI-15 , ..10111.111111.11.11111111111P �� _J Phf7 ldra DS 3N B.O.P 31 _ i vpi_• . ' Roars to Lola 1 3 /4 Pi-.0 s PI-19 {` 1 -1-:::‘.lead c,�5�` .. Basis of Location l '7 2 . . . BUC Mfg' f ,R, ; : -5 DS-3H West Monument Coordinates P1 N 6001016.61 •STAKED PI INFORMATION ONLY -* 1 a ' E 498081.23 I . S )./ m Ref. Lownsbury & Assoc. n� I D < Drawing No. l NSK 6.01—d672 .. 41 "s 1 OF A� �� 0 i4. T J * r 0 1.31111140•111/ »40.11/ ..• •.•; , e i 3."::,1;-,..1 • • ;lip G.Davis . O e 1 " v \ No.4110-S ••a``r*or ' ; ';`' ��r, 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 - -Aie-Ska-S-t- te--Plane- -S-edtitiFfLirTe CrIW- ,.., , -- Well No, ...__.____y _____________ x___ Latitude (N) Longitude (W) I -- 1 6,031,15t32 469,920,45 70 29 46,24160 150 14 45,4-646-8 3035 1077 13,50 ' 2 0,031,146,35 469,915,52 TO 29 46,19252 150 14 45,60922 3030 1082 13.50 • 3 6,031,141,39 409,910,59 70 29 46714354 150 14 45,75375 3025 1087 13:150 4 6,031,136.46 469,905,67 70 29 46.09485 150 14 45,89799 3020 1092 13.50 1 - 5 6,031,131.45 469,900.74 ' 70 29 46.04538 150 14 40,04252 .3015 —1097 13,50 6 6,031,126,51— 469,895,80 70 29 45,99660 150 14 46,16735 3010 1102-- 13,50 : L------1 --6,011,113,73 -469,003,13 70 29 45,67039-- 150 14 46755879 2997 1115 13.50 8 6,031,108773 469,878.21 70 29. 5,132102 150 14 46,703153 2992 1120 13.50 9 6,031,103.75 469,873,26 70 29 45.77164 750 14 46,B4814 2987 1125 13.50 10 6,031,098,79 469,868,36 70 29 45.72286 150 14 46,99179 2982 1130 - 1• 3,50 11 6,031,093,84 469,863,39 70 29 45,67398 150 14 47,13750 2977 1135 1• 3,50 —12 6,031,088,87 469,858.47 70 29 45,02490 150 14 47,28174 2972 1140 13.50 13 6,031,076,06 469,845,81 70 29 45,49840 150 14 47.05288 2960 1152 13,5014 6,031,071,09 469,840.87 - 70 29 45.44932 150 1447,79770 2955 1157 1• 3.50 15 6,031,006.15 469,835,96 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 46,08588 2945 1167 13.50 17 6,031,056,25 469,826,11 70 29 45,30277 150 14 48.23042 2940 1172 1• 3,50 18 67- -0311 -051.27 4091- -8217 18 70 29 45,25359 150 14 48,37495 2935 - 1177 -, 13,50— ' -19 6,031,038.52 469,808,50 70 29 45.12708 150 14 48,74668 2922 1189 13,50 20 6,031,033,50 469,803.59 70 29 45.07811 150 14 40,09001 2917 1194 13,50 ---- 21 6,031,028.53 469,798.62 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 49,18141 2907 1204 13.50 23 -0-,031,018,57 460-,788,76 70 29 44,93007 15014 49,32537 2902 1209 13,50 24--6,031,-0 1-a 6--C 470-,78$--,84 a 70294486159 ---150144.-9,46900 2697 1214 13,50 ".'cl°,...•-...":4 gi aor 3•• .44... ...If gt itr*i 9.r i.,,,.- !I *(90 o ' ...0•11g0 # .I, - • •••- mac:,-e Philip G.Davis :taio..," ,4 ,.:;.,,:. ,.._•,„....,„, , _ .,. No 4110-S "'- d%% ' •'.(k--or ::riT:I0031 .':':;'. th-'4:0:°*•14...•••••Nic " 3 :-, .,':.'-1 SC:7-_',41:Z 'illot".,ftFESS1C1401 N'.. Alill' ..7:::AA .1, -:-„5-1. .: .61",......."..--4.1" :? €, ' ': Notes; .-..s :,,'.-: •ii -''''''.* 1, Devotions QM bosed Qn sP Mean $go Level. 2, Coordinotes ore based on Alaska 5-tote Plane Nod 27, Zone 4, 3, Ali conduotore ore within Protrocted Section 11. Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Concluotoirs DRAWN BY; SL CHECKED BY: Mj0 LOCATION: Protrooted section 11 SCALE; N/A Township 13 North , Ronge 7 Eost DATE; 7-12-07 i Limiot Merielion 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 6,031,128.32 469,943.64 70 29 46.01630 150 14 44/7930 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 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 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 _������1i08 SURVEYOR'S CERTIFICATE ikP;''•�~••�••'' °� '/ I HEREBY CERTIFY THAT I AM o fl•' _ r I PROPERLY REGISTERED AND d h -� / 44'T ;* / LICENSED TO PRACTICE LAND i"'j �i SURVEYING IN THE STATE OF tT . ,/ ALASKA AND THAT THIS PLAT -i'' ' nl�r u• • i •• (.i. _��# REPRESENTS A SURVEY DONE BY ti.Mt 'Fk 1sik,0' • ili G.Davis o v i ME OR UNDER MY SUPERVISION t;,...;,.---:71R-1,:- .14,F. � -= tet ' ii,.10. No.4110-5 ."7,-;t's � .°°'as�`,�'i.�� -.r,�ia�,�f O F9e. .• , s AND THAT I BELIEVE THAT ALL ` 4 a;;,k S,t Z aoitssIDNAI\* + DIMENSIONS AND OTHER DETAILS « ,; G?...�:k' �N�4w..n."- � ARE CORRECT AS SUBMITTED TO - .`t'•?,� `k' ,, ,': 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 Umiat Meridian NANUQ JOB NO. SHEET DESCRIPTION: As-built Coordinates 05204 4 of 4 TRANSMITTAL LETTER CHECKLIST WELL NAME PTD# 2_1 ' Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: A (":`C l E r l( LPOOL:-e '//-►''�L�� r A( f � '�t�C t Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 El ( No -6 . 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HALLIBURTON 3/0 - /'/c ao?54 Sperry Drilling Surface Data Logging End of Well Report ODSN-18 fir ^ �� s'' � "� Client: Pioneer Natural Resources. psi itekai Il Field: Oooguruk Development Rig: Nabors 19AC Date: January 17, 2011 1'; 40dik HALLI B U RTO N I Sperry Drilling 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: Formation Evaluation Logs Halliburton Log Viewer EMF Log Viewer End of Well Report in PDF format ADI Backup PIONEER NATURAL RESOURCES HALLIBURTON I Sperry Drilling GENERAL WELL INFORMATION Company: Pioneer Natural Resources AK Rig: Nabors 19AC Well: ODSN-18 ODSN-18 PB1-PB5 Field: Oooguruk Borough: North Slope Borough State: Alaska Country: United States API Number: 50-703-20624-00-00 50-703-20624-70-00 50-703-20624-71-00 50-703-20624-72-00 50-703-20624-73-00 50-703-20624-74-00 Sperry Job Number: AK-AM-0007650103 Job Start Date: 5 Nov 2010 Spud Date: 25 Oct 2010 Total Depth: ODSN-18 16689' MD, 6228' TVD ODSN-18 PB1 11890' MD, 6172' TVD ODSN-18 PB2 13499' MD, 6253' TVD ODSN-18 PB3 13920' MD, 6222' TVD ODSN-18 PB4 13832' MD, 6154' TVD ODSN-18 PB5 14843' MD, 6215' TVD North Reference: True Declination: 21.228 Dip Angle: 80.946 Total Field Strength: 57,630 nT Date Of Magnetic Data: 25 Oct 2010 Wellhead Coordinates N: North 70° 29' 45.25" Wellhead Coordinates W: West 150° 14' 48.38" Drill Floor Elevation 56.2' Ground Elevation: 13.5' Permanent Datum: Mean Sea Level SDL Engineers: Tom Mansfield, Colby Marks, Mark Lindloff, Ryan Massey Company Geologist: Jacque Ledbetter, Paul Cozma, Jim Stewart, Mindaugas Kuzminskas Company Representatives: Rod Klepzig, Joey Cortez, Joe Polya, Jerry Haberthur SSDS Unit Number: 123 PIONEER NATURAL RESOURUE.`:; HALLIBURTON '.perry Drilling DAILY SUMMARY Begin ODSN-18 11/5/2010 Mudloggers arrived on location. Finished POOH, lay down 10 5/8"x 11 3/4" BHA. Picked up 9 -8"drill collar. Racked back same in derrick. Changed lower rams to 9 5/8"—tested same. Rig up to run 9 5/8" 40#liner. Run in hole to 1063' MD. 11/6/2010 Continue to run in hole with 9 5/8" liner to 3508' MD, noted increased weight. Circulated at 4 bpm increasing to 5 bpm. Continued to run in the hole with 9 5/8" liner on 5"drill pipe. Ran in the hole to 8448' MD and took weight. Released from liner at 8824' MD. Made up cement head and dropped ball, unable to shear. Max gas of 240 units at 2100 strokes. Pumped to cement liner. 11/7/2010 Continued pumping mud to bump plug. Finished chasing plug, did not bump. Attempted to release from running tool. Circulated 450 bbls at 6-8 bpm with 800-1200 psi and still did not bump plug. Attempted to set liner. Pulled out of the hole to approximately 2180' MD. Serviced top drive and cutoslip drilling line. Continued to pull out of the hole and found 4 joints of liner on drill string at surface. Changed and tested lower rams. Made up 8 1/2"clean-out BHA. Began to run in the hole with 2893' MD. 11/8/2010 Continued run in the hole with 8 1/2"clean out BHA. Tagged cement stringers at 3460' MD. Reamed to 4131' MD. Circulated and noted returned mud was cement contaminated and had separated. Continued to run in hole to 8700' MD and tagged landing collar. Circulated bottoms up at 3-12 bpm. Drilled landing collar/float equipment to 8739' MD. Reamed to 8830' MD and tagged shoe at 8822' MD. Circulated bottoms up. Short tripped from 8830' MD to 8604' MD. Pulled out of the hole from 8830' MD to 3290' MD and pumped slug. Short tripped from 3290' MD to 4418' MD with no problems. Finished pulling out of the hole and laid down 8.5" clean out BHA. Hole took 15 bbls mud on trip out of the hole and noted no static losses. Serviced rig. Made up 9 5/8" FAS squeeze packer. Ran in the hole with same on 5"drill pipe to 1145' MD. 11/9/2010 Continued to run in the hole with FAS DRIL on 5" drill pipe to 8800' MD. Set FAS DRIL at 8800' MD. Released running tool -extended stinger. Step rate circulated at 0.5 bpm to 5 bpm - lost 11 bbls while establishing circulation. Rigged up to cement. Pumped cement- lost 36 bbls while pumping cement. Unsting from FAS DRIL. Circulated bottoms up. Maximum gas throughout circulations was 121 units. Slugged pipe and pulled out to 4952' MD. Finished pulling out of hole with stinger- lost 16 bbls on trip out of hole. Laid down stinger. Picked up 2nd 9 5/8" FAS DRIL. Run in hole on 5"drill pipe to 576' MD. 11/10/2010 Finished running in the hole with 9 5/8" FAS DRIL on 5"drill pipe to 3340' MD. Attempted to set FAS DRIL in 1st joint of 9 5/8" liner- unsuccessful. Attempted to set FAS DRIL in 2nd joint of 9 5/8" liner— unsuccessful. Pulled out the hole with 9 5/8" FAS DRIL and laid down. Picked up 9 5/8" spear/grapple BHA. Attempted to run in hole. Tagged up at 545' MD. Pulled out of hole with 9 5/8"fishing BHA. Made up 11 3/4"clean-out BHA. Ran in hole rotating and pumping to 3310' MD -cement stringers found at 545' MD. Tagged top of 9 5/8" liner at 3320' MD. Circulated bottoms up and slugged pipe. Pull out of hole with 11 3/4"clean-out BHA. Troubleshoot draw works. Laid down 11 3/4"clean out BHA. Made up 9 5/8"spear/grapple. No mud losses while tripping. Gas levels averaged 2 with a maximum of 5 units. 11/11/2010 Ran in hole with 9 5/8"grapple/spear to 545' MD—took weight. Attempted to rotate- unsuccessful. Pulled out of hole with 9 5/8"fishing BHA. Grinded down stop sub on spear. Ran in hole with 9 5/8" fishing BHA to 3320' MD. Engaged and worked liner. Released from liner. Pulled out of hole with fishing BHA and laid down. Made up 9 5/8" FAS DRIL and ran in hole to 3340' MD. Set FAS DRIL and PIONEER NATURAL RESOURCES HALLI B U RTO N Sperry Drilling attempted to test 9 5/8" liner to 3500' MD. Unstung from FAS DRIL and rigged up cement head. Performed leak off test on annulus. Pumped 30 bbls of 15.8 ppg cement. Pulled out of hole to 2855' MD. Squeezed 15 bbls cement and circulated bottoms up. Troubleshoot draw works. Pulled out hole with 9 5/8" FAS DRIL stinger on 5" drill pipe to 1716' MD. 11/12/2010 Finished pulling out of the hole with 9 5/8" FAS DRIL stinger and laid down. Made up 10 5/8"clean out BHA and ran in hole to 3073' MD. Waited on cement. Cleaned out stringers from 3117' MD to 3213' MD and tagged cement. Drilled cement from 3213' MD to 3317' MD. Circulated 2 bottoms up. Max gas while circulating was 5 units. Tested 9 5/8" liner. Pulled out of hole with 10 5/8" cleanout BHA and laid down same. No mud losses for last 24 hrs. Tested BOPE. 11/13/2010 Finished testing BOPE. Made up 8 1/2"cleanout BHA and ran in hole to 3317' MD -tagged cement. Drilled cement and FAS DRIL to 3359' MD. Circulated 1.5 bottoms up. Continued RIH with 8 1/2"clean out BHA to 6214' MD and tagged plug at 3521' MD. 11/14/2010 Continued to run in the hole with 8 1/2" clean out BHA to 8744' MD and tagged cement. Drilled cement with FAS DRIL to 8850' MD and circulated bottoms up with 262 units of max gas. Performed FIT to 14 ppg EMW at 8850' MD, 5448' TVD. Continued cleaning out open hole from 8850' MD to 9139' MD. Drilled 20' of new hole and circulated bottoms up. Added 224 bbls of 10.2 ppg new LSND with lubes to system. Pulled out the hole to 8785' MD. Performed FIT to 14 ppg. Pulled out of hole and laid down 8 1/2" clean out BHA. Made up 8 1/2" x 9 1/2" drilling BHA. Began running in the hole. 11/15/2010 Continued to run in the hole with 8 1/2"x 9 1/2"drilling BHA. Tested Rhino Reamer and installed RCD element. Reamed open hole from 8781' MD to 9159' MD. Drilled 8 1/2"x 9 1/2" Intermediate interval#2 to 9507' MD and pumped Hi-vis sweep with 25-30% increase in cuttings. Drilled to 9668' MD and lost 46 bbls mud at a rate of 175 bph. Added Steel Seal to active system. Losses slowed to 3-4 bph by 9700' MD and stopped altogether thereafter. Circulated 12.0 ppg Hi-vis sweep and saw slight increase in cuttings. Strung in Steel seal at 3-4 sacks per hour to active system. Gas averaged 170 units with a maximum gas of 1385 units from 10,126' MD, below the top of the HRZ (at 10,062' MD). Reported average hole size for 9.5" hole section was 9.71". 11/16/2010 Continued drilling 8 1/2"x 9 1/2" Intermediate Interval #2. Drilled from 9880' MD to 10,071' MD. Repaired washed out MPD choke. Drilled from 10,071' MD to 10,803' MD. Diluted active system with 514 bbls of new 10.0 ppg LSND/PHPA mud while drilling ahead. Packed off at 10,803' MD and lost 40 bbls. Circulated weighted (2 ppg over MW) Hi-vis sweep with moderate increase in cuttings back (fines). Continued drilling ahead. Maximum gas for 24 hrs was 8438 units from 10,038' MD in the Kalubik. 11/17/2010 Continued drilling 8 12/'x 9 1/2" Intermediate Interval#2 while maintaining 13.0 ppg EMW. Drilled from 11,023' MD to 11,380' MD. Pumped weighted (2 ppg over MW) Hi-vis sweep with minimal increase in cuttings. Continued drilling to a TD of 11,890' MD. Calculated average hole diameter of 10.184"through 9 1/2" section and 10.35" average including rathole. Maximum gas for the day was 1240 units. Circulated 2 Hi-vis sweeps with a minimal increase in cuttings. Changed swab on #2 mud pump while circulating sweeps. Backreamed from 11,890' MD to 11,785' MD. Worked on both mud pumps. 11/18/2010 Attempted to pull back through pack off with no success with max gas reaching 2625 units. Pumped back in the hole to approximately 11,857' MD with gas dropping off. Circulated and pumped a sweep with 2969 units of gas being circulated and promptly dropped off to 400 units. Backreamed out of the hole to approximately 11,277' MD before BHA started to pack off. Staged pumps up slowly in an attempt to circulate hole clean. Backreamed to 11,113' MD and began to pack off. Staged pumps up slowly while PIONEER NATURAL RESOURCES HALLIBURTON I Sperry Drilling r ! seeing between 220-600 units of gas. Backreamed to 11,056' MD before pulling tight. Again, staged pumps up and circulated out slowly noting an average gas of 500 units. Backreamed to 10,916' MD and began to pull tight. Staged pumps up and slowly pulled back with gas of 4087 units. Gas trending downwards while backreaming at the time of report. 11/19/2010 Continued to back ream out of the hole to 10,007' MD, circulated and conditioned hole. Bottoms up gas maxed out at 5029 units and slowly dropped off thereafter. Noted losses ranging between 6 to 50 bbls/hr. Tripped out to 8796' MD. Slipped and cut drill line, serviced rig. Tripped in the hole to bottom and circulated bottoms up. Washed from 10,803' MD to 11,435' MD. Losses were 305 bbls. 11/20/2010 Short tripped out and in 10 stands in an effort clean the hole. Shorted out and in again to bottom. Lost 3 bbls during the trip back to bottom. Circulated bottoms up with a sweep, max gas as 1999 units which quickly dropped off to 237 units for a short time and thinned out thereafter. Displaced mud from a 10.0 ppg to a 12.8 ppg in and out. Pulled out of the hole while encountering some tight spots. Lost 4 bbls during the trip out. Laid down BHA and downloaded MWD. Losses were 16 bbls. 11/21/2010 Continued laying down BHA. Downloaded LWD data. Changed rams in BOPE and tested. Rigged up casing gear. Ran in the hole with 80 joints of 7" liner and lost 6 bbls. Rigged down casing gear and rigged up to run the 7" liner on drill pipe. Began running in the hole on 5" drill pipe. Casing started to slack off at 10,246' MD. Noted a net gain of 27 bbls during trip. 11/22/2010 Tripped in the hole with 7" liner on 5"drill pipe from 10,253' MD to 11,202' MD. Established circulation while reciprocating pipe and torque and slump through tight spots. Became stuck at 11,202' MD. Racked back stand and attempt to free pipe- unsuccessful. Picked single from pipe shed and continue to torque and slump in attempt to free pipe while mixing black magic pill. Continued to attempt to free pipe while spotting black magic pill. Continued to torque and slump every 15 minutes in attempt to free pipe. No gains/loss on trip in the hole. 11/23/2010 Continued to attempt to free pipe while spotting black magic pill up the hole at the 9 5/8" casing shoe at 8824' MD to 9600' MD. Continued to torque and slump in attempt to free pipe. Began circulating and cutting back mud weight from 12.8 ppg to 10.5 ppg. Removed trip nipple and installed RCD bearing. Blew down top drive and line up rig mud pumps on annulus to supply pressure to MPD equipment. Gained 2.6 bbls over past 24 hours. Remove trip nipple and install RCD bearing. Blow down top drive and line up rig mud pumps on annulus to supply pressure to MPD equipment. 11/24/2010 Circulated and jarred stuck pipe. Continued to torque and slump in attempt to free pipe. Remove RCD bearing and install trip nipple. Emergency released from liner hanger and packer. Installed cement lines and pumped cement down hole. Lost 176 bbls in doing so while seeing a max gas of 346 units. Once pumping stopped, noted 15 bbls gain. Stopped and monitored well—noted a 12.43 bbls gain. Circulated one bottoms up gaining 1.8 bbls with max gas of 108 units. Monitored hole for a second time noting a 1.82 bbls gain. All gains decreased the more time were spent waiting. 11/25/2010 Finished tripping out of the hole and lost 16 bbls on trip out. Picked up 4"xt-39 drill pipe. Made up cutting assembly. Ran in the hole with cutting assembly on 11 stands of 4"xt-39 drill pipe. Continued running in the hole on 5" drill pipe. Stopped every 15 stands to watch for gains. Ran in the hole noting a 16.6 bbls gain. Circulated 1 bottoms up with a max gas of 398 units. Mixed up dry job in preparation for trip out of the hole. Pumped dry job and began to pull out of hole. Pull out of hole with no issues noting a 20 bbls loss. Made up Spear Assembly and readied to run in the hole. Ran in the hole with no problems. Noted a 12.5 bbls gain. Latched onto 7" liner and began jarring. PIONEER NATURAL RESOURCES HALLIBURTON I Sperry Drilling P 11/26/2010 Continued jarring 7" liner in attempt to break free—no success. Pulled out of the hole noting a 12 bbls loss. Rigged down fishing BHA and rigged up cutting assembly. Ran in the hole to 8948' MD with no problems noting 8 bbls gain. Circulated for 70 minutes with max gas of 137 units. Pulled up to 8937' MD and circulated for 15 minutes noting 93 units of max gas. Pulled out to the hole to surface. Noted 13 bbls gain. Made up and ran in the hole with a spear fishing assembly. Gained 10 bbls on trip in. Latched on to 7" liner and began jarring. 11/27/2010 Continued to free stuck casing by jarring and attempting to circulate. Pulled out the hole from 8033' MD to surface. Tripped in the hole from surface to 8941' MD with cutter BHA. Cut 7" liner at 8948' MD with mechanical cutter. Pulled out the hole from 8948' MD to surface. Picked up casing spear BHA and tripped in the hole from surface to 7791' MD. Established circulation, observed pack off, and shut down pump. Latched onto fish and fully engaged spear with 300k pull. Gained 11.29 bbls over 24 hours. 11/28/2010 Tripped in the hole with cutter assembly from 368' MD to 8475' MD. Cut 7" liner at 8475' MD with cutter. Pulled out the hole from 8475' MD to surface and cutting BHA. Picked up casing spear BHA and tripped in the hole from surface to 7991' MD. Established circulation, observed pack off enter liner top at 8,014' MD, shut down pumps. Latched onto fish and fully engaged spear with 300k pull. Circulated with limited returns. Jarred on pipe with 200k over pull and pipe came free. Pulled out the hole from 8029' MD to 722' MD with fish. Gained 0.8 bbls for past 24 hours. 11/29/2010 Pulled out the hole from 722' MD to 485' MD with fish. Released spear and rigged up for 7"casing equipment to lay down fish. Pulled out the hole from 485' MD to surface laying down fish. Rigged down casing equipment. Picked up casing scraper BHA and tripped in the hole from surface to 3200' MD. Washed and reamed from 3200' MD to 3340' MD. Tripped in the hole from 3340' MD to 7800' MD. Washed and reamed from 7800' MD to 8475' MD. Pumped hi-vis weighted sweep and circulate three bottoms up. Pulled out the hole from 8475' MD to 1080' MD. Lost 8.3 bbls downhole. 11/30/2010 Pulled out of hole from 1080' MD to surface. Function tested all rams on BOP stack and flushed stack. Pick up casing spear BHA and tripped in hole from surface to 8475' MD. Established circulation and No- Go on top of fish at 8475' MD. Latched onto fish and fully engaged spear with 300k pull. Jarred on pipe with 200k over pull. Inspected derrick and top drive after jarring prior to pulling out of hole. Pulled out the hole from 8475' MD to 49' MD. Minimal losses during trips. 12/01/2010 Finished lay down stinger and 4" drill pipe. Changed lower rams and tested same. Made up the EZ DRIL BP. Ran in the hole with same to 8460' MD. Circulated at slow pump rates (3 bbls per minute) resulted in minimal gas noted. Set EZ DRIL BP at 8460' MD. Pressure tested casing to 1500 psi. Pulled out of the hole with running tool and laid down. Picked up 9 5/8"whipstock and mill assembly. Ran in the hole with assembly. Gained 3 bbls over past 24 hours. 12/02/2010 Continue to run in the hole with 9 5/8"whipstock from 1050' MD to 8409' MD. Broke circulation and oriented the whipstock face to 57° left. Tagged bridge plug at 8460' MD. Began milling window from 8438' MD to 8455' MD. Drilled open hole from 8455' MD to 8473' MD to clear upper string mill off of slide. Top of window was at 8438' MD (5195' TVD). Bottom of window was at 8455' MD. Circulated hole clean with hi-vis sweeps. Performed FIT to 13.6 ppg EMW. Perform rig maintenance. Pulled out of hole from 8400' MD to 7997' MD at midnight. PIONEER NATURAL RESOURCES HALLIBURTON I Sperry Drilling 12/03/2010 Continued pulling out of the hole from 7997' MD to surface. Laid down milling BHA and inspected mills. Flushed iron cuttings from BOP stack. Picked up drilling BHA with mud motor and ran in the hole to 8400' MD. Oriented motor to 57° left and worked through window from 8438' MD to 8455' MD. Worked down to open hole TD at 8473' MD. Directional drilled from 8473' MD to 8580' MD. 12/04/2010 Directionally drilled from 8612' MD to 8757' MD. Pulled above window and circulated bottoms up. Pulled out of the hole and laid down. Picked up 75 joints of 5"drill pipe from pipe shed, ran in hole, and stood back. Conduct BOPE test. Picked up drilling BHA and ran in to 536' MD at time of report. 12/05/2010 Shallow pulse tested MWD at 536'. Ran in the hole to 4344' MD. Tested Geo-Pilot and pulse test MWD. Continued to run in the hole to 8342' MD. Pulled trip nipple and installed RCD head. Work through window from 8438' MD to 8455' MD. Continued to run in the hole at 200 ftohr for mad pass to 8723' MD. Activated Rhino Reamer. Washed and reamed from 8723' MD to 8757' MD. Directionally drilled from 8757' MD to 9410' MD at time of report. 12/06/2010 Directionally drilled from 9410' MD to 9485' MD. Stopped drilling to change swab for mud pump#2. Directionally drilled to 9675' MD. Changed RCD bearing. Directionally drilled to 9731' MD. Stopped drilling to change swab in mud pump#1. Directionally drilled from 9731' MD to 10,468' MD. 12/07/2010 Directionally drilled from 10,468' MD to 11,481' MD. Circulated and condition mud. Directionally drilled from 11,481' MD to 11,732' MD. 12/08/2010 Directionally drilled from 11,732' MD to 12,100' MD where the Intermediate Section #2 was TD. Deactivated Rhino Reamer and circulated hole clean. Reamed 8 1/2" pilot hole with Geo-Pilot. Circulated hi-vis sweep surface to surface. Pulled out of the hole from 12,100' MD to 8433' MD (above window). Perform rig maintenance. Ran in the hole from 8433' MD to 11,008' MD. 12/09/2010 Continued to run in the hole to 12,100' MD. Pumped hi-vis sweep surface to surface. Continued to while prepping pits and weighting up mud to 13.0ppg. Pulled RCD bearing and installed trip nipple. Pumped out of hole 3 bbls per stand from 12,100' MD to window at 8438' MD. Continued pulling out of the hole on elevators from 8438' MD to 170' MD. 12/10/2010 Continued laid down drilling BHA. Changed out bottom rams to 7"and tested same. Rigged up and began running 7" 26# liner to 12,090' MD. Picked up cement head and rigged up to pump cement. 12/11/2010 Spotted liner shoe at 12,090' MD. Broke circulation and displaced drill pipe and liner with 10.2ppg mud. Set hanger and continued to displace well with 10.2ppg. Picked up to confirm running tool released. Lined up cementers and pumped 10 bbls seawater and tested lines. Pumped 40 bbls spacer at 12.5ppg. Pumped 34 bbls of cement at 15.5ppg. Dropped top plug and pumped 20 bbls seawater. Displace cement. Set liner top packer and circulate bottoms up. Pressure tested 7" liner lap—tested good. Liner top was at 8288' MD and liner shoe was at 12,090' MD. Pulled out of the hole laying down 5"drill pipe and liner running tool. Rigged up to test BOPE. 12/12/2010 Continued to test BOPE. Rigged up and began to run 7"tieback liner string from top of 7" liner at 8288' MD to surface. Worked seal assembly onto liner top at 8288' MD. Tested seals-good test. Pulled and laid down 3 joints of 7" liner. Attempted to re-enter 7" liner with seal assembly with no success. Laid PIONEER NATURAL RESOURCES HALLIBURTON Sperry Drilling down landing joint and hanger. Picked up 1 joint of 7"and attempted to work torque down hole and re- enter liner with no success. 12/13/2010 Attempted to pull out of the hole with 7" liner. Pulled to 6381'where it began to pull tight. Ran in hole with 7" liner. Pumped 167 bbls 10.2 ppg down the 11 3/4"x 7"annulus to freeze protect. Stung into 7" tie-back liner. Tested annulars and casing —tested good. Cutting and grinding casing at time of report. 12/14/2010 Continued to cut casing. Nipple up BOPE. Laid down 5" drill pipe from the derrick. Calibrated gas equipment and inventoried sample supplies in preparation for drilling production section. 12/15/2010 Continued to test BOPE. Made up Baker milling assembly with 6.0" Concave Mill for clean out run. Ran in the hole picking up singles of 4" drill pipe to 8242' MD. Washed and reamed to 8435' MD. Circulated at 92gpm for 20 minutes and 253gm up to 350gpm for 14 minutes. Performed rig maintenance. Began pulling out of the hole at time of report. No losses or gains. 12/16/2010 Continued to pull out of the hole with no losses. Laid down Baker milling BHA and made up BHA with 6.125" Mill Tooth bit for drilling out cement. Ran in the hole picking up singles of 4" drill pipe. No gains or losses with tripping in the hole. Washed and reamed from 10,951' MD to 11,800' MD. Tagged cement, mud was off balance. Drilling out cement and shoe track at the time of report. Max gas was 30 units. 12/17/2010 Continued drilling shoe track and 20' of new formation to 12,120' MD. Max drilling gas was 145 units. Performed FIT to 12.5ppg with success. Pulled out of the hole racking back 4" drill pipe in derrick. Laid down Mill Tooth BHA with no gains or losses for the trip. Made up 6.125" rotary BHA. Shallow pulse tested MWD tools—good. Ran in the hole to 2815' MD and tested MWD tools—good. Ran in the hole to 12,090' MD with zero losses. Removed trip nipple and installed RCD head. Performed rig maintenance and calibrated gas gear. 12/18/2010 Displaced from 10.2ppg LSND mud to 7.8ppg MOBM. Noted max gas of 359 units on bottoms up. Began drilling ahead at 12,120' MD. Noted minimal cuttings returning to surface. Pit watchers changed shaker screens while cuttings returned. Cuttings may have been washed away as mud ran over shakers. Pumped sweep and saw minimal increase in cuttings return to shakers. Continued to drilling ahead. Pumped sweep at 13,152' MD and saw a 5% increase in cuttings return to shakers. Drilled to 13,499' MD when hole started to pack off. Max drilling as was 4378 units at 13,499' MD while the average drilling gas was 376 units, this high max gas may be attributed to swabbing gas in the hole. Backreamed to 12,955' MD and circulated 2 bottoms up to clean hole, noted an increase of sand at the shakers. Max circulating gas was 1699 units averaging 315 units. No losses noted while drilling or tripping. Tripping in the hole to 13,323' MD at time of report 12/19/2010 Continued tripping in the hole to 13,323' MD. Had to wash from 13,323' MD to bottom due to multiple pack off events. Unable to run in further than 13,435' MD. Displaced from 7.9ppg to 10.2ppg mud and slow pumped our way to the 7" liner shoe. Pulled RCD head and rigged up trip nipple. Pulled out of the hole noting no losses. Began laying down BHA; MWD downloaded tools. The bit and part of the GeoPilot was missing, assumed to have twisted off. Began picking up 49 joints of 2.875"tubing and running in hole at time of report. 12/20/2010 Continued running the hole with 49 joints of 2.875" tubing and 4" drill pipe. Broke circulation at 13,383' MD by staging up the flow rates. Saw no losses or gains while tripping in the hole nor during circulation. Max trip gas was 1140 units, background gas before and after the max gas was 30 units. Pumped a hi- PIONEER NATURAL RESOURCES HALLI B U RTO N I Sperry Drilling vis sweep which returned to surface after approximately 5250 strokes with 1588 strokes attributed to down pipe strokes. Performed the 1st stage of the cement job. Pulled out to 12,670' MD and circulated the hole clean. Noted 111 units of max gas, averaging 35 units. Performed 2nd stage of the cement job pulled out to 11,700' MD. Circulated hole clean while noting average gas of 25 units with no peaks. No losses noted during either phases of cement job. Perform rig maintenance. Pulled out of the hole with no losses. Laying down cementing assembly at time of report. 12/21/2010 Finished laying down cementing assembly. Flush BOPE and test same. Performed maintenance on CVE and calibrate gas equipment. Made up 6.125" rotary steer-able drilling assembly. Confidence test M/LWD tools followed shallow pulse test. Performed rig maintenance. Ran in the hole with no losses. Tagged cement at 11,947' MD and drilled to 12,090' MD. Trip gas averaged between 50-60 units with no significant peaks. Began directionally drilling from 12,090' MD to 12,170' MD. Max drilling 448 units with an average of 245 units. Pulled off bottom 10' to take a survey when the drill string stalled. Attempted to slack off and pick up weight in order to pull string free. Jarred and worked pipe in an attempt to free drill string. 12/22/2010 Continued to jar and worked pipe to free drill string. 12/23/2010 Attempt to free stuck pipe with full circulation. Torque and slump pipe with 15k tq. Jar pipe at 50k down and 400k up. Pulled max pull at 90%tensile strength to 450k. Inspect derrick and top drive prior to jarring again. Attempt to jar pipe downward in attempt to free same. Rig up HES E-line unit, make up pack off on top of top drive goose neck, and make up string shot tools. Run in the hole with string shot from surface to 12,030'wlm. Locate and correlate CCL log with drill pipe tally. Work pipe and trap left hand torque in order to make back off. Trapped 17 left hand wraps at 6k torque. Attempt to fire string shot at 12,002'wlm. No indication of shot. Change out pack off element on top of top drive prior to pulling out the hole with E-line. 12/24/2010 Circulate bottoms up while rigging down E-line sheaves. Pull out the hole from 11,563' MD to surface. BHA plus 7 joints of drill pipe left in hole after blind back off. Top of fish at 11,563' MD. Service rig and top drive. Inspect derrick, crown, and blocks-Ok. Build cut lip screw in sub from an X-O sub and stage same up to rig floor. Trip in the hole picking up fishing BHA from surface to 362' MD. Trip in the hole from 362' MD to 11,251' MD; break, re-dope, and re-torque every connection. 12/25/2010 Trip in the hole from 11,251' MD to 11,563' MD. Tagged top of fish at 11,563' MD. Circulate surface to surface adding 6% NXS lube to mud system. Screw into fish at 11,563' MD and torque up same to 9k torque. Circulate lubes around BHA and begin jarring in attempt to free stuck BHA. Rig up pump in sub with TIW, Lo Torq Valves and tee to pump acid with cement pump. PJSM for pumping Mud Acid, tested lines to 3,500 psi and pumped: 18 bbls of mud acid and flush lines soda ash treatment. Spot mud acid treatment with rig pumps by displacing with 106 bbls. Displaced 6 bbls out of bit with 12 bbls left in drillstring. Pumped 3 bbls to flush spent acid after allowing mud acid to soak 45 minutes. Allowed Stage 2 acid to sit on formation while jarring up on pipe. BHA free. Pull BHA into 7"casing from 12,167' MD to 12,075' MD. Close upper pipe rams and bullhead 56 bbls of OBM through kill line to bullhead the mud acid into the formation. Bleed off and check pressure. Monitor well for flow back, static. Bled back total of 6 bbls. Circulate surface to surface monitoring returns for acid. No indications of acid returned to surface. Pull out the hole with fish from 12,075' MD to 8139' MD. Bottoms up max gas of 772 units. Trip out went well in regards to pipe displacement. 12/26/2010 Pull out the hole with fish from 8139' MD to the fishing BHA at 966' MD. Pull out the hole laying down fishing BHA and fish from 966' MD to surface. Perform complete inspection of derrick, top drive, crown, and substructure due to jarring operations. Pick up directional motor BHA from surface to 337' MD and PIONEER NATURAL RESOURCES HALLIBURTON I Sperry Drilling shallow pulse test same. Good test. Trip in the hole from 337' MD to 11,996' MD. Slip and cut 52' of drill line. Precautionary wash and ream from 11,996' MD to 12,167' MD. No tight hole issues observed. 211 units of trip gas observed. Run in hole showed proper displacement, no gains or losses. 12/27/2010 Directional drilling from 12,167' MD to 12,300'MD. Circulate 2x open hole volume and pull out the hole from 12,300' MD to 12,088' MD. Circulate bottoms up at 12,088' MD. Pull out the hole from 12,088' MD 111 to surface laying down BHA. Function test BOPE. Good test. Pick up directional RSS BHA from surface to 377' MD and shallow pulse test. Good test. Trip in the hole from 377' MD to 569' MD. Top drive not functioning properly due to extreme cold temperature; bring top drive below wind walls to warm while functioning hydraulics to warm up the hydraulic system oil. Trip in the hole from 569' MD to 3,269' MD. Pulse test LWD and break in Geo-Pilot bearings at 5-60 rpm. Good test. Trip in the hole from 3,269' MD to 4,041' MD. 24 hours max gas 330 units with an average of 246 units. No gains or losses to report. 12/28/2010 Inspect 2" service loop on top drive and found a pin hole leak (Partially caused by wear and likely worsened by extreme cold temperature). Screw in and circulate at 175 gpm to keep top drive warm and also preserve MWD batteries. Change out service loop while limiting exposure to 5 min intervals (temperature-48, wind chill-83). Repair hydraulic check valve on top drive. Trip in the hole from 4,041' MD to 12,036' MD. Function test BOPE. Good test. Pulse test LWD and Geo-Pilot bearings. Good test. Monitor well, static. Remove trip nipple and install RCD bearing. Pump 30 bbl hi-vis spacer and displace 10.2 ppg OBM with 7.8 ppg OBM. Take rotational surveys at various survey points as per HES directional driller for Cassandra survey corrections. No losses or gains to report for this period. 12/29/2010 Run in hole from 12,229' MD to 12,300' MD. Directional drill from 12,300' MD to 12,325' MD. Clean plugged flowline (cement) and troubleshoot MWD computer issues. Resume drilling from 12,325' MD to 12,493' MD. Wash and ream to clean up dogleg from 12,448' MD to 12,482' MD. Resume drilling from 12,493' MD to 13,910' MD. Circulate to clean hole due to packing off issues. Max gas for this interval was 263 units. No losses or gains to report. 12/30/2010 Drill from 13,910' MD to 13,920' MD. Packing off and torqueing up. Pull above trouble area to 13,863' MD. Pull out of hole on elevators from 13,863' MD to 13,160' MD. Pump hi-vis sweep around. Pull 1 stand to 13,080' MD. Circulate bottoms up x 3. Pull out of hole on elevators from 13,080' MD to 12,036' MD (54' inside 7" shoe). Perform annual maintenance on top drive. Run in hole from 12,036' MD to 12,850' MD. Reaming/troughing from 12820' MD to 12850' MD. Time drilling/sidetracking from 12,850' MD to 12,871' MD. Max gas 2364 units. 12/31/2010 Directional drilling from 12,871' MD to 13,832' MD. Circulate 3x open hole volume. Pull out of hole for short trip from 13,832' MD to 12,778' MD. Run in hole to 13,090' MD. Check shot survey shows entered old hole. Pull out of hole to 12,820' MD. Wash & ream. Work back into new hole. Wash and ream new hole from 12,875' MD to 12,905' MD w/200 fph, zero weight on bit. No gains or losses to report, max gas 601 units. 1/1/2011 Backream out of hole to 12,804' MD. Run in hole from 12,804' MD to 13,097' MD. Change RCD bearing. Continue to run in hole to 13,771' MD. Attempt to wash to bottom at 13,832' MD. Wash from 13,771' MD to 13,817' MD. Packing off. Pull out of hole to 13,445' MD. Circulate and condition hole. Lost detection on MWD tools. Wash & ream to 13,650' MD. Pump hi-vis nut plug sweep around. Obtained intermittent MWD signal. Pull out of hole to 13,386' MD. Circulate and check surface equip. Pull out of hole from 13,386' MD to sump at 12,550' MD. Pump 50 bbls hi-vis 10.1 ppg MOBM and spot 17 bbls in open hole. Pull out of hole from 12,550' MD to 12,036' MD (inside 7" shoe). Displace well to 10.1 ppg MOBM. Pull RCD head. Install trip nipple. Pump dry job. 10 bbl loss seen during pack off. Max gas 46 units. PIONEER NATURAL RESOURCES HALLIBURTON I Sperry Drilling 1/2/2011 Pull out of hole from 12,036' MD to surface. Lay down BHA. Test BOPE. Two failures: H2S gas& LEL gas alarms on rig floor. Both repaired and tested. Good test. Install wear ring. Pick up BHA. 36 bbl loss during trip. No gas to report at this time. 1/3/2011 Finish making up 6 1/8" BHA for Sidetrack#4. Run in hole to 7" shoe at 12,090' MD. Slip/cut drilling line. Rig up MPD. Continue to run in hole to 13,375' MD. Lost 17 bbls downhole on trip. Displace 10.1 ppg kill weight ENVIROMUL to 7.9 ppg ENVIROMUL(pumped 30 bbl 10.1 ppg ENVIROMUL hi-vis spacer) displaced kill mud light coming back 9.5-9.7 ppg. Time drilling at 13,384' MD to kick off open hole sidetrack (Sidetrack#4 13,375' MD). MPD holding 10.2 ppg EMW. Changed RCD element at 13,377' MD. Lost 17 bbl while tripping in. 24 hour max gas 2505 units -trip gas. 1/4/2011 Time drilling/sidetracking from 13,382' MD to 13,397' MD. Directional drilling from 13,397' MD to 14,255' MD. MPD held 10.15 ppg ECD while time drilling. The ECD was increased incrementally to 12.5 ppg, lost 4 bbls while increasing ECDs. MPD held 12.5 ppg EMW until 14,035' MD, where the ECD was increased to a 12.8 ppg. Currently drilling ahead w/MPD holding a 12.9 ppg ECD. 24 hour max gas 467 units, with an average background of 86 units. Observed 4 bbls losses to the hole while increasing ECD. 1/5/2011 Directional drilling from 14,255' MD to 14,843' MD. Circulate open hole volume x 4. Short trip from 14,843' MD to 13,465' MD. Encountered tight hole at 13,465' MD. Work pipe and pump lube. Work pipe free and backream from 13,465' MD to 13,387' MD. Work on top drive hydraulics. No losses observed. Max gas 381 units. 1/6/2011 Backream from 13,387' MD to 13,194' MD. Troughing/sidetracking from 13,220' MD to 13,324' MD. Backream from 13,324' MD to 13,238' MD. Troughing/sidetracking from 13,238' MD to 13,268' MD. No down hole losses, with a max gas reading of 246 units for the 24 hour period. 1/7/2011 Troughing/sidetracking from 13,238' MD to 13,268' MD. Time drilling/sidetracking from 13,268' MD to 13,291' MD. No losses for the past 24 hours. Max gas 389 units. 1/8/2011 Drilling from 13,291' MD to 13,484' MD. Circulate 3 x open hole volume. Pump 30 bbls lube pill and spot around BHA. Backream out to 13,350' MD. Change RCD head. Wash & ream from 13,350' MD to 13,484' MD. Directional drill from 13,484' MD to 14,195' MD. 24 hour max gas 759 units with an average background of 214 units. 108 bbl loss observed to the hole for the 24 hour period, most of which occurred during pack offs. 1/9/2011 Directional drilling from 14,195' MD to 15,895' MD. Function test BOPE. Max gas 548 units, with an average back ground of 235 units. Total losses to the hole for this 24 hour period were 44 bbl 1/10/2011 Directional drilling from 15,895' MD to 16,606' MD. Circulate open hole clean. Pull out of hole to 16,240' MD. Change RCD head. Repair MPD hydraulic pump. Run in hole from 16,240' MD to 16,606' MD. Directional drill from 16,606' MD to 16,689' MD. Circulate bottoms up. Max gas 323 units, with an average back ground of 126 units. Total losses to the hole for this 24 hour were 8 bbl. Increase of siltstone to 80%was observed in samples from 16,400' MD to 16,500' MD. From 16,500' MD to 16,689' MD sandstone returned to 90%. Gas dropped off at 18,642' MD, previously averaging before 240 units; now 90 units is the average. PIONEER NATURAL RESOURCES HALLIBURTON I Sperry Drilling 1/11/2011 Circulate bottoms up 4x standing back 1 stand every bottoms up. Pull out of hole from 16,265' MD to 12,030' MD. Change wash pipe packing. Run in hole from 12,030' MD to 13,387' MD. Ream from 13387' MD to 13484' MD. Run in hole to 6 1/8" TD at 16,689' MD. Circulate hole clean. Displace open hole to 6.8 ppg LVT. Pull out of hole from 16,689' MD to 14,448' MD. Continue to pull out of hole to 11,997' MD, at which point RCD was removed and well was displaced to 12 ppg mud. Max gas 120 units, with an average back ground of 30 units. Total losses for the past 24 hrs 102 bbls. 1/12/2011 Pull out of hole from 14,448' MD to 12,550' MD. Spot 30 bbl hi-vis pill from 12,550' MD to 12,080' MD, chase with 12.0 ppg MOBM. Pull out of hole from 12,550' MD to 12,037' MD. Displace well from 8.0 ppg OBM to 12.0 ppg OBM. RCD element started leaking, shut annular preventer, remove RCD bearing, and install trip nipple. Open annular preventer, circulate and condition mud weight to 12.0 ppg. Slip and cut drill line, service rig and top drive. Pull out of hole from 12,037' MD to 378' MD. Lay down directional BHA from 378' MD to surface. Trip in hole picking up 4" heavy weight drill pipe singles from pipe shed to 650' MD. Flush heavy weight drill pipe with 2x pipe capacity. Rack back 7 stands of heavy weight drill pipe in derrick. Rig up 4.5" handling equipment, held PJSM, and Baker-Lok shoe onto shoe joint. Total losses 24 bbl for the trip out 1/13/2011 Run in the hole with 4.5" L-80 12.6#HYD 521 liner from surface to 4,461' MD. Make up WFT liner hanger, liner top packer, and PBR. Pick up bumper jars and razor-back scraper assembly from 4,461' MD to 4,624' MD. Trip in hole with 4.5" liner on 4" drill pipe from 4,624' MD to 12,044' MD. Circulate drill pipe capacity at 12,044' MD and take pick up weight, slack off weight, and torque readings prior to entering open hole. Trip in hole with 4.5" liner on 4"drill pipe from 12,044' MD to 16,399' MD. Drop 1 3/4" ball and pump down same to seat and set hanger. Stage pump psi in 500 psi increments to 2,000 psi to set hanger. Slack off with 20k down to set hanger. Shear ball seat with 3,200 psi to release running tool. Test packer down annulus to 2,200 held and charted 30 min. Good test. Liner top at 11,914' MD, liner shoe at 16,399' MD. Change out air boot on trip nipple. Unsting from liner top packer and circulate bottoms up at 11,880'. Max gas 61 units. No losses 1/14/2011 Displace well from 12.0 ppg OBM to 10.0 ppg brine. Monitor well; flowing at 1 bbl every 8-10 min, circulate bottoms up with 10.0 ppg brine. 10 bbls OBM returned to surface at bottoms up indication of ballooning. Monitor well; flowing at 1 bbl every 8-10 min, raise brine weight to 10.2 ppg. Circulate surface to surface raising brine wt. to 10.2 ppg. Monitor well; flowing at 1 bbl every 20 minutes, decreasing to static condition. Pull out the hole from 11,880' MD to surface laying down scraper assembly and liner running tool. Remove wear bushing. Rig up 4 1/2"tubing running equipment, ROC gauge I-wire, and SSSV control line spools and sheaves. PJSM with crew, pick up seal assembly, and RIH with 4.5" L-80 12.6# Hyd 521 from surface to 138' MD. Max gas 161 units. 8 bbl gain for the past 24 hours. 1/15/2011 Install ROC gauge into carrier, splice I-wire to ROC gauge, and check communication. Good test. Run in the hole with 4.5" L-80 12.6#Hyd 521 frac string from 138' MD to 9,946' MD. Make up SSSV and control line, test control line to 5,000 psi for 15 min. Good test. Run in the hole with 4.5" L-80 12.6#Hyd 521 frac string from 9,946' MD to 11,883' MD. Run in the hole from 11,883' MD to No-Go with 20k down at 11,914' MD. Close annular and test annulus to 500 psi. Good test. Lay down 3 joints of tubing, pick up space out pups, and tubing hanger. Make I-wire and SSSV control line penetrations thru hanger and splice same to monitor while landing. Land hanger at 11,914' MD. Maintained 5,000 psi on SSSV control line while landing. Test upper and lower hanger seals to 5,000 psi on chart for 10 minutes. Good test. No gas or losses to report. 1/16/2011 Sperry mud loggers released. Rig down unit for row move. PIONEER MATI IRA! Rf°C(11 IR(` Q Customer: Pioneer Natural Res. Report#: 1 -IALLIBURTON Well: ODSN-18 Date: 11/06/2010-04:00 Area: Oooguruk 04:00 Depth 9139' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Run Casing Job No.: AK-AM-0007650103 Report For: J. Polya/J. Haberthu Daily Charges $4,145.90 Total Charges: ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) Flow In (gpm) SPP (psi) Gas (units) 0 15 20 _ Flow In (spm) Gallons/stroke Depth On Bot Hrs. Ann Corr Avg DiamDrilling Min Avg Max Hole Condition 9139' PWD All Circ Min Avg Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/gt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I 0/0 9139' 9.80 9.80 60 12.5 12 32 8.0 8.50 6K 7.6 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _ (current) r Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth to to to 1 to to f 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: Running in hole with casing. No losses to report at this time. ' Logging Engineer: Tom Mansfield/Colby Marks * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 1 -IALLIBURTON Well: ODSN-18 Date: 11/06/2010-04:00 Area: Oooguruk 04:00 Depth 9139' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH Job No.: AK-AM-0007650103 Report For: J. Polya/J. Haberthu Daily Charges $3,999.18 Total Charges: $36,101.81 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) Flow In (gpm) SPP (psi) l Gas (units) 0 118 50 Flow In (spm) Gallons/stroke Depth On Bot Hrs Ann Corr Avg Diam Drilling Min Avg Max Hole Condition 9139, PWD Drilling Circ Min Avg Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids 1 Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 9139' 9.80 9.80 55 13.8 12 29 8.0 9.00 8.5K 7.5 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition Lithology (%): Sd Sst _ Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff { (current) r Gas Breakdown ' H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth to to to to to to to to i 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: Continue running liner,could not get liner to bottom. Ball seated, but was unable to shear. Circulated hole while getting ready for cement job.After pumping cement,chased it with new mud,got cement returns to surface.POOH at report time to figure out what the plan forward will be. Logging Engineer: Tom Mansfield/Colby Marks * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 3 HALLIBURTON Well: ODSN-18 Date: 11/08/2010-04:00 Area: Oooguruk 04:00 Depth 9139' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH Job No.: AK-AM-0007650103 Report For: J. Polya/J. Haberthu Daily Charges $3,999.18 Total Charges: $40,100.99 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) _ Flow In (gpm) SPP (psi) _ Gas (units) Flow In (spm) Gallons/stroke Depth On Bot Hrs Ann Corr Avg DiamDrilling _Min Avg Max Hole Condition 9139' PWD All Circ min Avg Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/gt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I % 9139' 9.80 9.80 55 13.8 12 29 8.0 9.00 8.5K 7.5 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth to to to to to to to to 'I 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... ffff 24 hr Recap: POOH to pick up BHA. Make up BHA and RIH with same.Circulate and condition mud while rotating down,shipping mud to RSC.RIH on elevators at report time. Logging Engineer: Tom Mansfield/Colby Marks * 10000 units= 100%Gas In Air 11 t Customer: Pioneer Natural Res. Report#: 4 ' ALLIBUR'TON Well: ODSN-18 Date: 11/09/2010-04:00 Area: Oooguruk 04:00 Depth 9139' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH Job No.: AK-AM-0007650103 Report For: J. Polya/J. Haberthu Daily Charges $4,145.90 Total Charges: $49,038.69 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) Flow In (gpm) SPP (psi) Gas (units) Flow In (spm) Gallons/stroke Depth On Bot Hrs Ann Corr Avg Diam 9139' PWD Drilling Min Avg Max Hole Condition All Circ Min Avg Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I 9139' 9.80 9.80 58 2.0 8 16 10.0 10.50 14K 7.2 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition f Lithology (%): Sd Sst Silt Siltst Cht Clyst _ Sh Lst Coal _ Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth to l' to to to to l 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: Finished RIH to landing collar and drill out same and float equipment. POOH with clean out BHA. 15bbI loss to hole for trip out,no static losses.M/U squeeze packer.RIH with packer at report time I Logging Engineer: Tom Mansfield/Colby Marks * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 5 IALLIBURTON Well: ODSN-18 Date: 11/10/2010-04:00 Area: Oooguruk 04:00 Depth 9139' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH Job No.: AK-AM-0007650103 Report For: J. Polya/J. Haberthu Daily Charges $4,145.90 Total Charges: $53,184.59 ROP & Gas: _ Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) Flow In (gpm) SPP (psi) Gas (units) 60 121 Flow In (spm) Gallons/stroke Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling Min Avg Max 9139' All Circ Min Avg Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 9139' 9.80 9.80 44 2.5 10 19 9.6 10.00 13K 7.2 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition Lithoiogy (%): Sd Sst Silt Siltst Cht _ Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth to to to to to to to /1 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: Finished RIH with FAS DRIL and set at 8800'.Sting into FAS DRIL. Establish circulation, lose 11 bbl while doing so. R/U and pump cement,lost 36 bbl while pumping cement. Unsting from FAS DRIL and POOH. Lost 16bbl on trip out.Pick up 2nd FAS DRIL and RIH.Got to TOL and could not set packer.POOH at report time. Max gas seen while circulating was 121 units. I Logging Engineer: Tom Mansfield/Colby Marks " 10000 units = 100%Gas In Air I ;ice.,_ :.._._ ..._ Customer: Pioneer Natural Res. Report#: 6 HALLIBURTON Well: ODSN-18 Date: 11/11/2010-04:00 Area: Oooguruk 04:00 Depth 9139' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Habert Daily Charges $4,145.90 Total Charges: $57,330.49 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) Flow In (gpm) SPP (psi) Gas (units) Flow In (spm) Gallons/stroke Depth On Bot Hrs Ann Corr Avg Diam Drilling Min Avg Max Hole Condition 9139' PWD All Circ Min - Avg Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 0/0 9139' 9.80 9.80 45 6.2 12 17 13.8 12.00 14 7.7 ,., BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data l Sample Line Max: Avg: l Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth 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: After RIH with FAST DRIL with no success, POOH with same. P/U Spear and RIH with same and could not get past 545'.POOH,lay down spear,and P/U clean out BHA.RIH rotating and circulating to TOL at 3320'. POOH and lay down clean out BHA.M/U and RIH with Spear/Grapple.Got hung up around same place.POOH and grind down Spear.RIH to TOL at report time with Spear. Logging Engineer: Tom Mansfield/Colby Marks " 10000 units = 100%Gas In Air Customer: Pioneer Natural Res. Report#: 7 HALLIBURTON Well: ODSN-18 Date: 11/12/2010-04:00 Area: Oooguruk 04:00 Depth 9139' Location: _North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Circulating Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Habertl Daily Charges $4,145.90 Total Charges: $61,476.39 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) Flow In(gpm) SPP (psi) Gas(units) Flow In(spm) Gallons/stroke Depth On Bot Hrs Ann Corr Avg Diam Drilling Min Avg Max Hole Condition 9139' PWD All Circ • nein Avg Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 9139' 9.90 9.90 48 6.0 11 17 15.0 12.00 13 8.3 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg I Ambient Air Pit Room'Max: Avg: Gas(units) Chromatograph (ppm) Depth 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: Attempt to test casing. Unsting from FAS DRIL and rig up for cement. Perform LOT on annulus. Pump 30 bbls of. cement.POOH to 2855'.Squeeze 15 bbl cement.Circulate bottoms up.POOH and lay down FAS DRIL.Rih with clean out assembly assembly.Washing and reaming down at report time. Logging Engineer: Tom Mansfield/Colby Marks * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 8 HALLIBURTON Well: ODSN-18 Date: 11/13/2010-04:00 Area: Oooguruk 04:00 Depth 9139' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services) Rig: Nabors 19AC Rig Activity: TEST BOP Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Habert Daily Charges $4,145.90 Total Charges: $65,622.29 I ROP & Gas: Current R.O.P. (ft/hr) Avg 24 hr Max Max @ ft Flow In(gpmCurrent) Pump & Flow Data: SPP(psi) Gas(units) 0 3 4 Flow In(spm) Gallons/stroke Depth On Bot Hrs Ann Corr Avg DiamDrilling Min Avg Max Hole Condition 9139' PWD All Circ Min Avg Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 9139' 9.90 9.90 42 6.0 5 16 16.8 12.30 14 8.2 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line'Max: Avg: I Ambient Air Pit Room 'Max: Avg. I Gas(units) Chromatograph (ppm) Depth 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: Continue RIH with Clean out assembly,cleaning out stringers.Tag cement at 3213',drill out cement to 3317'. Circulate bottoms up 2 times.Gas never went above 4 units.Test 9 5/8"liner lap to 2500 psi for 30 min.POOH with clean out assembly and lay down same.Nipple up and test BOPs.Testing BOPS at report time. Logging Engineer: Tom Mansfield/Colby Marks * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 8 IALLit LM iUIV Well: ODSN-18 Date: 11/13/2010-04:00 Area: Oooguruk 04:00 Depth 9139' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drill Out Cement Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Habert Daily Charges $4,145.90 Total Charges: $69,768.19 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) Flow In (gpm) SPP (psi) Gas (units) 18 24 42 Flow In (spm) Gallons/stroke Depth On Bot Hrs Ann Corr Avg Diam Drilling Min Avg Max Hole Condition 9139' PWD All Circ Min Avg Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 9139' 9.90 9.90 48 6.0 16 17 18.8 12.30 13,500 8.2 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition Lithology (%): Sd Sst Silt Siltst Cht _ Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth to to to to to Ito 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: Finished testing BOP. Make up 8.5"clean out assembly and RIH with same.Tag cement at 3317'. Drill cement and FAS DRIL to 3359'.Continue RIH to 8850'.Circulating prior to performing FIT at report time.No losses observed to hole for the past 24 hours. Max gas seen for thhis time interval was 42 uits. Logging Engineer: Tom Mansfield/Colby Marks " 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 10 iALLIItJN 1'UN Well: ODSN-18 Date: 11/15/2010-04:00 Area: Oooguruk 04:00 Depth 9159' Location: North Slope Progress 24 hrs: 20' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Instar RCD Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Habert Daily Charges $5,622.73 Total Charges: $76,867.75 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) Flow In (gpm) SPP (psi) Gas (units) 0 93 262 Flow In (spm) Gallons/stroke Depth On Bot Hrs Ann Corr Avg Diam__ Drilling _Min Avg Max Hole Condition 9139' -- PWD All Circ Min Avg Max ionHole ConditionHole ConditionHole ConditionHo e ConditionHole ConditionHole I . Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/1 % 9139' 9.90 9.90 48 6.0 16 17 18.8 12.30 13,500 8.2 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 500 Security PDC 8.5 0.969 9\139 Lithology (%): Sd Sst Silt Siltst _ Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth 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: Perfrom FIT at 8850 to 14 ppg.Continue RIH and drill 20'of new formation to 9159'. POOH to 8785 and perform FIT 14 ppg EMW.POOH and lay down clean out assembly,with a 17 bbl loss for the trip out.P/U 8 1/2 by 9 1/2 drilling BHA and RIH with same.Shallow pulse test MWD,continue running in. Installing RCD bearing at report time.Max gas seen in the past 24 hrs was 262 units. Logging Engineer: Tom Mansfield/Colby Marks * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 11 'ALLIBURTON Well: ODSN-18 Date: 11/16/2010-04:00 Area: Oooguruk 04:00 Depth 10071' Location: North Slope Progress 24 hrs: 912' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Install RCD Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Habert Daily Charges $5,622.73 Total Charges: $82,490.48 ROP & Gas: Current Avg 24 hr Max Max @ ft _ Current Pump & Flow Data: R.O.P. (ft/hr) 0.0 57.0 104.0 9628' _ Flow In (gpm) 552 SPP (psi) 2764 Gas(units) 652 200 830 10038' Flow In (spm) 156 Gallons/stroke 3.5000 f Depth On Bot Hrs Ann Corr Avg Diam Drilling 12.53 Min 13.05 Avg 13.68 Max Hole Condition 10071' 16.8 65bb1 9.72" PWD All Circ 12.45 Min 13.03 Avg 13.68 Max ionHole ConditionHole onditionHole-ConditionHo e ConditionHole ConditionHole i . Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I ` 9880' 10.00 10.00 46 6.2 16 17 18.8 12.30 13,500 8.2 BHA Run # Bit Type Size TFA , Hours Depth in/out Footage WOB RPM Condition 10 500 Security PDC 8.5 0.969 16.80 _ 9139' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth 9691 to 9691 520 125 45993 2452 1130 665 305 CG 9691 to 10067 830 530 79046 3735 1374 638 289 GP to to to to to / to I Gas Type abreviations: BG- Background Gas; GP-Gas Peak; CG- Connection Gas; WTG -Wiper Trip Gas; f POG- Pumps Off Gas; PG- Produced Gas; RG - Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Ream open hole from 8781'to 9159'. Drill ahead to 9668',experience losses, loss rate was 175bbl/hr,with a total loss t for that interval of 40bb1.Slow pumps down,add STEELSEAL and also pump HI-VIS sweep. Losses slowed to about 3-5bbl hr. Currently drilling ahead at report time with no losses.Total losses for the past 24 hours was 65bb1.Max gas seen was 1 Logging Engineer: Tom Mansfield/Colby Marks ` 10000 units = 100%Gas In Air Customer: Pioneer Natural Res. Report#: 12 HALLIBURTUN Well: ODSN-18 Date: 11/17/2010-04:00 Area: Oooguruk 04:00 Depth 11224' Location: North Slope Progress 24 hrs: 1152' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Habert Daily Charges $6,531.55 Total Charges: $89,022.03 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: _t R.O.P. (ft/hr) 7.5 64.7 155.0 10676' Flow In (gpm) 691 SPP (psi) _ 3824 Gas(units) 512 961 8438 10038' Flow In (spm) 193 Gallons/stroke 3.5000 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 12.56 Min 12.97 Avg 14.39 Max 11224' 34.6 45 bbls 10.10" All Circ 12.20 Min 12.95 Avg 14.39 Max ionHole ConditionHole onditionHole ConditionHo e ConditionHole ConditionHole 1 . Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 9880' 10.00 10.00 46 6.2 16 17 18.8 12.30 13,500 8.2 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 500 Security PDC 8.5 0.969 34.60 9139' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: 1 Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth 10000 to 10412 1645 425 135477 5823 2359 1395 628 GP 10412 to 10739 4339 600 206546 9370 3522 1565 591 GP 10832 to 10832 1518 1057 119082 4905 2046 1165 574 CG 10832 to 10863 8438 1100 513962 26902 9766 3939 1401 PG 11119' to 11119' 762 500 58950 2738 1142 669 365 CG 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... I 24 hr Recap: Repaired washed out MPD choke.Continue drilling ahead to 10803',when pack off was encountered,accompanied by a 40bbl loss.Pump HI-vis sweep,with moderate increase in cuttings once at surface.Continue drilling.Drilling ahead at r report time.Total losses for the past 24 hours was 63 bbl. Max gas seen was 8438 units. Logging Engineer: Tom Mansfield/Colby Marks * 10000 units = 100%Gas In Air — Customer: Pioneer Natural Res. Report#: 12 dALLIBuH I UN Well: ODSN-18 Date: 11/18/2010-04:00 Area: Oooguruk 04:00 Depth 11890' Location: North Slope Progress 24 hrs: 666' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Back Reaming Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Habert Daily Charges $6,531.55 Total Charges: $95,553.59 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 0.0 56.9 155.0 10676' Flow In (gpm) 147 SPP (psi) _ 1274 Gas (units) 360 520 2911 Circ Flow In (spm) 45 Gallons/stroke 3.5000 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 12.56 Min 12.97 Avg 14.39 Max 11890' 46.29 45 bbls 10.10" All Circ 12.20 Min 12.95 Avg 14.39 Max ionHole ConditionHole onditionHole ConditionHo e ConditionHole ConditionHole i Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 11890' 10.00 10.00 56 15.0 15 25 7.2 8.40 18,000 9.1 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 500 Security PDC 8.5 0.969 46.29 9139' Lithology (%): Sd Sst Silt Siltst _ Cht Clyst Sh Lst Coal Gvl Tuff (current) • Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth 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: Continue drilling ahead to TD at 11890'.Work on rig pumps. Back reaming and working through pack off at report time. Total losses for past 24 hour periods was 36bbl,this was all during pack off events.Max gas seen was 2911 units. .Logging Engineer: Tom Mansfield/Colby Marks * 10000 units = 100% Gas In Air 1 Customer: Pioneer Natural Res. Report#: 14 HALLIBURTON Well: ODSN-18 Date: 11/19/2010-04:00 Area: Oooguruk 04:00 Depth 11890' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Back Reaming out of Hole Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Cortez Daily Charges $7,269.97 Total Charges: $102,823.55 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na _ na na na Flow In (gpm) 601 SPP (psi) 3060 Gas (units) 2858 554 4087 Circ Flow In (spm) 169 Gallons/stroke 3.5000 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling na Min na Avg na Max 11890' 46.31 40 bbls 10.30" All Circ 12.94 Min 13.05 Avg 13.24 Max Hole Condition(sole Condition Hole Condition Hole Condition Hole . Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft _ in out (sec/qt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I _ % 11890' 10.20 10.20 48 20.0 12 26 10.6 8.10 18,000 9.6 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 500 Security PDC 8.5 0.969 46.29 9139' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal _ Gvl Tuff _ (current) Gas Breakdown H2S Data 1 Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth 11094' to 11115' 2647 1978 262049 8854 2974 1267 496 RG 11879' to 11877' 2970 1701 284896 9981 3383 1386 514 RG 11218' to 11223' 2295 1679 214681 6579 2105 973 448 RG 11050' to 11044' 2245 1849 213089 7430 2397 1053 491 RG 10899' to 10877' 4087 2805 376300 13426 4427 1904 800 RG 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: Attempted to pull back through pack off with no success with max gas reaching 2625 units. Pumped back in the hole to approximately 11857'MD with gas dropping off. Circulated and pumped a sweep with 2969 units of gas being circulated and promptly dropped off to 400 units. Backreamed out of the hole to approximately 11277'MD before BHA started to pack off. Staged pumps up slowly in an attempt to circulate hole clean. Backreamed to 11113'MD and began to pack off. Staged pumps up slowly while seeing between 220-600 units of gas. Backreamed to 11056'MD before pulling tight. Again,staged pumps up and I circulated out slowly noting an average gas of 500 units. Backreamed to 10916'MD and began to pull tight. Staged pumps up and slowly pulled back with gas of 4087 units. Gas trending downwards while backreaming at the time of report. Losses from Midnight to Midnight were 109 bbls Sample Catchers added to Field Ticket at midnight of 11/19/2010. Mark Lindloff crew changing for Tom Mansfield Logging Engineer: Tom Mansfield/Ryan Massey * 10000 units= 100%Gas In Air I Customer: Pioneer Natural Res. Report#: 15 IALLIBI IRTON Well: ODSN-18 Date: 11/20/2010-04:00 Area: Oooguruk 04:00 Depth 11890' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Back Reaming out of Hole Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Cortez Daily Charges $6,361.15 Total Charges: $109,184.70 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In(gpm) 648 SPP (psi) 3360 Gas (units) 0 419 5029 Circ Flow In (spm) 180 Gallons/stroke 3.5000 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg na Max Hole Condition11890' 46.31 40 bbls 10.30" PWD All Circ na Min na Avg na Max Hole Condition(sole Condition Hole Condition Hole Condition Hole . Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids I Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 11890' 10.20 10.20 44 20.0 9 14 8.7 8.00 18,000 9.6 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 500 Security PDC 8.5 0.969 46.29 9139' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) .. - Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) • Depth 10657' to 10696' 5029 2104 421241 15652 5524 2262 870 RG 10584' to 10466' 2382 908 224756 9584 3638 1768 762 RG 11870' to 11841' 458 314 41809 3196 1697 1021 486 WTG 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: Continue to run in the hole to 11880",Circulate,Max Gas was 5029 units.Gas slowly diminished. Losses from 6 bbls/hr to 50 bbls/hr.POH on elevators to 8796'.Slip and cut drill line,service rig and trip in hole.Had to wash F/10803'to 11435'.then continued to bottom and circulate B/U.Max Gas 458 units,gas diminished quickly after Bottoms up. Losses from Midnight to Midnight were 305 bbls Logging Engineer: Tom Mansfield/Ryan Massey * 10000 units= 100%Gas In Air 64 Customer: Pioneer Natural Res. Report#: 16 HALLIBURTON Well: ODSN-18 Date: 11/21/2010-04:00 Area: Oooguruk 04:00 Depth 11890' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: LAY Down BHA Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Cortez Daily Charges $5,622.73 Total Charges: $114,807.43 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In(gpm) 0 SPP (psi) 0 Gas (units) 0 210 2782 Circ Flow In (spm) _ 0 Gallons/stroke 3.5000 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg na Max Hole Condition 11890' 46.31 40 bbls 10.30" PWD All Circ na Min na Avg na Max Hole Condition(sole Condition Hole Condition Hole Condition Hole . Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ftin out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/1 _ 11890' 12.80 12.80 110 20.0 34 53 10.8 11.90 15,000 19.3 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 500 Security PDC 8.5 0.969 46.29 9139' 11890' 2751' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth 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: Short Trip 10 Stands and Run back in the hole. Circulate Bottoms up,gas at Bottoms up 2782units then disipitated quickly,Displace mud to 12.8 ppg,POOH,some tight areas around 9167'some jarring was experienced.Lay Down BHA. Displacement on the trip was-4 bbls under caculated. Logging Engineer: Ryan Massey/Mark Lindloff " 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 17 IALLIBURTON Well: ODSN-18 Date: 11/22/2010-04:00 Area: Oooguruk 04:00 Depth 11890' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH W 7"Casing Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Cortez Daily Charges $5,622.73 Total Charges: $120,430.16 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) _ na na _ na na Flow In(gpm) 0 SPP (psi) 0 ' Gas(units) 0 0 0 Circ Flow In(spm) 0 Gallons/stroke 3.5000 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg na Max Hole Condition 11890' 46.31 40 bbls 10.30" PWD All Circ na Min na Avg na Max Hole Condition Hole Condition Hole Condition Hole Condition Hole . Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 11890' 12.60 12.60 50 7.5 21 33 8.6 10.80 15,000 17.8 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 500 Security PDC 8.5 0.969 46.29 9139' 11890' 2751' Lithoiogy (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth to to to to i to P 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: Continue to lay down BHA.Change rams in BOP's and test. Rig up and run in with 3180'of 7"26#liner.Make up hanger and install cross over.Trip in hole with 5"drill pipe ran smoothly till 10893'md,worked through tight spot and continue to RIH 5 stands and currently working through another tight spot at report time. Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 18 HALLIBURTON Well: ODSN-18 Date: 11/23/2010-04:00 Area: Oooguruk 04:00 Depth 11890' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Waiting on Pill Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Cortez Daily Charges $5,622.73 Total Charges: $126,052.89 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na _ na na na Flow In (gpm) 0 SPP (psi) 0 Gas (units) 0 124 420 Circ Flow In (spm) 0 Gallons/stroke 3.5000 Depth On Bot Hrs Ann Corr Avg Diam Drilling - na Min na Avg na_Max Hole Condition 11890' 46.31 40 bbls 10.30" PWD All Circ na Min na Avg na Max Hole Condition Eiole Condition Hole Condition Hole Condition Hole . Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft _ in out (sec/gt) (ppb Eq) cP (Ib/100ft) m1/30min mg/I _ % 11890' 12.80 12.80 48 7.5 16 29 6.6 8.00 17,000 18.7 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 500 Security PDC 8.5 0.969 46.29 9139' 11890' 2751' 29-Jan 142 2-4-CT-A-X-I-ER-TD Lithology (%): Sd _ Sst _ Silt Siltst Cht Clyst _ Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth fk 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; IPOG- Pumps Off Gas; PG- Produced Gas; RG - Ream Gas; T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Pumped and spotted a pill of Black Magic in open hole.Wait on pill for 12 hours.Jar pipe every 15 minutes and pump 6 strokes of fluid to move pill up the well bore at report time. Net G/L+26 bbls while circulating,Well static when pumps are off. Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units = 100% Gas In Air Customer: Pioneer Natural Res. Report#: 19 IALLIBURTON Well: ODSN-18 Date: 11/24/2010-04:00 Area: Oooguruk 04:00 Depth 11890' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: circulating Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Cortez Daily Charges $5,622.73 Total Charges: $131,675.62 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In (gpm) 213 SPP (psi) 1389 Gas (units) 0 124 420 Circ Flow In (spm) 60 Gallons/stroke 3.5000 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg na Max Hole Condition 11890' 46.31 40 bbls 10.30" PWD All Circ na Min na Avg na Max I Hole Condition(sole Condition Hole Condition Hole Condition Hole . Mud Data: _ Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I % 11890' 10.50 10.50 44 7.0 13 18 7.2 8.20 17,000 10.2 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM _ Condition 500 Security PDC 8.5 0.969 46.29 9139' 11890' 2751' 29-Jan 142 2-4-CT-A-X-I-ER-TD Lithology (%): Sd Sst Silt Siltst _ Cht Clyst Sh Lst _ Coal _ Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: y Gas(units) Chromatograph (ppm) F Depth to to to to to i 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: Wait on pill for 8 hours, break circulation and start cutting weight back to a 10.5 ppg using centrifuge and sea water to cut it.Install RCD,circulate for 2 hours with ECD at 13 ppg,Bumbed ECD's from 13-14 PPG and showed losses of 45 bbls/hr.Reduced ECD's to 13.5 and losses stablized. Raised ECDs to 13.7 and showing slight loss of 2.1 bbls/hr at report time From midnight to midnight+2.6 bbls Midnight to 0500-25 bbls Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 20 IALLIBURTON Well: t Date: 11/25/2010-04:00 Area: Oooguruk 04:00 Depth 11890' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Cortez Daily Charges $4,884.32 Total Charges: $138,036.79 1 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In (gpm) SPP (psi) Gas (units) 0 124 420 Circ Flow In(spm) Gallons/stroke 3.5000 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg na Max Hole Condition11890' 46.31 40 bbls 10.30" PWD All Circ na Min na Avg na Max Hole Condition dole Condition Hole Condition Hole Condition Hole Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 11890' 10.50 10.50 41 7.5 11 15 7.0 10.10 17,000 11.7 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 500 Security PDC 8.5 0.969 46.29 9139' 11890' 2751' 29-Jan 142 2-4-CT-A-X-I-ER-TD Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown L H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth 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: Continue to RIH,Circulate and jar stuck pipe. Install cement lines and pump cement down and cement liner in place. Lost 176 bbls during cement Job,Gained 16 bbls back, Monitored well Gained, 12.43 bbls,Circulated Bottoms up with a 1.8 bbl gain Stoppped Monitored well 1.82 bbls gain.Unsting from liner and POOH 60'.Circulate and pump slug.POOH and lay down, liner hanger/running tool.-15 bbl displacement for trip,Clean rig floor and prepare to TIH with casing cutter at report time. Hole displacement+10 bbls, Notified driller and are stopping every 15-20 stands to observe well.Well showing static and mud is observed dropping down the hole. From midnight to midnight-185 bbls Midnight to 0500+10 bbls Logging Engineer: Ryan Massey/Mark Lindloff 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 21 IALLIBURTONWell: ODSN-18 Date: 11/26/2010-04:00 ' Area: _ _Oooguruk 04:00 Depth 11890' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH Job No.: AK-AM-0007650103 Report For: J. Polya/J. Cortez Daily Charges $4,884.32 Total Charges: $142,921.11 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In (gpm) SPP (psi) 1 Gas (units) 0 62 398 Circ Flow In (spm) Gallons/stroke 3.5000 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg na Max Hole Condition 40 bbls 10.30" PWD All Circ na Min na Avg na Max Hole Condition(sole Condition Hole Condition Hole Condition Hole Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I ok 11890' 10.50 10.50 43 7.5 11 17 7.4 11.00 17,000 12.2 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 500 Security PDC 8.5 0.969 46.29 9139' 11890' 2751' 29-Jan 142 2-4-CT-A-X-I-ER-TD Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: J Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth 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: Continue to run in hole and cut casing.Confirm cut depth at 9074 on 7"liner.Trip Displacement+16 bbls. POOH and pick up stinger.Trip Displacement-20 bbls.RIH with stinger to tie into liner,Trip displacement+14 bbls and try to pull out of hole with cut liner,could not pull out, release stinger and currently pulling out of the hole.Current Displacement for 55 stnds at report time-9 bbls From midnight to midnight+8 bbls I Midnight to 0500-9 bbls Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units = 100%Gas In Air !�! Customer: Pioneer Natural Res. Report#: 22 IALLIBURTON Well: ODSN-18 Date: 11/27/2010-04:00 Area: Oooguruk 04:00 Depth 11890' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Retrieving Cut Casing Job No.: AK-AM-0007650103 Report For: J. Polya/J. Cortez Daily Charges $4,145.90 Total Charges: $147,067.01 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) _ na na na na Flow In (gpm) SPP (psi) Gas (units) 0 20 137 Circ Flow In (spm) _ Gallons/stroke 3.5000 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg na Max Hole Condition 40 bbls 10.30" PWD All Circ na Min na Avg na Max Hole Condition(sole Condition Hole Condition Hole Condition Hole . Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/gt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 11890' 10.50 10.50 42 7.5 9 16 4.5 11.00 17,000 12.2 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 500 Security PDC 8.5 0.969 46.29 9139' 11890' 2751' 29-Jan 142 2-4-CT-A-X-I-ER-TD Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl _ Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth to i to i to to to to to to .k to f 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: POOH but was unable to bring out liner.Trip Displacement (-12 bbls),Make up cutter again and TIH.Trip Displacement(+8 bbls).Cut casing again and POOH.Trip Displacement(-4.8 bbls).Casing cutter looked worn when layed out of hole.Make up stinger and trip in hole Trip Displacement(+10 bbls).Currently Trying to retrieve cut casing. l I From midnight to midnight(+13 bbls) II Midnight to 400(+2 bbls) Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 23 HALLIBUh, (ON Well: ODSN-18 Date: 11/28/2010-04:00 Area: Oooguruk 04:00 Depth 11890' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH to Cut Casing Job No.: AK-AM-0007650103 Report For: J. Polya/J. Cortez Daily Charges $4,145.90 Total Charges: $151,212.91 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In(gpm) SPP (psi) Gas(units) 0 _ Circ Flow In(spm) Gallons/stroke 3.5000 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling na Min na Avg na_Max 40 bbls 10.30" All Circ na Min na Avg na Max Hole Condition Nole Condition Hole Condition Hole Condition Hole Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 11890' 10.50 10.50 42 7.5 10 20 4.7 10.70 17,000 12.2 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 500 Security PDC 8.5 0.969 46.29 9139' 11890' 2751' 29-Jan _ 142 2-4-CT-A-X-I-ER-TD Lithology (%): Sd Sst Silt _ Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data 1 Sample Line Max: Avg: 1 Ambient Air Pit Room Max: tAvg: Gas(units) Chromatograph (ppm) Depth 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: Run in the hole to pull out liner,(+10 bbl Displacement). Attempt to pull out liner.Jar and pull with no success, No losses or gains seen during this time.POOH and lay down stinger,(-16.5 bbls displacement).Tested BOPs. Make up cutter and tripping in hole at report time. From midnight to midnight(-6.5 bbls)+10 bbl gain RIH and-16.5 bbls POH Midnight to 0400(+11.29 bbls)while RIH Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 24 HALLIBURTON Well: ODSN-18 Date: 11/29/2010-04:00 Area: Oooguruk 04:00 Depth 11890' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: P/U staging equipment Job No.: AK-AM-0007650103 Report For: J. Polya/J. Cortez Daily Charges $4,145.90 Total Charges: $151,212.91 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na _ Flow In(gpm) SPP (psi) Gas (units) 0 Circ _ Flow In (spm) Gallons/stroke 3.5000 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg na Max Hole Condition 40 bbls 10.30" _PWD All Circ na Min na Avg na Max i Hole Condition Hole Condition Hole Condition Hole Condition Hole Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids i Depth ft _ in out (sec/qt) (ppb Eq) _ cP (Ib/100ft2) m1/30min mg/I % 11890' 10.50 10.50 44 7.5 11 19 i 5.3 11.20 17,000 11.7 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 500 Security PDC 8.5 0.969 46.29 9139' 11890' 2751' 29-Jan 142 2-4-CT-A-X-I-ER-TD Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal _ Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg Gas (units) Chromatograph (ppm) Depth to to to to r to i 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: Cut liner at 8475'and POOH,(-13bbls displacement). Lay down cutter. Pick up[fishing tool BHA and RIH,stopp to slip and cut drill line at 1772'.Continue to RIH to 8029'.(+13.8 bbls displacement)Position spear and tie into fish,POOH with fish. (-4.6 bbl Displacement.)Currently picking up staging equipment for a scraper run. . From midnight to midnight(+0.8 bbls)-13 bbl gain POH and+13.8 bbls RIH Midnight to 0400(-4.4 bbls)while POH i Logging Engineer: Ryan Massey/Mark Lindloff " 10000 units= 100% Gas In Air I iiii Customer: Pioneer Natural Res. Report#: 25 HALLIBURTON Well: ODSN-18 Date: 11/30/2010-04:00 Area: Oooguruk 04:00 Depth 11890' Location: ___North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: _ R/U Fishing BHA Job No.: AK-AM-0007650103 Report For: J. Polya/J. Cortez Daily Charges $4,145.90 Total Charges: $155,358.81 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na , na na _ na Flow In(gpm) SPP (psi) Gas (units) 0 41 383 Circ Flow In(spm) Gallons/stroke 3.5000 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg _ na Max Hole Condition 40 bbls 10.30" PWD All Circ na Min na Avg na Max Hole Condition Hole Condition Hole Condition Hole Condition Hole . Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I % 11890' 10.55 10.55 43 8.0 9 23 5.2 10.30 17,000 12.2 I BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 500 Security PDC 8.5 0.969 46.29 , 9139' 11890' 2751' 29-Jan 142 2-4-CT-A-X-I-ER-TD 1 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth 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: TIH(+10 bbls displacement)and ream and wash to top of fish.Circulate 3 1/2 bottoms up.(-3.3 bbls)retained on cuttings. Pump slug and POOH(-5 bbls displacement).Lay down Scraper BHA,Currently Picking up Fishing BHA. From midnight to midnight(-8.3 bbls)+10bbI gain RIH and-5 bbls POH with-3.3 bbls retained on cuttings. Midnight to 0400(0 bbls) i Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100%Gas In Air I 6 Customer: Pioneer Natural Res. Report#: 26 HALLIPURTON Well: ODSN-18 Date: 12/01/2010-04:00 Area: Oooguruk 04:00 Depth 11890' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: R/U Fishing BHA Job No.: AK-AM-0007650103 Report For: J. Polya/J. Cortez Daily Charges $4,145.90 Total Charges: $164,215.65 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In (gpm) SPP (psi) Gas (units) 0 10 83 Circ Flow In (spm) Gallons/stroke 3.5000 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg na Max Hole Condition 40 bbls 10.30" PWD All Circ na r Min na Avg na Max Hole Condition(•tole Condition Hole Condition Hole Condition Hole . Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out _ (sec/gt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 11890' 10.50 10.50 44 7.5 11 21 5.6 10.50 17,000 1012.2 i BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 500 Security PDC 8.5 0.969 46.29 9139' 11890' 2751' 29-Jan 142 2-4-CT-A-X-I-ER-TD Lithology (%): Sd _ Sst Silt Siltst Cht _ Clyst Sh _ Lst Coal _ Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth to to to to to to to to li 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: POOH(-12.6 bbls displacement)and lay down stinger.Currently laying down 4"drill pipe. From midnight to midnight(-1.6 bbls)(+11 bbl)gain RIH and(-12.6 bb)POH. Midnight to 0400(0 bbls) Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100%Gas In Air �.l Customer: Pioneer Natural Res. Report#: 27 HALLiauai i uN Well: ODSN-18 Date: 12/02/2010-04:00 Area: Oooguruk 04:00 Depth 11890' Location: _ North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH W/whipstockAssy Job No.: AK-AM-0007650103 Report For: J. Polya/J. Haberthu Daily Charges $5,622.73 Total Charges: $172,792.04 r ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: _R.O.P. (ft/hr) na na na na Flow In (gpm) SPP (psi) Gas (units) 0 2 42 Circ Flow In (spm) Gallons/stroke 3.5000 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg na Max Hole Condition 40 bbls 10.30" PWD All Circ na Min na Avg na Max Hole Condition hole Condition Hole Condition Hole Condition Hole . Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids I Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 11890' 10.50 10.50 47 7.0 13 21 6.0 10.00 15,000 12.2 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 500 Security PDC _ 8.5 0.969 46.29 9139' 11890' 2751' 29-Jan 142 2-4-CT-A-X-I-ER-TD 4 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth 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; IPOG - Pumps Off Gas; PG- Produced Gas; RG - Ream Gas; T-- -Trip...; F--- Formation...; E--- Early... 24 hr Recap: Test csg T/1500 psi. POOH w/BP running tool.(-9.15 bbls Displacement)L/D same.P/U 9 5/8"Whipstock/mill assembly. RIH w/whipstock/mill at report time at 7347'and From midnight to midnight(-+3 bbls)(+12.15bbI)gain RIH and(-9.15 bb)POH. Midnight to 0400(-12.3 bbls)RIH Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100% Gas In Air t Customer: Pioneer Natural Res. Report#: 28 IALLIBURTON Well: ODSN-18 Date: _12/03/2010-04:00 Area: Oooguruk 04:00 Depth 8473' Location: North Slope Progress 24 hrs: 17' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Laying Down Singles Job No.: AK-AM-0007650103 Report For: J. Polya/J. Haberthur Daily Charges $4,145.90 Total Charges: $175,461.11 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 0.0 5.3 _ 10.0 8439' Flow In (gpm) 0 SPP (psi) _ 0 Gas(units) 0 22 89 8454' Flow In (spm) 0 Gallons/stroke 3.5000 Depth On Bot Hrs Ann Corr Avg Diam Drilling 10.39 Min 10.59 Avg 10.96 Max Hole Condition 8473' 7.8 20 bbls 8.50" PWD All Circ 10.39 Min 10.68 Avg 11.84 Max Hole Condition bole Condition Hole Condition Hole Condition Hole . Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 8473' 10.10 10.10 47 6.2 13 25 4.4 9.50 15,500 10.7 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 500 Security PDC 8.5 0.969 46.29 9139' 11890' 2751' 142 2-4-CT-A-X-I-ER-TD milling R.,' 8" n no 18' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth 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: new formation F/8444'-T/8473'.TOW 8438'BOW 8455.Circulate 5x Bottoms up,Performed an FIT to 13.6 ppg EMW at 8473'. (5195'TVD). Slip/cut drlg line.Serviced Top Drive.Slugged pipe.POOH'with 8 3/8"mill assembly,Currently Laying down singles for pipe management From midnight to midnight(-12 bbls)(-12..00 bbl Displacement RIH). Midnight to 0400(-1.9 bbls) with 41 stands POH Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 29 HALLIBURTON Well: ODSN-18 Date: 12/04/2010-04:00 Area: Oooguruk 04:00 Depth 8702' Location: North Slope Progress 24 hrs: 229' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Ahead Job No.: AK-AM-0007650103 Report For: J. Polya/J. Haberthu Daily Charges $5,622.73 Total Charges: $181,083.84 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 48.0 37.0 112.0 8644' Flow In (gpm) 450 SPP (psi) 1735 Gas (units) 45 57 58 8511' Flow In (spm) 127 Gallons/stroke 3.5000 Depth On Bot Hrs Ann Corr Avg Diam 8473' 5.8 20 bbls Drilling 10.45 Min 10.63 Avg 10.96 Max Hole Condition 8.50" PWD All Circ 10.62 Min 10.45 Avg 10.96 Max Hole Condition Hole Condition Hole Condition Hole Condition Hole Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 8473' 10.10 10.10 50 5.0 14 26 4.4 8.70 15,000 12.0 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 700 Security PDC 8.5 0.868 46.29 8473' 142 2-4-CT-A-X-I-ER-TD 5 7.25, 18' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: 1 Ambient Air Pit Room 'Max: Avg: Gas (units) Chromatograph (ppm) Depth 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: Continue to L/D DP w/worn hardband. L/D milling BHA. Flush stack.M/U 8.5"BHA. RIH w/same.(No gains or losses) during trip).Con't kicking off sidetrack from window in 9 5/8"casing at 8455'. Directionally drilling 8473 to 8700' i From midnight to midnight 0. Midnight to 0400(0.0 bbls) Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 30 HALLIBURTDN Well: ODSN-18 Date: 12/05/2010-04:00 Area: Oooguruk 04:00 Depth 8757' Location: North Slope Progress 24 hrs: 55' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH Job No.: AK-AM-0007650103 Report For: J. Polya/J. Haberthu Daily Charges $5,622.73 Total Charges: $186,706.57 ROP & Gas: Current Avg 24hrMax Max@ft Current Pump & Flow Data: R.O.P. (ft/hr) 0.0 46.0 91.0 8709' Flow In(gpm) 0 SPP(psi) 0 Gas(units) 0 53 188 8723' Flow In(spm) 0 Gallons/stroke 3.5000 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 10.91 Min 10.95 Avg 11.00 Max 8757' 5.8 20 bbls 8.50" All Circ 10.79 Min 10.94 Avg 11.00 Max Hole Condition(sole Condition Hole Condition Hole Condition Hole Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in _ out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 8473' 10.05 10.05 53 5.0 15 29 3.6 9.00 16,000 9.2 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 700 Security PDC 8.5 0.868_ 46.29 8473' 142 2-4-CT-A-X-I-ER-TD 18' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line IMax: Avg: 1 Ambient Air Pit Room Max: IAvg: Gas(units) Chromatograph (ppm) Depth to to 1 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... f 24 hr Recap: Finish kicking off sidetrack out of 9 5/8"window. Directionally drill F/8580'-T/8757'.Pull up into window and circ casing clean.Slug pipe.POOH w/8 1/2"BHA.L/D same Function test BOPE.P/U 74 jts 5"DP-circ pipe. POOH R/B in derrick.M/U 8 1/2"x 9 1/2"BHA for sidetrack 1,Currently Running in the hole. From midnight to midnight 0. Midnight to 0400:(0 gains or losses during Trip) Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 31 nN►r`�IBURTON Well: ODSN-18 Date: 12/06/2010-04:00 Area: Oooguruk 04:00 Depth 9632' Location: North Slope Progress 24 hrs: 875' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0007650103 Report For: J. Polya/J. Haberthu Daily Charges $5,622.73 Total Charges: $192,329.30 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 69.6 65.0 200.0 8709' Flow In(gpm) 635 SPP (psi) 3216 Gas (units) 105 64 201 8723' Flow In (spm) 178 Gallons/stroke 3.5000 Depth On Bot Hrs Ann Corr Avg Diam Drilling 12.77 Min 13.05 Avg 13.33 Max Hole Condition 9241' 5.8 20 bbls 9.56" PWD All Circ 12.60 Min 13.04 Avg 13.33 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/gt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I _ 8473' 10.05 10.05 53 5.0 19 34 3.8 8.50 15,000 8.7 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 700 Security PDC 8.5 0.868 46.29 8473' 142 2-4-CT-A-X-I-ER-TD 18' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst _ Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth 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: Continue to RIH w/8 1/2"x 9 1/2"BHA on 5"DP T/8342'.Service TD. Install RCD.Con't RIH T/8723'. Pump ball to engage Rhino Reamer.Wash/ream T/8757'.Drill 8 1/2"x 9 1/2"Sidetrack 1 interval F/8757'-T/9295'.Drilling ahead at report time at 9410'maintaining 13 ppg EMW at the window w/MPD. From midnight to midnight: -114 bbls(Losses from Solids Control, no down hole losses) Midnight to 0400:(0 losses to report down hole) Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 32 HALLIBURTON Well: ODSN-18 Date: 12/07/2010-04:00 Area: Oooguruk 04:00 Depth 10700' Location: North Slope Progress 24 hrs: 1068' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0007650103 Report For: J. Polya/J. Haberthur Daily Charges $5,622.73 Total Charges: $197,952.03 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 79.0 74.0 232.0 10439' Flow In (gpm) 675 SPP(psi) 3507 Gas(units) 578 592 2775 10413' Flow In (spm) 190 Gallons/stroke 3163.0000 Depth On Bot Hrs Ann Corr Avg Diam Drilling 12.69 Min 13.04 Avg 13.27 Max Hole Condition 9241' 5.8 20 bbls 9.56" PWD All Circ 12.55 Min 13.04 Avg 13.36 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (lb/100ft2) ml/30min mg/I % 10342' 10.05 10.05 46 12.5 12 24 506.0 8.50 13,000 8.3 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 700 Security PDC 8.5 0.868 46.29 8473' 142 2-4-CT-A-X-I-ER-TD 18' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl _ Tuff (current) Gas Breakdown H2S Data I Sample Line Max: lAvg: I Ambient Air Pit Room 'Max: IAvg: Gas(units) Chromatograph (ppm) Depth 10287' to 10438' 2775 1577 266511 9778 3498 1431 491 GP to to to to to to to to f 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: Con't drilling 8 1/2"x 9 1/2"Sidetrack Interval. Drill F/9410'-T/9485'maintaining a 13.0 ppg EMW with MPD. C/O swab on Pump 2.Drill F/9485'-T/9675'.C/O RCD.Drill F/9675'-T/9731'.C/O swab on Pump 1.Drill F/9731'-T/10468' C/O RCD,Drill ahead F/10468'-T/10700'. Increase in gas readings Between 10,287 to 10,438,Max Gas 2775 Units From midnight to midnight: -797 bbls(Losses from Solids Control Equipment,no down hole losses Midnight to 0400:-147 bbls(Losses from Solids Control Equipment)0 losses to report down hole 1 Logging Engineer: Ryan Massey/Mark Lindloff ` 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 33 HALLIBURTON Well: ODSN-18 Date: 12/08/2010-04:00 Area: Oooguruk 04:00 Depth 11944' Location: North Slope Progress 24 hrs: 1244' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0007650103 Report For: J. Polya/J. Haberthur Daily Charges $5,622.73 Total Charges: $203,574.76 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 68.0 82.7 262.0 10439' Flow In (gpm) 703 SPP(psi) 3740 Gas(units) 753 303 3044 10413' Flow In (spm) 198 Gallons/stroke 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling 12.65 Min 13.03 Avg 13.28 Max Hole Condition 11944' 50 25 bbls 9.56" PWD All Ciro 12.61 Min 13.03 Avg , 13.49 Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 10342' 10.10 10.10 45 10.0 14 22 4.4 8.50 14,000 8.2 BHA Run # Bit Type Size TFA Hours Depth in/out _ Footage WOB RPM Condition 700 Security PDC 8.5 0.868 46.29 8473' 142 2-4-CT-A-X-I-ER-TD 18' Lithology (%): Sd _ Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line IMax: 'Avg: I Ambient Air Pit Room 'Max: 'Avg: Gas(units) Chromatograph (ppm) Depth 10700' to 11850' 3044 309 270533 7715 2643 1187 515 GP 11850' to 11900' 1332 859 135746 4394 1599 761 330 GP 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: Cont drilling 8 1/2"x9 1/2"Sidetrack 1 maintaining 13.0 ppg EMW w/MPD.Drill F/10700'-T/10864'.Pumped sweep with moderate cuttings on return Con't drilling T/11481' As dilution came back,overran shakers -CIO shaker screens to handle fluid.Drilling ahead at report time at 11944'. From midnight to midnight: --678 bbls(Losses from Solids Control Equipment, no down hole losses Midnight to 0400:-95 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 34 HALLIBURTON Well: ODSN-18 Date: 12/09/2010-04:00 Area: Oooguruk 04:00 Depth 12100' Location: North Slope Progress 24 hrs: 156' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Circulating Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Haberthur Daily Charges $5,622.73 Total Charges: $209,197.49 ROP & Gas: Current Avg 24 hr Max Max @ ft _ Current Pump & Flow Data: R.O.P. (ft/hr) NA 89.0 211.0 10439' Flow In (gpm) 651 SPP (psi) 3393 _ Gas (units) 1171 377 4444 Cir Flow In (spm) 185 Gallons/stroke 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam .PWD Drilling 12.84 Min 13.02 Avg 13.29 Max 12100' 51.8 25 bbls 9.56" All Circ 12.55 Min 13.00 Avg 13.64 Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I ok 10342' 10.20 10.20 49 14.0 13 24 5.6 9.00 14,000 9.3 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition _ 700 _ Security PDC 8.5 0.868_ 46.29 8473' _ 142 2-4-CT-A-X-I-ER-TD 600 Milling Assy 8.5 2.250 0.00 8455' 8473' 18' 16 85 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data l Sample Line Max: Avg: l Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth 11944' 12100' 3964 580 228067 7141 2716 2040 450 GP 12:43 to 13:12 4444 1622 415392 _ 11622 3977 1662 673 GP to to to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; f POG- Pumps Off Gas; PG-Produced Gas; RG- Ream Gas;T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Con't drilling 8 1/2"x 9 1/2"Sidetrack 1 Interval.Drill F/11944'-T/12051'.C/O swab/liner on MP 2. Drill F/12051'to TD at 12100'MD. Pump ball to deactivate reamer.Pump weighted sweep.C/O swab/liner on MP 2. Minimal increase in cuttings seen coming across shakers. Wash/ream to enlarge 8 1/2"pilot hole F/12000'-T/12100'.Circ weighted sweep- minimal increase in cuttings.Short trip F/12100'-T/8433'. (no gains or losses observed POH)Slip/cut drlg line. RIH at report time at 11008', (No gains or losses RIH) From midnight to midnight: --378 bbls(Losses from Solids Control Equipment, no down hole losses Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 35 HALLIBURTON Well: ODSN-18 Date: 12/10/2010-04:00 Area: Oooguruk 04:00 Depth 12100' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Laying Down BHA Job No.: AK-AM-0007650103 Report For: R.Klepzig/J.Haberthur Daily Charges $5,622.73 Total Charges: $214,820.22 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) NA NA NA Cir _Flow In (gpm) _ SPP(psi) Gas(units) 0 199 6323 Cir Flow In (spm) Gallons/stroke 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam ,PWD Drilling NA Min NA Avg NA Max 12100' 51.8 25 bbls 9.56" All Circ 12.82 Min 12.98 Avg 13.11 Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I 12100' 13.10 13.10 71 11.0 30 44 4.0 8.50 14,000 20.3 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 800 Security PDC 8.5 0.969 51.80 8473' 12100' 3627' 25-Jan 143 600 Milling Assy 8.5 2.250 0.00 8455' 8473' 18' 16 85 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data l Sample Line IMax: Avg: l Ambient Air Pit Room IMax: 'Avg: Gas(units) Chromatograph (ppm) Depth 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: Finish RIH hole T/12100'-taking 25-50K weight F/11150'-T/11572'. Pump sweep-minimal increase in cuttings. Repair Pump 1 and prepare the pits for the displacement of 13 ppg mud weight while ossilating the pipe and circulating. Max gas while circulating 6322 units.Displace well to 13.0 ppg,Rig Down RCD element.POOH into 9 5/8"liner pumping 3 bbls per std-tight at 11662', 11616', 11575', 11433, 11323'.Slug pipe.Con't POOH,no losses or gains during trip displacement L/D BHA at report time. From midnight to midnight:-375 bbls(Losses from Solids Control Equipment,no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100%Gas In Air • Customer: Pioneer Natural Res. Report#: 36 HALLIBURTON Well: ODSN-18 Date: 12/11/2010-04:00 Area: Oooguruk 04:00 Depth 12100' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Displacing Mud Job No.: AK-AM-0007650103 Report For: R. Klepzig/J.Haberthur Daily Charges $5,622.73 Total Charges: $220,442.95 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) NA NA NA Cir Flow In (gpm) 115 SPP(psi) 1205 Gas(units) 261 50 261 Cir Flow In (spm) 32 Gallons/stroke 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling NA Min NA Avg NA Max Hole Condition 12100' 51.8 20 bbls 9.56" PWD All Circ 0.00 Min 0.00 Avg 0.00 Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min - mg/I 12100' 13.00 13.00 68 12.5 24 34 4.0 8.50 13,000 20.4 BHA Run # Bit Type Size TFA _ Hours Depth in/out Footage WOB RPM Condition 800 Security PDC 8.5 0.969 51.80 8473' 12100' 3627' 25-Jan 143 840 7"Casing Run 7" 0.00 18 Lithology (%): Sd _ Sst Silt Siltst Cht Clyst Sh Lst ' Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth 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: Change lower rams to 7".Test same. R/U to run 7"26#liner.RIH w/7"liner on 5"DP to top of 9 5/8"liner top. CBU.RIH w/7"liner on 5"DP T/9799'-tight-fill pipe,work free.Con't RIH w/7"liner-rotating 15-20 RPM T/12090'.M/U cement head at report time.Establish circulation starting at 5 stks/min working up to 32 stks/min. Currently displacing mud from 13.0 ppg to 10.2 ppg while getting pits ready for the cement job. No losses or gains observed during casing trip. From midnight to midnight:0 bbls(Losses from Solids Control Equipment,no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Ryan Massey/Mark Lindloff " 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 37 HALLIBURTON Well: ODSN-18 Date: 12/12/2010-04:00 Area: Oooguruk 04:00 Depth 12100' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Testing BOP's Job No.: AK-AM-0007650103 Report For: R. Klepzig/J.Haberthur Daily Charges $4,145.90 Total Charges: $223,112.02 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) NA NA NA Cir Flow In (gpm) 0 SPP(psi) 0 Gas(units) 0 116 502 Cir Flow In (spm) 0 Gallons/stroke 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling NA Min NA Avg NA Max 12100' 51.8 20 bbls 9.56" All Circ 0.00 Min 0.00 Avg 0.00 Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 12100' 10.20 10.20 45 10.0 11 12 6.8 8.20 15,000 9.7 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 800 Security PDC 8.5 0.969 51.80 8473' 12100' 3627' 25-Jan 143 840 7"Casing Run 7" 0.00 18 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: l Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth 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: Reduce MW from 13.0 ppg to 10.2 ppg.Set liner hanger. Cement liner). Set packer TOL 8288', BOL 12090').Test 9 5/8" _ liner top x 7"liner T/3500 psi-good.R/D cement head.POOH w/liner running tool UD 5"DP.Testing BOPE at report time. No losses or gains observed during Trip out of hole. From midnight to midnight:-82bbls(Losses from Solids Control Equipment, no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Ryan Massey/Mark Lindloff " 10000 units = 100% Gas In Air 11 Customer: Pioneer Natural Res. Report#: 38 HALLIBURTON Well: ODSN-18 Date: 12/13/2010-04:00 Area: Oooguruk 04:00 Depth 12100' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH 7"Casing Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Haberthur Daily Charges $4,145.90 Total Charges: $227,257.92 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) NA NA NA _ Cir Flow In (gpm) 0 SPP(psi) 0 Gas (units) 0 0 0 Cir Flow In (spm) 0 Gallons/stroke 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling NA Min NA Avg NA Max Hole Condition PWD All Circ 0.00 Min 0.00 Avg 0.00 ,Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 12100' 10.20 10.20 44 10.0 11 10 7.0 8.20 14,000 9.7 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 800 Security PDC 8.5 0.969 51.80 8473' _ 12100' 3627' 25-Jan 143 840 7"Casing Run 7" 0.00 18 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth 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: Finish testing BOPE.R/U to run 7"26#tie-back casing.RIH w/same T/8260'. Pressure test 9 5/8"x 7"casing/shoe T/2500 psi-good.Space out,M/U Vetco hanger.Attempting to sting into tie-back.Unable to sting into hanger.Service rig while making up Saver sub and IBOP.Attempt to rotate on mule shoe.Could not connect to hanger.Decision made to pull 7" casing.Currently pulling 7"casing No losses or gains observed While RIH with 7"casing From midnight to midnight:0 bbls(Losses from Solids Control Equipment,no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 39 HALLIBURTON Well: ODSN-18 Date: 12/14/2010-04:00 Area: Oooguruk 04:00 Depth 12100' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Cutting the casing Job No.: AK-AM-0007650103 Report For: R. Klepzig/J.Haberthur Daily Charges $4,145.90 Total Charges: $231,403.82 ROP & Gas: Current Avg 24 hr Max Max@ft Current Pump & Flow Data: ( R.O.P. (ft/hr) NA NA NA Cir Flow In (gpm) 0 _ SPP (psi) 0 Gas(units) 0 0 0 Cir Flow In (spm) 0 Gallons/stroke 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling NA Min NA Avg NA Max Hole Condition PWD All Circ 0.00 Min 0.00 Avg 0.00 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) _ (ppb Eq) cP (Ib/100ft2) ml/30min mg/I 12100' 10.20 10.20 46 10.0 11 11 7.6 8.00 14,000 9.7 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 800 Security PDC 8.5 0.969 51.80 8473' 12100' 3627' 25-Jan 143 840 7"Casing Run 7" 0.00 18 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth to F 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: Attempt to POOH w/7"casing-pulled T/6381'-pulled tight. RIH w/7"csg. Pump 167 bbls 10.2 ppg down the _ 11 3/4"x 7"annulus to freeze protect.Sting into 7"tie-back.Test 11 3/4"x 7"annulus T/2500 psi for 30 min.Test 7"casing T/3500 psi for 30 min. N/D BOPE to cut 7"csg.Currently cut and grinding casing, No losses or gains observed While RIH with 7"casing From midnight to midnight:0 bbls(Losses from Solids Control Equipment, no down hole losses observed) _ Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 40 _ HALLIBURTON Well: ODSN-18 Date: 12/15/2010-04:00 Area: Oooguruk 04:00 Depth 12100' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Replacing the Bag Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Haberthur Daily Charges $4,884.32 Total Charges: $236,288.14 i ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) NA NA NA Cir Flow In(gpm) 0 SPP (psi) 0 Gas(units) 0 0 0 Cir Flow In (spm) 0 Gallons/stroke 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling NA Min NA Avg NA Max All Circ 0.00 Min 0.00 Avg 0.00 Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min _ mg/I % 12100' 10.15 10.15 44 10.0 11 11 7.8 8.00 14,000 9.7 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 800 Security PDC 8.5 0.969 51.80 , 8473' 12100' 3627' 25-Jan 143 860 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I (current) Gas Breakdown H2S Data l Sample Line Max: Avg: l Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth 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: Continue to cut casing. N/U BOPE.Lay Down 5"DP from the derrick.Replacing bag at report time. Sample Catchers Arrive today Steve Mircovich and Dave McKechnie No losses or gains observed From midnight to midnight:0 bbls(Losses from Solids Control Equipment,no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole I d Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 41 HALLIBURTON Well: ODSN-18 Date: 12/16/2010-04:00 Area: Oooguruk 04:00 Depth 12100' _ Location: North Slope Progress 24 hrs: 0' _ Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH Job No.: AK-AM-0007650103 Report For: R. Klepzig/J.Haberthur Daily Charges $5,793.14 Total Charges: $242,081.28 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) NA NA NA Cir Flow In (gpm) 0 SPP(psi) 0 Gas(units) 0 0 0 Cir Flow In (spm) 0 Gallons/stroke 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling NA Min NA Avg NA Max All Circ 0.00 Min 0.00 Avg 0.00 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I cyo 12100' 10.10 10.10 44 10.0 12 9 7.8 8.00 14,000 9.7 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 800 Security PDC 8.5 0.969 51.80 8473' 12100' 3627' 25-Jan 143 860 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff 7 (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth 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: Continue to change out rotating head/rubber.Test BOP's. P/U 6"Baker Milling BHA.RIH w/same P/U 4"DP.RIH T/8242'-wash/ream T/8339'.Circ T/8435'.Slip/cut drlg line.Slug pipe.POOH w/6"Baker Mill BHA. Tom Mansfield in Mark Lindloff out Extra Man charged for today No losses or gains observed during trips in and out of hole. From midnight to midnight:0 bbls(Losses from Solids Control Equipment,no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Ryan Massey/Mark Lindloff * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 42 HALLIBURTON Well: ODSN-18 Date: 12/17/2010-04:00 Area: Oooguruk 04:00 Depth 12120' Location: North Slope Progress 24 hrs: 20' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Cortez Daily Charges $4,884.32 Total Charges: $246,965.60 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) NA 39.8 63.2 12100' Flow In (gpm) 0 SPP (psi) 0 Gas (units) 0 15 146 12118' Flow In (spm) 0 Gallons/stroke 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling NA Min NA Avg NA Max Hole Condition PWD All Circ 0.00 Min 0.00 Avg 0.00 Max • Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min _ mg/I 12100' 10.10 10.10 43 10.0 11 11 8.0 8.00 14,000 9.7 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 800 Security PDC 8.5 0.969 51.80 8473' 12100' 3627' 25 143 900 Sec FXG64 6.125 0.389 0.75 12100' 12120' 20' 16 120 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 30 70 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas (units) Chromatograph (ppm) Depth to to to to to _ to 1 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... r 24 hr Recap: Finish POOH w/Baker Milling BHA and L/D same. M/U 6 1/8"Clean-out BHA. RIH while picking up 4"DP. Wash and ream from 10951'to 11800',tag cement. Filled pipe,mud off balance. Continued wash/ream from 11800'to 12095'. Drill out cement and shoe track to 12120'and FIT to 710 psi, 12.5 ppg EMW. Pump dry job and POOH at report time. I. No losses or gains observed during trips in and out of hole. From midnight to midnight:0 bbls(Losses from Solids Control Equipment, no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Ryan Massey/Tom Mansfield * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 43 "IALLIBURTON Well: ODSN-18 Date: 12/18/2010-04:00 Area: Oooguruk 04:00 Depth 12152' Location: North Slope Progress 24 hrs: 32' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Ahead Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Cortez Daily Charges $6,361.15 Total Charges: $254,065.16 ROP & Gas: Current Avg r. 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 124.0 95.0 129.0 12132' Flow In (gpm) 236 SPP (psi) 2115 Gas (units) 10 15 371 12120' Flow In (spm) 236 Gallons/stroke 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling 9.85 Min NA Avg NA Max Hole Condition12152' 0.38 0 bbls 6.13" PWD All Circ 9.85 Min 0.00 Avg 0.00 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % 12152' 8.00 8.00 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1000 Sec FXG64 6.125 0.389 12120' 32' 8 85 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 20 30 50 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: 0 Avg: 0 Gas (units) Chromatograph (ppm) Depth 1 12120' to 12120' 371 15 1316 20 7 BKG to to to to to to to I 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: Finish POOH. Make up MWD,surface test same. RIH. Shallow pulse test MWD. Continue RIH to 12070'and install RCD. Work on mud pump isolation valve. Swap out water based drilling fluid with MOBM. Drill ahead. I No losses or gains observed during trips in and out of hole. From midnight to midnight:0 bbls(Losses from Solids Control Equipment,no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Ryan Massey/Tom Mansfield " 10000 units= 100%Gas In Air i Customer: Pioneer Natural Res. Report#: 44 ALLIRURTON Well: ODSN-18 Date: 12/19/2010-04:00 Area: Oooguruk 04:00 Depth 13499' Location: North Slope Progress 24 hrs: 1347' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Displace to 10.2 ppg Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Cortez Daily Charges $6,361.15 Total Charges: $261,164.73 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na 141.0 349.0 12488' Flow In (gpm) 231 SPP (psi) 1863 Gas (units) 95 386 3480 13499' Flow In (spm) 66 Gallons/stroke 3.5540 • Depth On Bot Hrs Ann Corr Avg Diam Drilling 9.79 Min 9.89 Avg 10.20 Max Hole Condition 13499' 11.9 0 bbls 6.13" PWD All Circ 9.79 Min 9.85 Avg 13.52 Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Pom) 13499' 7.80 7.80 43 6.6 6 7 1260.0 3.11 2 3.8 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1000 Sec FXG64 6.125 0.389 11.90 12120' 1379' 14 107 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 80 20 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room IMax: 0 Avg: 0 Gas (units) Chromatograph (ppm) 1Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 12120' to 12650' 772 385 87299 1849 501 146 15 BKG I 12650' to 12805' 917 725 83168 1859 596 219 33 BKG 12805' to 13180' 620 475 62601 1950 672 260 70 BKG r 13180' to 13499' 3480 415 255249 10519 3442 1109 152 RG 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: Drill 6 1/8"interval from 12120'to 13499'with 9.8 ppg EMW w/MPD. Pumped HiVis sweeps every 500'with minimal increase in cutting return. Hole began packing off at 13499'. Backreamed out of hole to 12937'and circulated bottoms up to clean hole with some increase in sand and 3480 units of gas. Ran back in hole from 12937'to 13323'. Hole continued attempting to / pack off. Max gas while working to bottom 1700 units. No losses or gains observed. From midnight to midnight:0 bbls(Losses from Solids Control Equipment,no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole f` If Logging Engineer: Ryan Massey/Tom Mansfield * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 45 HALLAURTON Well: ODSN-18 Date: 12/20/2010-04:00 Area: Oooguruk 04:00 Depth 13499' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH w/2 7/8"stinger-PB2 Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Cortez Daily Charges $6,361.15 Total Charges: $267,525.88 ROP & Gas: Current Avg I 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In (gpm) 233 SPP(psi) 1782 Gas(units) 45 395 1700 Circ Flow In (spm) 66 Gallons/stroke 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling na Min na Avg na Max 13499' 11.9 0 bbls 6.13" All Circ 9.79 Min 9.85 Avg 10.93 Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Porn) % 13499' 7.80 7.80 43 6.6 6 7 1260.0 3.11 2 3.8 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1000 Sec FXG64 6.125 0.389 11.90 12120' na 1379' 14 107 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 80 20 Gas Breakdown H2S Data I Sample Line!Max: Avg: I Ambient Air Pit Room 'Max: 0 'Avg: 0 Gas(units) Chromatograph (ppm) Depth Max Gas Avg Gas C1 C2 C3 C4 C5 Type 13499' to 13499' 1700 395 104423 3352 1063 368 100 BKG 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: Continued wash/ream to bottom to 13405'.Hole packing off. Decide to POOH. Displaced well from 7.8 ppg to 10.2 ppg kill weight mud. POOH from 13380'to 7"shoe at 12100'. R/D RCD and slug pipe. POOH and L/D 6 1/8"BHA-missing bit and part of GeoPilot. P/U 49 juts of 2 7/8"tubing stinger and RIH w/same on 4"DP to plug back well. Break circ at 13383'stepping up flow rate. Circulating 10.1 ppg mud with 45 units gas at report time. No losses or gains observed. 1 From midnight to midnight:0 bbls(Losses from Solids Control Equipment,no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole I Logging Engineer: Ryan Massey/Tom Mansfield * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 46 HALLIBURTOI» Well: ODSN-18 Date: 12/21/2010-04:00 Area: Oooguruk 04:00 Depth 13499' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Test BOPS Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Cortez Daily Charges $4,884.32 Total Charges: $271,302.58 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In (gpm) 233 SPP (psi) 1782 Gas(units) 45 145 1140 Circ Flow In (spm) 66 Gallons/stroke 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling na Min na Avg na Max 13499' 11.9 0 bbls 6.13" All Circ 9.79 Min 9.85 Avg 10.93 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Porn) % 13499' 7.90 7.90 50 6.4 8 8 1624.0 5.18 4.00 4.6 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1000 Sec FXG64 6.125 0.389 11.90 12120' na 1379' 14 107 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 13499' to 13499' 1140 145 104423 3352 1063 368 100 BKG 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: Finish RIH w/2 7/8"stinger T/13400'-Circulated HiVis sweep with Max Gas of 1140 units from bottoms up. Pumped 1st cement plug and POOH to 12670'. Circulated bottoms up with Max Gas of 115 units. Pumped 2nd cement plug. POOH to 11700'and circulated bottoms up with 45 units Max Gas. Finish POOH and L/D 2 7/8"stinger. Test BOPE. No losses or gains observed. From midnight to midnight:0 bbls(Losses from Solids Control Equipment,no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Ryan Massey/Tom Mansfield * 10000 units= 100% Gas In Air F •i G Customer: Pioneer Natural Res. Report#: 47 HALLIBURTON Well: ODSN-18 Date: 12/22/2010-04:00 1 Area: Oooguruk 04:00 Depth 12172' Location: North Slope Progress 24 hrs: 80' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Work Pipe Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Cortez Daily Charges $6,361.15 Total Charges: $278,771.35 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In (gpm) , _206 SPP(psi) 2580 Gas(units) 18 250 450 12160' Flow In (spm) _ 58 Gallons/stroke 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling 10.89 Min 11.49 Avg 11.72 Max Hole Condition 12172' 1.3 0 bbls 6.13" PWD All Circ 10.88 Min 11.27 Avg 11.82 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) _ cP (Ib/100ft2) (volt) (lbs/bbl) (Porn) • 13499' 7.80 7.80 50 6.5 8 6 1765.0 5.83 4.50 3.9 BHA Run # Bit Type Size TFA Hours_ _ Depth in/out Footage WOB RPM Condition _ 1100 Sec FXG646.125 0.389 1.30 12090' na 82' 14 87 _ Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: 'Avg: I Ambient Air Pit Room Max: 0 'Avg: 0 Gas (units) Chromatograph (ppm) Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 12100' to 12168' 450 250 44939 1340 360 130 23 BKG to to i to I 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: Finish tesing BOPE. M/U 6 1/8"BHA for sidetracking PB2. RIH on 4"DP and tag cement at 11947'. Drill from 11947' to 12167'. Working pipe at report time at 12167'. Max gas of 450 units from 12160'. No losses or gains observed. From midnight to midnight:0 bbls(Losses from Solids Control Equipment,no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole l 1 Logging Engineer: Ryan Massey/Tom Mansfield * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 48 ALLIBURTON Well: ODSN-18 Date: 12/23/2010-04:00 Area: Oooguruk 04:00 Depth 12167' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Work Pipe Job No.: AK-AM-0007650103 Report For: R. Klepzig/J. Cortez Daily Charges $6,361.15 Total Charges: $285,132.50 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na _ na Flow In (gpm) na SPP (psi) na Gas(units) na 12 117 circ Flow In (spm) na Gallons/stroke 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg na Max Hole Condition 12167' 1.3 0 bbls 6.13" PWD All Circ na Min na Avg na Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Porn) % 13499' 10.05 10.05 71 6.2 21 16 1357.0 3.89 3.00 18.9 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1100 Sec FXG64 6.125 0.389 1.30 12090' na 82' 14 87 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: 0 Avg: 0 Gas (units) Chromatograph (ppm) Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 12100' to 12168' 450 250 44939 1340 360 130 23 BKG to to to Ik 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... 1 24 hr Recap: Continued working tight spot. Pumped HiVis sweep with no significant increase in cuttings. R/U and RIH with wireline string shot to 4400'. Continued RIH with wireline assisting with pumps to 12030'. Locate free point at 12002'and attempt shot. No fire. POOH with wireline. No losses or gains observed. From midnight to midnight:0 bbls(Losses from Solids Control Equipment, no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Ryan Massey/Tom Mansfield * 10000 units = 100%Gas In Air Customer: Pioneer Natural Res. Report#: 49 ALLIBURTON Well: ODSN-18 Date: 12/24/2010-04:00 Area: Oooguruk 04:00 Depth 12167' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH Job No.: AK-AM-0007650103 Report For: J. Polya/J. Cortez Daily Charges $6,361.15 Total Charges: $291,493.65 ROP & Gas: _ Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In (gpm) na SPP(psi) na Gas (units) na 11 13 circ Flow In (spm) na Gallons/stroke 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg na Max Hole Condition 12167' 1.3 0 bbls 6.13" PWD All Circ na Min na Avg na Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Porn) ok 13499' 10.10 10.10 83 6.0 22 19 1260.0 8.29 6.40 19.3 rBHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1100 Sec FXG64 6.125 0.389 1.30 12090' na 77' 14 87 I Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: 0 Avg: 0 I Gas (units) Chromatograph (ppm) Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 12100' to 12168' 450 250 44939 1340 360 130 23 BKG to 11 to to to to to to to t 1 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: Finished POOH w/wireline stringshot. Break circ and pump 20 bbl bbl HiVis, 10 seawater and 2nd 20 bbl HiVis spacer. Spot 5 bbs seawater out of drillstring and work pipe. Continued pumping 1 bbl every hour until all 10 bbls of seawater reached backside. R/U and run 2nd stringshot. Pump stringshot from 4400'to 12030'. Set at 12002'and fire shot, POOH with wireline. Perform blind backoff. Pulse test MWD for pulses,negative. Continue circulating bottoms up with Max gas of 13 units. POOH at report time. No losses or gains observed. From midnight to midnight:0 bbls(Losses from Solids Control Equipment, no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Ryan Massey/Tom Mansfield * 10000 units = 100% Gas In Air Customer: Pioneer Natural Res. Report#: 50 HALLIBURTON Well: ODSN-18 Date: 12/25/2010-04:00 Area: Oooguruk 04:00 Depth 12167' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Jar on Fish Job No.: AK-AM-0007650103 Report For: J. Polya/J. Cortez Daily Charges $6,361.15 Total Charges: $297,854.80 ROP & Gas: Current Avg 24 hr Max Max @ ft _ Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In (gpm) 210 SPP (psi) 3300 to 3500 Gas (units) 7 11 70 TG _ Flow In (spm) 59 Gallons/stroke 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg na Max Hole Condition 12167' 1.3 0 bbls 6.13" PWD All Circ na Min na Avg na Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) - (m1/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Pom) ok 13499' 10.20 10.20 75 6.0 23 16 1271.0 6.60 5.10 19.9 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1100 Sec FXG64 6.125 0.389 1.30 12090' na 77' 14 87 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data 1 Sample Line Max: Avg: I Ambient Air Pit Room Max: 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth Max Gas Avg Gas C1 C2 C3 C4 C5 Type 12100' to 12168' 70 11 7069 321 84 30 2 TG 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: POOH with 120 stands DP(11563')after back off. Left BHA plus 7 joints DP in hole. P/U fishing BHA and RIH to 11558' and circulate bottoms up Max Trip Gas of 70 units,background of 7 units. Latch onto fish and begin jarring. No losses or gains observed. From midnight to midnight:0 bbls(Losses from Solids Control Equipment,no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Ryan Massey/Tom Mansfield * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 51 HALLIBURTON Well: ODSN-18 Date: 12/26/2010-04:00 Area: Oooguruk 04:00 Depth 12167' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH Job No.: AK-AM-0007650103 Report For: J. Polya/J. Cortez Daily Charges $6,361.15 Total Charges: $304,215.95 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na Flow In (gpm) 210 SPP(psi) 3300 to 3500 Gas(units) na 22 772 TG Flow In (spm) 59 Gallons/stroke 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling na Min na Avg na Max Hole Condition 12167' 1.3 0 bbls 6.13" PWD All Circ na Min na Avg na Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Pom) 13499' 10.20 10.20 81 6.0 23 12 1049.0 5.83 4.50 19.9 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1100 1 Sec FXG64 6.125 0.389 1.30 12090' na 77' 14 87 Lithoiogy (%): Sd Sst Silt Siltst Cht _ Clyst Sh Lst _ Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Pax: 0 'Avg: 0 Gas(units) Chromatograph(ppm) h, Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 12100' to 12168' 70 11 7069 321 84 30 2 TG 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: Worked pipe. Spotted 18 bbls Schlumberger Acid Treatment around lower assembly. Allowed time to treat and began working pipe. Freed pipe and POOH to 12090'. Bullheaded 60 bbls into formation(MOBM and Acid Treatment). Formation returned 6 bbls before pressure stabilized. Circulated bottoms up while checking pH at shakers. POOH. No losses or gains observed. From midnight to midnight:0 bbls(Losses from Solids Control Equipment,no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole ( Logging Engineer: Ryan Massey/Tom Mansfield * 10000 units= 100%Gas In Air I Customer: Pioneer Natural Res. Report#: 52 HALLIBURTON Well: ODSN-18 Date: 12/27/2010-04:00 Area: Oooguruk 04:00 Depth 12286' Location: North Slope Progress 24 hrs: 119' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling ahead Job No.: AK-AM-0007650103 Report For: J. Polya/J. Cortez Daily Charges $6,361.15 Total Charges: $311,485.92 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 31.5 45.8 73.7 12274' Flow In (gpm) 205 SPP (psi) 2580 Gas(units) 160 232 330 12228' Flow In (spm) 58 Gallons/stroke 3.5540 ,Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 11.25 Min 11.52 Avg 11.70 Max 12167' 2.97 0 bbls 6.13" All Circ 11.25 Min 11.52 Avg 12.08 Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ftz) (volt) (lbs/bbl) (Pom) % 12167' 10.10 10.10 115 5.0 20 12 1148.0 7.25 5.60 18.9 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1100 Sec EQH14DR 6.125 0.389 2.97 12167' na 15 84 Lithology (%): Sd Sst _ Silt Siltst Cht Clyst _ Sh Lst Coal Gvl Tuff (current) 100 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: 0 Avg: 0 Gas (units) Chromatograph (ppm) Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 12167' to 12250' 330 232 36641 1097 308 92 3 BG to to to to _ to to to to I 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: Finished POOH and L/D BHA and Fish. P/U Sperry Motor BHA and RIH to 11996'with proper displacement. Slip and cut drill line. Wash and Ream to 12167'with Trip Gas of 211 units. Drill ahead with slides at 12243'-12251'and 12274'-12286'. No losses or gains observed. From midnight to midnight:0 bbls(Losses from Solids Control Equipment, no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Colby Marks/Tom Mansfield " 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 53 HALLIBURTON Well: ODSN-18 Date: 12/28/2010-04:00 Area: Oooguruk 04:00 Depth 12300' Location: North Slope Progress 24 hrs: 14' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH-Rig Maintenance Job No.: AK-AM-0007650103 Report For: J. Polya/J. Cortez Daily Charges $6,361.15 Total Charges: $317,847.07 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na _ 41.5 58.1 12292' Flow In (gpm) 179 SPP (psi) 1210 Gas(units) 10 246 263 12293' Flow In (spm) 50 Gallons/stroke 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling 11.21 Min 11.52 Avg 11.70 Max Hole Condition 12300' 3.37 0 bbls 6.13" PWD All Circ 10.92 Min 11.02 Avg 11.25 Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Pom) 12300' 7.85 7.85 50 5.0 9 6 1652.0 2.85 2.20 4.4 BHA Run # Bit Type Size TFA Hours _ Depth in/out Footage WOB RPM Condition 1200 Sec EQH14DR 6.125 0.389_ 3.37 12167' 12300' 133' 15 84 1-2-ER-A-E-I-NO-BHA 1300 Sec FXG64 6.125 0.389 12300' Lithology (%): Sd Sst Silt Siltst Cht Clyst rSh Lst Coal Gvl Tuff (current) 100 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: 0 Avg: 0 Gas (units) Chromatograph (ppm) Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 12167' to 12250' 330 232 36641 1097 308 92 3 BG to t` to to to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; II POG- Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Continue drilling ahead to 12300'MD,6200.18'TVD. POOH to 12088'and circulate 1X bottoms up. Continue POOH and L/D BHA and mud motor. P/U GeoPilot BHA and RIH to 569'. Pulse test MWD. RIH to 3360'. Fill pipe and shallow test MWD and test GeoPilot downlink. RIH to 4040'and perform top drive maintenance. No losses or gains observed. 1 From midnight to midnight:0 bbls(Losses from Solids Control Equipment, no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Colby Marks/Tom Mansfield ` 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 54 HALLIBURTON Well: ODSN-18 Date: 12/29/2010-04:00 Area: Oooguruk 04:00 Depth 12422'MD,6214'TVD Location: North Slope Progress 24 hrs: 122' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Ahead Job No.: AK-AM-0007650103 Report For: J. Polya/J. Cortez Daily Charges $6,361.15 Total Charges: $321,484.15 ROP & Gas: Current Avg 24 hr Max _ Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 75.0 118.0 147.0 12352' Flow In (gpm) 241 SPP (psi) 2450 Gas (units) 110 55 197 12300' Flow In (spm) 68 Gallons/stroke 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 11.21 Min 11.52 Avg 11.70 Max 12420' 4.4 0 bbls 6.13" All Circ 10.92 Min 11.02 Avg 11.25 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in _ out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Porn) ok 12300' 7.95 7.95 48 6.0 10 5 1807.0 2.33 1.80 4.9 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM _ Condition 1200 Sec EQH14DR 6.125 0.389 3.37 12167' 12300' 133' 15 84 1-2-ER-A-E-I-NO-BHA 1300 Sec FXG64 6.125 0.389 1.33 12300' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 100 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: 0 Avg: 0 Gas (units) Chromatograph (ppm) Depth Max Gas Avg Gas C1 C2 C3 C4 C5 Type 12300' to 12333' 330 150 11038 459 137 38 3 BG 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: Finish changing out Top Drive Service Loop. RIH from 4041'to 12036'. Install RSD Element. Pump 30 bbl HiVis sweep and displace hole with 7.8 ppg MOBM. Trip Gas of 197 units. RIH taking check shot surveys. Clean out chunks of cement from flowline at 12326'. Drilling ahead. I No losses or gains observed. From midnight to midnight:0 bbls(Losses from Solids Control Equipment,no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Colby Marks/Tom Mansfield * 10000 units= 100%Gas In Air I Id. Customer: Pioneer Natural Res. Report#: 55 HALLIBURTON Well: ODSN-18 Date: 12/30/2010-04:00 Area: Oooguruk 04:00 Depth 13920' Location: North Slope Progress 24 hrs: 1498' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: woo Job No.: AK-AM-0007650103 Report.For: J. Polya/J. Cortez Daily Charges $6,361.15 Total Charges: $330,569.37 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na 138.8 274.7 13107' Flow In (gpm) 241 SPP (psi) 2450 Gas (units) 1800 348 2364 13920' Flow In (spm) 68 Gallons/stroke 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 9.47 Min 9.90 Avg 11.69 Max 12420' 13.28 13 bbls 6.70" All Circ 9.22 Min 9.88 Avg 12.65 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Porn) % 13826' 7.95 7.95 44 5.6 9 6 1444.0 3.89 3.00 5.0 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1200 Sec EQH14DR 6.125 0.389 3.37 12167' 12300' 133' 15 84 1-2-ER-A-E-I-NO-BHA 1300 Sec FXG64 6.125 0.389 13.28 12320' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 100 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 13910' to 13910' 2364 212716 6628 1987 630 173 GP 12400' to 13900' 1411 337 75695 2236 645 222 63 GP 12400' to 13900' 1411 337 46397 1888 616 214 48 BG 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: Drill ahead to 12493'. Ream/wash trough from 12455'to 12493'. Drill ahead from 12493'to 13910'. Hole attempting to pack off. Circulate hole clean. Pump 30 bbl HiVis sweep. POOH to 13,100'and circulate 3X bottoms up. WOO. No losses or gains observed. 1 From midnight to midnight:0 bbls(Losses from Solids Control Equipment, no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Colby Marks/Tom Mansfield ` 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 56 IIALLIBURTOIY Well: ODSN-18 Date: 12/31/2010-04:00 Area: Oooguruk 04:00 Depth 12904' Location: North Slope Progress 24 hrs: -1016' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Time Drill Ahead Job No.: AK-AM-0007650103 Report For: J. Polya/J. Cortez Daily Charges $6,361.15 Total Charges: $336,930.52 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 35.4 11.2 35.4 12904' Flow In (gpm) 237 SPP (psi) 2300 Gas (units) 90 75 601 12870' Flow In (spm) 67 Gallons/stroke 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 9.68 Min 9.83 Avg 9.96 Max 12900' 14.9 3 bbls 6.43" All Circ 9.68 Min 9.83 Avg 9.96 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids E Depth ft in out (sec/qt) _ (ml/30 min) cP (lb/100ft2) (volt) (lbs/bbl) (Porn) % 12868' 7.80 7.80 44 4.6 9 5 1803.0 2.59 2.00 4.1 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1200 Sec EQH14DR 6.125 0.389 3.37 12167' 12300' 133' 15 84 1-2-ER-A-E-I-NO-BHA 1300 Sec FXG64 6.125 0.389 13.28 12320' ILithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 100 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: 0 Avg: 0 Gas (units) Chromatograph (ppm) IDepth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 12850' to 12890' 601 65 4048 197 87 50 14 BG 12870' to 12870' 601 100 12388 418 126 47 6 CG L to to i 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: Finish circulating 3X bottoms up at 13100'. POOH to 12036'. Service rig. Decision to openhole sidetrack well at 12850'. Time drill at report time. No losses or gains observed. From midnight to midnight:0 bbls(Losses from Solids Control Equipment, no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: Colby Marks/Tom Mansfield * 10000 units = 100% Gas In Air Customer: Pioneer Natural Res. Report#: 57 -IALLIBURTON Well: ODSN-18 Date: 1/1/2011-04:00 Area: Oooguruk 04:00 Depth 13833' Location: North Slope Progress 24 hrs: 929' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Circulating Job No.: AK-AM-0007650103 Report For: J. Polya/J. Cortez Daily Charges $6,361.15 Total Charges: $344,200.49 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 0.0 125.4 220.0 12904' _ Flow In (gpm) 233 SPP (psi) 1470 Gas (units) 52 196 874 12870' Flow In (spm) 44 Gallons/stroke! 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam_PWD Drilling 9.63 Min 11.46 Avg 12.20 Max 13833' 23.6 3 bbls 6.43" All Circ 9.63 Min 11.71 Avg 12.29 Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) _ (lbs/bbl) (Porn) % 12868' 7.90 7.90 43 5.0 10 5 1878.0 2.98 2.30 4.9 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1200 _ Sec EQH14DR 6.125 0.389 3.37 12167' 12300' 133' 15 84 1-2-ER-A-E-I-NO-BHA 1400 Sec FXG64 6.125 0.389 13.28 12320' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 60 40 Gas Breakdown H2S Data I Sample Line Max: Avg: 1 Ambient Air Pit Room 'Max: 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 13000' to 13100' 874 587 96217 2641 732 222 57 GP to to to to to to to rGas 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: Drill F/12871'-T/13832'.Circ hole clean.Short-trip F/13832'-T/12778'-tight at 12960'.TIH T/13090'-check survey- old wellbore.POOH T/12820'.Troughing back into Sidetrack#3 at report time at 12904'.increased EMW being held with MPD from 9.8 ppg EMW to 12.0 ppg EMW at 13,100'(increased in 0.5 ppg increments).Change out RCD Bearing.Start RIH to 13809'.Start circulating, Experiencing some packing off.Currently fighting pack off's while working to bottom. No losses or gains observed. From midnight to midnight:0 bbls(Losses from Solids Control Equipment,no down hole losses observed) Midnight to 0400:0 bbls(Losses from Solids Control Equipment)0 losses to report down hole Logging Engineer: *Colby Marks/Mark Lindloff * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 58 HALLIBURTON Well: ODSN-18 Date: 1/2/2011-04:00 { Area: Oooguruk 04:00 Depth 13833' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH Job No.: AK-AM-0007650103 Report For: J. Polya/J. Cortez Daily Charges $6,361.15 Total Charges: $350,561.64 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 0.0 0.0 0.0 0' Flow In (gpm) 0 SPP (psi) 0 Gas(units) 0 12 46 Circulating Flow In (spm) 0 Gallons/stroke 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling NA Min NA Avg NA Max 13833' 23.6 3 bbls 6.43" All Circ 10.01 Min 11.73 Avg 12.28 Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Pom) 12868' 7.85 7.85 45 4.6 9 5 2000.0 4.53 3.50 4.9 kBHA Run # Bit Type Size TFA Hours Depth in/out _ Footage WOB RPM Condition 1200 Sec EQHI4DR 6.125 0.389 3.37 12167' 12300' 133' 15 84 1-2-ER-A-E-I-NO-BHA 1400 Sec FXG64 6.125 0.389 13.28 12320' 13833' 1513' 14 127 Lithology (%): Sd _ Sst Silt Siltst Cht Clyst Sh Lst Coal _ Gvl Tuff (current) 60 40 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: 0 Avg: 0 Gas (units) Chromatograph (ppm) Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 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... I 24 hr Recap: rate to 240 gpm-600 psi increase- f no MWD detection. RIH F/13445'-T/13650'-pumped 30 bbls sweep.Circ F/13386'-T/13350'-lost detection. POOH T/12550'- t Displace to 10.1 ppg,MWD started to detect intermittently.POOH F/12550'-T/12036'.Finish displacing well to a 10.1 ppg. I dumped 30 bbls mud. R/D RCD element.Slugging pipe at report time in preparation to POOH. Maintained 12.0 ppg EMW w/MPD I until displacing well to kill weight mud.Currently POOH at report time, I From midnight to midnight:-36 bbls(-26 Losses from Solids Control Equipment,-10 down hole losses observed) Midnight to 0400:-13 bbls loss while POOH Logging Engineer: *Colby Marks/Mark Lindloff * 10000 units = 100% Gas In Air Customer: Pioneer Natural Res. Report#: 59 HALLIBURTON Well: ODSN-18 Date: 1/3/2011-04:00 Area: Oooguruk 04:00 Depth 13833' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH Job No.: AK-AM-0007650103 Report For: J. Polya/J. Cortez Daily Charges $6,361.15 Total Charges: $356,922.79 ROP & Gas: _ Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 0.0 0.0 0.0 0' Flow In (gpm) 0 SPP(psi) 0 Gas(units) 0 0 0 Circulating Flow In (spm) 0 Gallons/stroke _ 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling NA Min NA Avg NA Max Hole Condition 13833' 6.43" PWD All Circ NA Min NA Avg NA Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in _ out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Porn) ok 13832' 10.20 10.20 78 6.0 21 8 1343.0 7.25 5.60 18.8 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1500 Sec FXG64 6.125 0.389 13375' 1400 Sec FXG64 6.125 0.389 13.28 12320' 13833' 1513' 14 127 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal _ Gvl Tuff (current) 60 40 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: 0 Avg: 0 Gas (units) Chromatograph (ppm) Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 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: POOH w/6 1/8"BHA F/12036'-lost 33 bbls downhole. L/D same.Test BOPE. M/U 6 1/8"BHA at report time to open- hole sidetrack for Sidetrack#4.Currently RIH with BHA 15 From midnight to midnight:-51 bbls(-18 Losses from Solids Control Equipment,-33 Displacement while POOH) Midnight to 0400:-5 bbls loss while RIH Logging Engineer: "Colby Marks/Mark Lindloff * 10000 units = 100% Gas In Air Customer: Pioneer Natural Res. Report#: 60 1ALLIBURTOI\ Well: ODSN-18 Date: 1/4/2011-04:00 Area: Oooguruk 04:00 Depth 13389' Location: North Slope Progress 24 hrs: 14' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Time Drilling Job No.: AK-AM-0007650103 Report For: J. Polya/J. Haberthur Daily Charges $6,361.15 Total Charges: $363,283.94 ROP & Gas: Current R.O.P. (ft/hr) Avg 24 hr Max Max @ ft Current Pump & Flow Data: 3.0 1.6 2.2 13384' Flow In (gpm) 203 SPP (psi) 1972 Gas(units) 23 18 2505 B/U Flow In (spm) 58 Gallons/stroke 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling 10.14 Min 10.14 Avg 12.66 Max Hole Condition 13833' 9.82 30 bbls 6.74" PWD All Circ 9.82 Min 10.31 Avg 12.76 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Pom) 13832' 7.90 7.90 48 4.4 10 6 2000.0 4.92 3.80 4.9 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1500 _ Sec FXG64 6.125 0.389 13375' 1400 Sec FXG64 6.125 0.389 13.28 12320' 13833' 1513' 14 127 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Avg: 1 Ambient Air Pit Room Max: 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 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... i 24 hr Recap: at 13377'. 10.1 ppg Kill Weight to 7.9 ppg-displaced kill mud light coming back 9.5-9.7 ppg.Timedrilling at 13384'to kick off open hole sidetrack at report time(Sidetrack#4 13375'MD). MPD holding 10.2 ppg EMW-changed RCD element.Continue Time Drilling at report time. From midnight to midnight:-37 bbls(-20 Losses from Solids Control Equipment,-17 Displacement while RIH) Midnight to 0400:0 bbls loss while Drilling Logging Engineer: *Colby Marks/Mark Lindloff * 10000 units= 100% Gas In Air — Customer: Pioneer Natural Res. Report#: 61 HALLIBURTON Well: ODSN-18 Date: 1/5/2011-04:00 Area: Oooguruk 04:00 Depth 14563' Location: North Slope Progress 24 hrs: 1174' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0007650103 Report For: J. Polya/J. Haberthur Daily Charges $6,361.15 Total Charges: $369,645.09 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 81.0 92.0 203.0 13951' Flow In(gpm) 238 SPP(psi) 3445 Gas(units) 23 86 467 13481' Flow In(spm) 68 Gallons/stroke 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 10.06 Min 12.10 Avg 13.83 Max 14563' 29.12 30 bbls 6.74" All Circ 10.03 Min 12.15 Avg 13.83 Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Porn) % 13832' 7.85 7.85 45 4.6 9 5 2000.0 3.50 2.70 4.7 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1 1500 Sec FXG64 6.125 _ 0.389 13375' 1400 Sec FXG64 6.125 0.389 13.28 12320' 13833' 1513' 14 127 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 20 80 Gas Breakdown H2S Data I Sample Line Max: Avg: 1 Ambient Air Pit Room Max: 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 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: Con't time-drilling to kick off 6 1/8"Sidetrack 4 F/13382'-T/13386'.Service rig.Drill F/13386'-T/14062'.Service rig. _ _MPD held 10.15 ppg ECD while time-drilling.The ECD was increased incrementally to 12.5 ppg-lost 4 bbls while increasing ECD.MPD held 12.5 ppg EMW until 14035',where the ECD was increased to a 12.8.Currently drilling ahead w/MPD holding a 12.9 ppg ECD. Samples grading from 85%Sandstone to 80%Siltstone when crossing fault.Gas has been negligible. From midnight to midnight:-35 bbls(-31 Losses from Solids Control Equipment,-4 Downhole) Midnight to 0400:-8 bbls loss while Drilling Logging Engineer: *Colby Marks/Mark Lindloff * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 62 4ALLIRURTDN Well: ODSN-18 Date: 1/6/2011-04:00 Area: Oooguruk 04:00 Depth 13250' Location: North Slope Progress 24 hrs: -1593' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0007650103 Report For: R. Klepzig//J. Haberthur Daily Charges $6,361.15 Total Charges: $376,006.24 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 1.8 106.6 211.0 14645' Flow In (gpm) 202 _ SPP (psi) 1872 Gas (units) 39 64 381 Circ Flow In (spm) 57 Gallons/stroke 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 12.53 Min 12.94 Avg 13.71 Max 14563' 29.12 30 bbls 6.74" All Circ 9.72 Min 11.11 Avg 13.71 Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Pom) % 13832' 7.85 7.90 44 4.6 10 6 2000.0 1.04 0.80 5.1 BHA Run # Bit Type Size TEA Hours Depth in/out Footage WOB RPM Condition 1500 Sec FXG64 6.125 0.389 31.86 13375' 14843' 1468' 17 115 OH Sidetrack 1600 Sec FXG64 6.125 0.389 13250' Litholo % : Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff 9Y1 ) Y (current) 20 80 Gas Breakdown H2S Data I Sample Line'Max: Avg: I Ambient Air Pit Room Max: 0 Avg: 0 Gas (units) Chromatograph (ppm) Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 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: Cont drilling 6 1/8"Sidetrack 4 F/14255'-T/14843'-MPD holding 12.8 ppg EMW.Circ 4x OH volume.Trip out of hole F/14843'-T/13465'.Working pipe at 13465'-circ 240 gpm,unable to rotate. Reduce EMW w/MPD F/12.8 ppg to 10.1 ppg. Work pipe.Spotted lube pill at BHA-allow to soak-pump 1 bbl/min.Circ pill out while working pipe.Free pipe.Backream F/13465'-T/13387'.Repairing TD at report time.MPD maintaining 9.8 ppg EMW.Prep for openhole sidetrack. Currently troughing to kick off Side Track 5. From midnight to midnight:40 bbls(-32 Losses from Solids Control Equipment,-8 Downhole) Midnight to 0400:0 bbls loss while Drilling Logging Engineer: *Colby Marks/Mark Lindloff * 10000 units= 100%Gas In Air . I Customer: Pioneer Natural Res. Report#: 63 IALLIBURTOIN Well: ODSN-18 Date: 1/7/2011-04:00 Area: Oooguruk 04:00 Depth 13324' Location: North Slope Progress 24 hrs: 74' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Time Drilling Job No.: AK-AM-0007650103 Report For: R. Klepzig//J. Haberthur Daily Charges $6,361.15 Total Charges: $382,367.39 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 1.0 14.4 29.4 14645' Flow In (gpm) 202 SPP (psi) 1856 Gas (units) 44 48 230 Circ Flow In (spm) 57 Gallons/stroke 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling 9.74 Min 9.91 Avg 10.20 Max Hole Condition 13324' 13 30 bbls 6.74" PWD All Circ 9.73 Min 9.90 Avg 10.20 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft_ in out (sec/qt) (ml/30 min) cP , (Ib/100ft2) (volt) (lbs/bbl) (Pom) 13832' 7.85 7.85 45 4.4 8 6 2000.0 4.53 3.50 4.8 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM _ Condition f 1500 Sec FXG64 6.125 0.389 31.86 13375' 14843' 1468' . 17 115 OH Sidetrack 1600 k Sec FXG64 6.125 0.389 13250' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 100 Gas Breakdown H2S Data Sample Line Max: Avg: Ambient Air Pit Room Max: 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth Max Gas Avg Gas C1 C2 C3 C4 C5 Type 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: POOH F/13387'-1/13194'.Service rig.Trough F/13220'-T/13250'to open-hole sidetrack well for Sidetrack 5. Time-drill F/13250'-T/13324'-old wellbore.Service rig.Bacckream F/13324'-T/13238'.Trough F/13238'-T/13268. Trough to kick off 6 1/8"openhole sidetrack(Sidetrack 5 13250'MD). MPD maintaining 9.8 ppg EMW. iF/13465'-T/13387'. MPD maintaining 9.8 ppg EMW.Pull back and openhole sidetrack.Currently Time Drilling From midnight to midnight:-15 bbls(-15 Losses from Solids Control Equipment,0 Downhole) Midnight to 0400:0 bbls loss while Drilling Logging Engineer: *Colby Marks/Mark Lindloff " 10000 units= 100%Gas In Air 1 Customer: Pioneer Natural Res. Report#: 64 HALLIBU , ('ON Well: ODSN-18 Date: 1/8/2011-04:00 Area: Oooguruk 04:00 Depth 13484' Location: North Slope Progress 24 hrs: 160' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Changing RCD Job No.: AK-AM-0007650103 Report For: R. Klepzig//J. Haberthur Daily Charges $6,361.15 Total Charges: $388,728.54 ROP & Gas: Current Avg 24 hr Max Max @ ft \ Current Pump & Flow Data: R.O.P. (ft/hr) 0.0 115.6 158.2 14645' Flow In (gpm) 202 SPP(psi) 1858 Gas (units) 0 47 1 389 Circ Flow In (spm) 57 Gallons/stroke 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 9.73 Min 9.91 Avg 9.97 Max 13484' 35 30 bbls 6.74" All Circ 9.71 Min 9.89 Avg 10.12 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Pom) % 13832' 7.85 7.85 46 4.4 9 6 2000.0 4.53 3.50 4.8 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1500 Sec FXG64 6.125 0.389 31.86 13375' 14843' 1468' 17 115 OH Sidetrack 1600 Sec FXG64 6.125 0.389 13250' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst _ Coal Gvl Tuff (current) 100 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 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: Con't troughing to kick-off 6 1/8"Sidetrack 5.Trough F/13238'-T/13268'.Time-drill F/13268'-T/13291'.Service rig. Continue time drilling at 13291-13324'. MPD maintaining 9.8 ppg EMW.Start drilling F/13224'T/13484'. Drill out of formation change out MPD RCD Bearing while waiting on orders from town. From midnight to midnight:-24 bbls(-24 Losses from Solids Control Equipment,0 Downhole) Midnight to 0400:0 bbls loss while Drilling Logging Engineer: *Colby Marks/Mark Lindloff * 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. Report#: 65 IALLIBURTON Well: ODSN-18 Date: 1/9/2011-04:00 Area: Oooguruk 04:00 Depth 14544' Location: North Slope Progress 24 hrs: 1060' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Ahead Job No.: AK-AM-0007650103 Report For: R. Klepzig//J. Haberthur Daily Charges $6,361.15 Total Charges: $395,089.69 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 70.7 _ 108.0 293.0 13683' Flow In (gpm) 243 SPP (psi) 3496 Gas (units) 339 214 759 Circ Flow In (spm) 68 Gallons/stroke 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling 12.50_Min 12.86 Avg 13.15 Max Hole Condition 14544' 46.92 30 bbls 6.74" PWD All Circ 9.83 Min 12.78 Avg 13.68 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in _ out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Pom) % 13832' 7.90 7.90 47 4.4 14 6 2000.0 3.89 3.00 5.5 BHA Run # Bit Type Size TFA Hours Depth in/out Footage _ WOB RPM Condition 1500 Sec FXG64 6.125 0.389 31.86 13375' 14843' 1468' 17 115 OH Sidetrack 1600 Sec FXG64 6.125 0.389 13250' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal _ Gvl Tuff (current) 100 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type to to to to to to to to 11 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: at report time T/13350'-stage pumps up.C/O RCD element increased EMW w/MPD staging up in 0.3 ppg increments from 10.1 ppg to 12.8 ppg.Wash/ream F/13350'-T/13484'-work tight hole/pack offs-lost 108 bbls downhole. Drill F/13484'-T/14062'.Service TD. Drilling ahead.Samples 100%SST since 13850'MD, Gas varying from 200-400 units. From midnight to midnight:-157 bbls(-49 Losses from Solids Control Equipment,-108 Downhole) Midnight to 0400:0 bbls loss while Drilling k _Logging Engineer: *Colby Marks/Mark Lindloff * 10000 units= 100%Gas In Air l Customer: Pioneer Natural Res. Report#: 66 HALLIBURTON Well: ODSN-18 Date: 1/10/2011-04:00 Area: Oooguruk 04:00 Depth 16269' Location: North Slope Progress 24 hrs: 1725' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Ahead Job No.: AK-AM-0007650103 Report For: R. Klepzig//J. Haberthur Daily Charges $6,361.15 Total Charges: $401,450.84 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) _ 131.0 112.6 326.0 16221' Flow In (gpm) 240 SPP(psi) 3617 Gas (units) 364 235 588 15253' Flow In (spm) 67 Gallons/stroke 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling 12.52 Min 12.99 Avg 13.26 Max Hole Condition 16262' 65.2 50 bbls 6.90" PWD All Circ 12.52 Min 12.98 Avg 13.28 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (m1/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Porn) ok 13832' 8.00 8.00 47 4.4 14 6 1517.0 5.44 4.20 5.3 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1500 Sec FXG64 6.125 0.389 31.86 13375' 14843' 1468' 17 115 OH Sidetrack 1600 ' Sec FXG64 6.125 0.389 13250' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 100 Gas Breakdown H2S Data I Sample Line Max: !Avg: I Ambient Air Pit Room Max: 0 'Avg: 0 Gas (units) Chromatograph (ppm) Depth Max Gas Avg Gas C1 C2 C3 C4 C5 Type 14544' to 15000' 449 249 50162 1720 666 242 75 GP 15000' 16000' 588 233 65730 2251 805 271 87 GP 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: report time at ahead at report time at 15895'. MPD maintaining 12.8 ppg EMW at 13350'.Sporadic seepage losses while drilling. From midnight to midnight:-189 bbls(-145 Losses from Solids Control Equipment,-44 Downhole) Midnight to 0400:0 bbls loss while Drilling Logging Engineer: *Colby Marks/Mark Lindloff * 10000 units= 100% Gas In Air lit Customer: Pioneer Natural Res. Report#: 67 HALLIBURTON Well: ODSN-18 Date: 1/11/2011-04:00 Area: Oooguruk 04:00 Depth 16689' Location: North Slope Progress 24 hrs: 420' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Ahead Job No.: AK-AM-0007650103 Report For: R.Klepzig//J. Haberthur Daily Charges $6,361.15 Total Charges: $407,811.99 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) 0.0 97.0 253.0 16221' Flow In (gpm) 238 SPP(psi) 3629 Gas(units) 17 126 323 15253' Flow In (spm) 68 Gallons/stroke 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 12.83 Min 13.11 Avg 13.26 Max 16689' 71.36 50 bbls 6.90" All Circ 12.19 Min 13.09 Avg 13.39 Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Pom) % 16689' 8.00 8.00 46 4.2 11 6 1698.0 5.96 4.60 5.5 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1500 Sec FXG64 6.125 0.389 31.86 13375' 14843' 1468' 17 115 OH Sidetrack 1600 Sec FXG64 6.125 0.389 71.36 13250' 16689' 3439' 17 122 Lithology (%): ' Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 90 10 Gas Breakdown H2S Data I Sample Line Max: Avg: 1 Ambient Air Pit Room]Max: 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 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: Cont drilling 6 1/8"Sidetrack 5. Drill F/15895'-T/16570'.Circ while waiting on orders.Drill F/16570'-T/16606'. POOH F/16606'-T/16240'.C/O MPD element-troubleshoot MPD-mud in hydraulic oil.RIH F/16240'-T/16606'.Drill F/16606'- T/16689'-geopilot not holding toolface-out of zone.Service rig.Circ 4 x BU and Currently short tripping to shoe. MPD maintaining 12.8 ppg EMW at 13350'. Increase of siltstone to 80%was observed in samples From 16400'to 16500'.From 16500 to 166689 Sandstone returned to 90%. Gas dropped off at 18642'MD.Averaging before 240 units and after 90 units. From midnight to midnight:-117 bbls(-109 Losses from Solids Control Equipment,-8bbls Downhole) Midnight to 0400:0 bbls loss while Drilling Logging Engineer: *Colby Marks/Mark Lindloff * 10000 units= 100%Gas In Air P Customer: Pioneer Natural Res. Report#: 68 HALLIBURTON Well: ODSN-18 Date: 1/12/2011-04:00 Area: Oooguruk 04:00 Depth 16689' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Ahead Job No.: AK-AM-0007650103 Report For: R. Klepzig//J. Haberthur Daily Charges $6,361.15 Total Charges: $414,173.14 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) NA NA NA NA Flow In (gpm) 181 SPP (psi) 1807 Gas (units) 13 9 117 Cir Flow In (spm) 51 Gallons/stroke 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling NA Min NA Avg NA Max 16689' 71.36 50 bbls 6.90" All Circ 11.21 Min 12.38 Avg 13.05 Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft _ in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Pom) 16689' 8.00 8.00 46 4.4 11 6 1856.0 5.44 4.80 5.6 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1500 Sec FXG64 6.125 0.389 31.86 13375' 14843' 1468' 17 115 OH Sidetrack 1600 Sec FXG64 6.125 0.389 71.36 13250' 16689' 3439' 17 122 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 90 10 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room 'Max: 0 Avg: 0 Gas (units) Chromatograph (ppm) Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 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... 1 24 hr Recap: Finish circ 4 x BU-pulling 1 std every BU. POOH F/16281'-T/12030'-backream F/13373'-T/13380'.0/0 swivel packing/service TD. MPD reduce EMW from 12.8 ppg at 13350'to 12.0 ppg EMW at 7"shoe.RIH F/12030'-T/13387'. _ Wash/ream F/13387'-T/13484'-tight 13413'and 13425'.RIH F/13484'-T/16689'.Stage pump to 240 gpm.Pump 30 bbls Hi-vis. sweep-minimal increase in cuttings.Spot 170 bbls LVT in openhole. POOH to11997'Currently Displacing to 12 ppg kill mud. MPD maintaining 12.0 ppg EMW at 7"shoe. No TG noted at Bottoms up From midnight to midnight:-127 bbls(-25 Losses from Solids Control Equipment,-102 bbls Downhole) Midnight to 0400: 15 bbls loss down hole while Displacing Logging Engineer: *Colby Marks/Mark Lindloff ` 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 69 AALLidURTON Well: ODSN-18 Date: 1/13/2011-04:00 Area: Oooguruk 04:00 Depth 16689' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH W/4.5"Liner Job No.: AK-AM-0007650103 Report For: R. Klepzig//J. Cortez i E Daily Charges $6,361.15 Total Charges: $420,534.29 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: i! R.O.P. (ft/hr) NA . NA NA NA Flow In (gpm) 0 SPP(psi) 0 Gas (units) 0 6 61 Cir Flow In (spm) 0 Gallons/stroke 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling NA Min NA Avg NA Max 16689' 71.36 50 bbls 6.90" All Circ 0.00 Min 0.00 Avg 0.00 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) _ (lbs/bbl) (Pom) % 16689' 12.00 12.00 73 9.8 31 12 1348.0 3.37 2.60 22.0 BHA Run # Bit Type _ Size TFA Hours Depth in/out Footage WOB RPM Condition 1500 Sec FXG64 6.125 0.389 31.86 13375' 14843' 1468' 17 115 OH Sidetrack 1600 Sec FXG64 6.125 0.389 71.36 13250' 16689' 3439' 17 122 1-1-NO-A-X-I-NO-DTF Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 90 10 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: 0 Avg: 0 Gas (units) Chromatograph (ppm) Depth Max Gas Avg Gas C1 C2 C3 C4 C5 Type 1 I to to to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; I POG- Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T---Trip...; F--- Formation...; E--- Early... 24 hr Recap: Continue displacing to 12.0 ppg OBM(625 bbls pumped around before 12.0 ppg OBM returned to surface). Finish POOH and LD BHA. PU and rack back 21 JT HWDP.Rig up to run 4.5"liner,Currently RIH with 4.5"Liner. Receiving 0.5-1.2 bbls while RIH. u II From midnight to midnight:-109 bbls(-85 Losses from Solids Control Equipment,-24 bbls Displacement POOH) Midnight to 0400:--5.88 bbls for 50 Jnts while RIH with 4.5"Liner.(Calculated+8.43 bbls) Logging Engineer: *Colby Marks/Mark Lindloff * 10000 units= 100% Gas In Air Customer: Pioneer Natural Res. Report#: 70 HALLIBURTON Well: ODSN-18 Date: 1/14/2011-04:00 Area: Oooguruk 04:00 Depth 16689' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Weighting up Brine Job No.: AK-AM-0007650103 Report For: R. Klepzig//J. Cortez Daily Charges $5,793.14 Total Charges: $426,327.43 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) NA NA NA NA Flow In (gpm) 0 SPP (psi) 0 Gas (units) 0 6 161 Cir Flow In (spm) 0 Gallons/stroke 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling NA Min NA Avg NA Max Hole Condition 16689' 71.36 50 bbls 6.90" PWD All Circ 0.00 Min 0.00 Avg 0.00 Max • Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Pom) 16689' 11.00 11.00 79 10.0 32 12 1281.0 3.24 2.50 20.4 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1500 Sec FXG64 6.125 0.389 31.86 13375' 14843' 1468' 17 115 OH Sidetrack 1600 Sec FXG64 6.125 0.389 71.36 13250' 16689' 3439' 17 122 1-1-NO-A-X-I-ER-DTF Lithology (%): Sd Sst _ Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 90 10 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: 0 Avg: 0 Gas (units) Chromatograph (ppm) Depth Max Gas Avg Gas C1 C2 C3 C4 C5 Type to _ E to to to I to I 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: RIH w/4.5"liner to 4461'.MU and RIH w/liner setting sleeve to 4624'.Continue RIH w/4'DP to 12044'.Circulate 132 bbls OBM while monitoring MW(MW in 11.05 ppg,MW out 10.8ppg). RIH and set liner at 16399'(top of liner at 11914').Brake away and circulate BU from top of liner while monitoring MW(returning MW range from 10.8 ppg to 12.8 ppg).Trip Gas 161 units. Displace well with 10 ppg Brine. Performed Static Well Check, well gained 1 bbl/10 minutes.Currently increasing Brine weight to 10.2 ppg. { From midnight to midnight:0 bbls(-0 Losses from Solids Control Equipment,-0 bbls Displacement RIH w/4.5"Liner) Midnight to 0400:During Staic Test well gained 1 bbl/10 min=6 bbls/hr Logging Engineer: *Colby Marks/Mark Lindloff * 10000 units= 100% Gas In Air -- Customer: Pioneer Natural Res. Report#: 71 HALLIBURTON Well: ODSN-18 Date: 1/15/2011 -04:00 Area: Oooguruk 04:00 Depth 16689' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH with 4.5"Tubing Job No.: AK-AM-0007650103 Report For: R. Klepzig//J.Cortez Daily Charges $4,884.32 Total Charges: $431,211.75 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na _ Flow In (gpm) - 0 SPP(psi) 0 Gas(units) 0 0 0 na Flow In (spm) 0 Gallons/stroke 3.5540 Depth On Bot Hrs Ann Corr Avg Diam Drilling NA Min NA Avg NA Max Hole Condition 16689' 71.36 50 bbls 6.90"—PWD All Circ 0.00 Min 0.00 Avg 0.00 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Pom) % 16689' 10.20 10.20 28 - - - - - - - BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1500 Sec FXG64 6.125 0.389 31.86 13375' 14843' 1468' 17 115 OH Sidetrack 1600 Sec FXG64 6.125 0.389 71.36 13250' 16689' 3439' 17 122 1-1-NO-A-X-I-ER-DTF Lithology (%): Sd Sst Silt Siltst _ Cht Clyst _ Sh _ Lst Coal Gvl Tuff _ (current) 90 10 Gas Breakdown H2S Data I Sample Line'Max: 'Avg: I Ambient Air Pit Room Max: 0 Avg: 0 Gas(units) Chromatograph (ppm) Depth Max Gas Avg Gas C1 C2 C3 C4 C5 Type 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: Finished displacing well with 10.20ppg Brine well flowing at 3 bbl/hr. Pumped dry job and noted the well was no longer flowing. Pulled out of the hole with no losses or gains. Rigged up to run 4.5"Tubing and began running in with same. Losses from midnight to midnight were 10 bbls. Logging Engineer: Colby Marks/Ryan Massey " 10000 units= 100%Gas In Air Customer: Pioneer Natural Res. __ Report#: 72 HALLIBUk rON Well: ODSN-18 Date: 1/16/2011 -04:00 Area: Oooguruk 04:00 Depth 16689' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Job No.: AK-AM-0007650103 Report For: R. Klepzig//J.Cortez Daily Charges $5,849.12 Total Charges: $437,070.87 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. (ft/hr) na na na na _Flow In (gpm) 0 SPP(psi) 0 Gas(units) 0 0 0 na Flow In (spm) 0 Gallons/stroke 3.5540 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling NA Min NA Avg NA Max 16689' 71.36 50 bbls 6.90" All Circ 0.00 Min 0.00 Avg 0.00 Max Mud Data: Density(ppg) Viscosity HTHP PV YP Elec Stab Lime Alkai Cor Solids Depth ft in out (sec/qt) (ml/30 min) cP (Ib/100ft2) (volt) (lbs/bbl) (Porn) % 16689' 10.20 10.20 28 - - - - - - - BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 1500 Sec FXG64 6.125 0.389 31.86 13375' 14843' 1468' 17 115 OH Sidetrack 1600 Sec FXG64 6.125 0.389 71.36 13250' 16689' 3439' 17 122 1-1-NO-A-X-I-ER-DTF Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst _ Coal Gvl Tuff (current) 90 10 Gas Breakdown H2S Data 1 Sample Line Max: IAvg: I Ambient Air Pit Room !Max: 0 IAvg: 0 Gas(units) Chromatograph (ppm) Depth Max Gas Avg Gas Cl C2 C3 C4 C5 Type 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: Ran 4.5"Tubing to 11914'MD and landed hanger. No gains/losses during trip in hole. Pressure testing Seal Assembly and annulus to 2200psi at time of report. Losses from midnight to midnight were negligable. Sample Catchers on SOA through 1/15/11. Sample Supplies were included in today's Daily Charges. Logging Engineer: Colby Marks/Ryan Massey * 10000 units= 100%Gas In Air (13 N Q 0 Y N CO mCi N CL o a d Y x a C J N C d J Y I . y 0 0 0 y li 0 0 0 0 0 0 . <n 7- y 7 1- F- F- F- F- I- t 45 d o a o C. 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N CU( (O r CD C O .- CV M V US NNNNNNNNNNO (7 HALLIBURTON PIONEER Sperry Drilling NATURAL RESOURCES ODSN-18 PB1 Interpolated Tops Marker MD INC AZ TVD TVDSS Top of Permafrost 838.00 5.17 282.09 837.12 780.92 Base of Permafrost 1681.00 13.61 273.65 1668.09 1611.89 Top West Sak 2331.00 15.83 274.40 2297.13 2240.93 Tuffaceous Shale 3098.00 39.77 266.05 2958.91 2902.71 Hue_1 3320.00 45.20 265.24 3123.63 3067.43 Top of 9 518"Liner 3320.00 45.20 265.24 3123.63 3067.43 Hue 2 3506.00 49.38 265.01 3249.04 3192.84 SCP 3600.00 50.14 265.11 3309.44 3253.24 Brook 2B 5681.00 70.66 258.19 4267.98 4211.78 Torok Top 7910.00 69.20 260.21 5009.93 4953.73 Torok Base 8535.00 69.46 258.26 5228.86 5172.66 ICP1 8824.00 69.15 258.51 5329.15 5272.95 Torok SH_1 9043.00 69.43 261.48 5407.51 5351.31 Poss Black 1 fx zone 9668.00 70.53 280.83 5625.88 5569.68 Violet3 Fault 10000.00 71.09 289.80 5737.02 5680.82 Top HRZ 10056.00 71.41 290.92 5755.01 5698.81 Base HRZ 10518.00 74.09 303.97 5887.55 5831.35 Kalubik Marker 10851.00 77.27 314.39 5967.16 5910.96 Top Kup C 11110.00 76.19 325.97 6027.08 5970.88 LCU 11118.00 76.22 326.29 6028.99 5972.79 BCU 11562.00 80.38 335.28 6116.86 6060.66 Top Nuiqsut_D1 11808.00 80.42 336.32 6158.89 6102.69 Top Nuiq::Nuiq_1_D1 11868.00 80.62 336.06 6168.73 6112.53 ICP2 11880.00 80.62 336.06 6170.69 6114.49 Nuiq_1::Nuiq_2_D1 Nuiq_2::Nuiq 3 D1 Nuiq_3::Nuiq_4_D1 Nuiq_4::Nuiq_5_D1 T3 T4(Invert#1) T5 Nuiq_5::Nuiq_4_U2 Nuiq_4::Nuiq_3_U2 Nuiq_3::Nuiq_2_U2 Nuiq_2::Nuiq_1_U2 T6 T7(Revert#2) Nuiq_1::Nuiq_2_D3 Nuiq_2::Nuiq_3_D3 Nuiq_3::Nuiq_4_D3 Nuiq_4::Nuiq_5_D3 19 '10(Invert#2) Nuiq_5::Nuiq_4_U4 Nuiq_4::Nuiq_3_U4 Nuiq_3::Nuiq_2_U4 Nuiq_2::Nuiq_1_U4 T13(Revert t#3) T14 Nuiq_1::Nuiq_2_D5 Nuiq_2::Nuiq_3_D5 Nuiq_3::Nuiq_4_D5 Nuiq_4::Nuiq_5_D5 Nuiq_5::Transition Zone Nuiq_5::Nuiq_Base_D5 T15-TD HALLIBURrrHJ PIONEER Sperry Drilling \i 11 .fyi 10. .:;( )l.iliC:E _:_ ODSN-18 PB2 Interpolated Tops Marker MD INC AZ TVD TVDSS Top of Permafrost 838.00 5.17 282.09 837.12 780.91 Base of Permafrost 1681.00 13.61 273.65 1668.09 1611.89 Top West Sak 2331.00 15.83 274.40 2297.13 2240.93 Tuffaceous Shale 3098.00 39.77 266.05 2958.91 2902.71 Hue_1 3320.00 45.20 265.24 3123.63 3067.43 Top of 9 5/8"Liner 3320.00 45.20 265.24 3123.63 3067.43 Hue 2 3506.00 49.38 265.01 3249.04 3192.84 SCP 3600.00 50.14 265.11 3309.44 3253.24 Brook 2B 5681.00 70.66 258.19 4267.98 4211.78 Torok Top 7910.00 69.20 260.21 5009.93 4953.73 KOP Top of the Window 8438.00 69.60 258.48 5195.01 5138.81 Torok Base 8540.00 72.60 255.05 5227.59 5171 39 Torok SH_1 9165.00 72.54 256.48 5405.49 :9 Torok SH_2 9396.00 72.21 265.67 5475.13 5418.93 Torok SH_3 9713.00 72.01 277.33 5572.69 5516.49 Poss fracture zone(losses) 9838.00 71.37 281.76 5611.89 5555.69 Torok SH_4 9932.00 71.41 286.17 5641.90 5585.70 Violet 3 Fault-21'DTNE 10052.00 71.58 290.45 5680.15 5623.95 Top HRZ 10310.00 71.94 299.26 5759.94 5703.74 Base HRZ 10758.00 74.79 311.29 5887.07 5830.87 Kalubik Marker 11083.00 75.71 318.40 5971.99 5915.79 Top Kup C 11323.00 76.47 327.12 6031.05 5974.85 LCU 11330.00 76.55 327.38 6032.68 5976.48 BCU 11831.00 79.89 339.14 6129.03 6072.83 Top Nuigsut_D1 12056.00 80.08 343.00 6168.75 6112.55 Top Nuiq::Nuiq_1_D1 12074.00 80.12 343.44 6171.85 6115.65 ICP2 12090.00 80.21 343.93 6174.59 6118.39 Nuiq_1::Nuiq_2_D1 12260.00 78.69 345.95 6206.03 6149.83 Nuiq_2::Nuiq_3_D1 12300.00 79.46 345.83 6213.62 6157.42 FAULT 1 Zone 3::Zone 5 D1(10'DTSE) 12350.00 80.86 344.89 6222.25 6166.05 FAULT 2 Zone 5::Zone 5 D1(10'DTSE) 12540.00 85.61 339.05 6243.21 6187.01 FAULT 3 Zone 5::Nechelik D 1(40'DTSE) 12825.00 87.03 333.98 6258.46 6202.26 T3 Invert#1 13028.00 90.03 333.42 6273.57 6217.37 Top Nechelik::Bas Nuiq_U2 13390.00 93.67 330.17 6261.36 6205.16 TD 13499.00 93.67 330.17 6254.38 6198.18 i It HALLIBURTON PIONEER Sperry Drilling NATURAL RESOURCES ODSN-18PB3 Interpolated Tops Marker MD INC AZ TVD TVDSS ICP2(Sidetrack#2 f/ICP2) 12090.00 80.21 343.64 6174.98 Nuiq_1::Nuiq_2_D1 12400.00 83.99 338.66 6211.56 6155.36 Nuiq_2::Nuiq_3_D1 12450.00 83.93 340.97 6216.82 6160.62 12614.65 90.00 341.72 6225.82 6169.62 Nuiq_3::Nuiq_2_D1 12652.00 91.14 341.00 6225.44 6169.24 Nuiq_2::Nuiq_1_U2 12677.00 91.89 340.51 6224.78 6168.58 FAULT 1 Zone_1::Zone_5(-58'DTSE) 12806.00 93.45 337.35 6218.20 6162.00 Nuiq_5::Nuiq_4_U2 13118.00 93.36 326.04 6198.44 6142.24 FAULT 2 Zone_4::Kingak(-60 DTNW) 13150.00 93.51 324.36 6196.52 6140.32 Revert#1 13510.10 90.00 325.62 6177.57 6121.37 Kingak::BCU_D3 13545.00 88.66 325.37 6177.98 6121.78 CBU::Top Nuiq_D3 13700.00 82.77 323.80 6189.42 6133.22 Top Nuiq::Nuiq_1_D3 13735.00 81.38 323.29 6194.25 6138.05 FAULT 3 Zone_1::Nechelik(-90'DTSE) 13838.00 81.47 320.84 6209.60 6153.40 TD 13920.00 81.47 320.84 6221.77 6165.57 HALLIBURTON PIONEER Sperry Drilling ,' ODSN-18PB4 Interpolated Tops Marker MD INC AZ TVD TVDSS Sidetrack#3 KOP(open hole) 12850.00 93.34 336.38 6215.59 6159.3 FAULT 2 Zone_5::Zone_1 (-60'DTNW) 13200.00 90.84 324.69 6206.44 6150.24 Nuiq_1::Top Nuiq_U1 13420.00 93.37 320.56 6203.46 6147.26 Small Fault Top Nuiq::Zone_1 (-5'DTSE) 13445.00 94.32 320.50 6201.79 6145.59 Nuiq_1::Top Nuiq_U1 13498.00 95.70 320.43 6197.15 6140.95 Top Nuiq::Kingak_U1 13525.00 96.40 320.40 6194.31 6138.11 Kingak::BCU_U1 13730.00 97.90 321.05 6168.18 6111.91 TD 13832.00 97.94 321.09 6154.10 6097.91: HALLIBU RTO Sperry Drilling NAFURAL__ HHELSOURCt ODSN-18PB5 Interpolated Tops Marker MD INC AZ TVD TVDSS Sidetra, 13375.00 91.68 320.68 6205.45 6149.25 Small Fault Nuiq_1::Kingak(-8'DTNW) 13508.00 91.24 317.25 6202.72 _ 6146.52 FAULT 3 Kingak::Kingak(-20'DTNW) 13725.00 93.75 316.74 6190.71 6134.51 Kingak::BCU_U2 14040.00 94.17 _ 318.69 6167.40 6111.20 Revert#1 14206.63 90.00 320.29 6158.87 6102.67 BCU::Kingak_D3 14670.00 82.33 319.99 6193.67 _ 6137.47 TD 14843.00 82.15 317.76 6216.77 6160.57 HALLIBURTON PIONEER Sperry Drilling NATURAL RESOURCES ODSN-18 Interpolated Tops Marker MD INC AZ TVD TVDSS Top of Permafrost 838.00 5.17 282.09 837.12 -.,... Base of Permafrost 1681.00 13.61 273.65 1668.09 1611.89 Top West Sak 2331.00 15.83 274.40 2297.13 2240.93 Tuffaceous Shale 3098.00 39.77 266.05 2958.91 2902.71 Hue_1 3320.00 45.20 265.24 3123.63 3067.43 Top of 9 518"Liner 3320.00 45.20 265.24 3123.63 3067.43 Hue 2 3506.00 49.38 265.01 3249.04 3192.84 SCP 3600.00 50.14 265.11 3309.44 3253.24 Brook 2B 5681.00 70.66 258.19 4267.98 4211.78 Torok Top 7910.00 69.20 260.21 5009.93 4953.73 KOP Top of the Window 8438.00 69.60 258.48 5195.01 5138.81 Torok Base 8540.00 72.60 255.05 5227.59 5171.39 Torok SH_1 9165.00 72.54 256.48 5405.49 5349.29 Torok SH_2 9396.00 72.21 265.67 5475.13 5418.93 Torok SH_3 9713.00 72.01 277.33 5572.69 5516.49 Poss fracture zone(losses) 9838.00 71.37 281.76 5611.89 5555.69 Torok SH_4 9932.00 71.41 286.17 5641.90 5585.70 Violet 3 Fault-21' D INE 10052.00 71.58 290.45 5680.15 5623.95 Top HRZ 10310.00 71.94 299.26 5759.94 5703.74 Base HRZ 10758.00 74.79 311.29 5887.07 5830.87 Kalubik Marker 11083.00 75.71 318.40 5971.99 5915.79 Top Kup C 11323.00 76.47 327.12 6031.05 5974.85 LCU 11330.00 76.55 327.38 6032.68 5976.48 BCU 11831.00 79.89 339.14 6129.03 6072.83 Top Nuiqsut_D1 ' 12056.00 80.08 343.00 6168.75 6112.55 Top Nuiq::Nuiq_1_D1 12074.00 80.08 343.26 6171.86 6115.66 ICP2 7"casing shoe 12090.00 80.08 343.26 6174.61 6118.41 ICP2 7"casing TD 12100.00 80.08 343.26 6176.33 6120.13 Nuiq_1::Nuiq_2_D1 12400.00 83.99 338.66 6211.56 6155.36 Nuiq_2::Nuiq_3_D1 12450.00 83.93 340.97 6216.82 6160.62 Invert#1 U2 12614.65 90.00 341.72 6225.82 6169.62 Nuiq_3::Nuiq_2_D1 12652.00 91.14 341.00 6225.44 6169.24 Nuiq_2::Nuiq_1_U2 12677.00 91.89 340.51 6224.78 6168.58 Fault 1 Zone_1::Zone_5(-58'DTSE) 12806.00 93.45 337.35 6218.20 6162.00 Fault 2 Zone_5::Zone_1(-60'DTNM) 13200.00 90.84 324.69 6206.44 6150.24 Revert#1 D3 13235.40 90.00 324.07 6206.18 6149.98 Sidetrack#5 KOP(open hole) 13250.00 89.65 323.82 6206.22 6150.02 Small Fault Nuiq_1::Kingak_D3 13386.00 87.72 323.55 6210.71 6154.51 Kingak::Top Nuiq_03 13425.00 88.40 323.34 6212.03 6155.83 Invert#2 U4 14397.00 90.00 321.00 6240.73 6184.53 Small Fault Nuiq_1::Kingak_U4 14668.00 91.57 312.19 6238.01 6181.81 Revert#2 D5 14758.00 90.00 309.15 6235.72 6179.52 Small Fault Kingak::Nuiq_1_D5 14770.00 89.51 308.85 6235.77 6179.57 Invert#3 U6 15034.00 90.00 305.50 6244.31 6188.11 Revert#3 D7 15218.50 90.00 300.96 6241.17 6184.97 Invert#4 U8 15576.61 90.00 305.50 6253.42 6197.22 Revert#4 D9 16176.83 90.00 306.56 6229.21 6173.01 Small Fault Nuiq_1::Kingak_D9 16400.00 89.29 307.61 6232.52 6176.32 Invert#5 U10 16511.00 90.00 307.54 6233.26 6177.06 TD 16689.00 92.33 310.64 6228.77 6172.57 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB1 Database: .Pioneer 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 ODSN-18-Slot ODS-18 Well Position +N/-S 0.00 ft Northing: 6,031,051.27 ft Latitude: 70°29'45.254 N +E/-W 0.00 ft Easting: 469,821.18 ft Longitude: 150° 14'48.375 W 1 Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSN-18 PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-18 PN11 PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 42.70 If Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 290.79 Survey Program Date 1/27/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 141.00 981.00 ODSN-18 PB1 Gyro 1 (ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 10/25/2010 1,027.53 1,027.53 ODSN-18 PBI MWD 1 (ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/2/2010 1: 1,123.00 1,123.00 ODSN-18 PB1 Gyro 2(ODSN-18 PBI) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 11/2/2010 1; 1,174.40 3,566.42 ODSN-18 PB1 MWD 2(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/26/2010 • 3,630.15 9,109.89 ODSN-18 PB1 MWD 3(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/1/2010 1: 9,183.00 11,847.02 ODSN-18 PB1 MWD 4(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/15/2010 • I Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-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 6,031,051.27 469,821.18 0.00 0.00 UNDEFINED 141.00 0.26 304.00 141.00 84.80 0.13 -0.19 6,031,051.40 469,820.99 0.26 0.22 SR-Gyro-SS(1) 199.00 0.27 348.71 199.00 142.80 0.33 -0.32 6,031,051.60 469,820.86 0.35 0.42 SR-Gyro-SS(1) 232.00 0.49 322.56 232.00 175.80 0.52 -0.42 6,031,051.79 469,820.76 0.83 0.58 SR-Gyro-SS(1) 290.00 0.48 322.52 290.00 233.80 0.91 -0.72 6,031,052.18 469,820.46 0.02 1.00 SR-Gyro-SS(1) 323.00 0.93 308.43 322.99 266.79 1.19 -1.02 6,031,052.46 469,820.17 1.45 1.37 SR-Gyro-SS(1) 382.00 1.25 295.72 381.98 325.78 1.76 -1.97 6,031,053.04 469,819.22 0.68 2.47 SR-Gyro-SS(1) 415.00 1.90 288.47 414.97 358.77 2.09 -2.81 6,031,053.38 469,818.38 2.06 3.37 SR-Gyro-SS(1) 472.00 2.17 284.07 471.93 415.73 2.66 -4.76 6,031,053.94 469,816.43 0.55 5.39 SR-Gyro-SS(1) 505.00 2.74 284.05 504.90 448.70 3.00 -6.13 6,031,054.29 469,815.06 1.73 6.79 SR-Gyro-SS(1) 1/312011 9:36:16AM Page 2 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB1 Database: .Pioneer Alaska Survey Map Map Vertical 1 MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) 01001 (ft) Survey Tool Name 568.00 3.14 281.82 567.82 511.62 3.72 -9.28 6,031,055.03 469,811.92 0.66 9.99 SR-Gyro-SS(1) 601.00 3.54 281.44 600.76 544.56 4.11 -11.16 6,031,055.42 469,810.04 1.21 11.89 SR-Gyro-SS(1) 662.00 3.66 281.14 661.64 605.44 4.86 -14.92 6,031,056.19 469,806.28 0.20 15.67 SR-Gyro-SS(1) 685.00 3.95 280.22 684.59 628.39 5.14 -16.42 6,031,056.47 469,804.79 1.29 17.17 SR-Gyro-SS(1) 758.00 4.41 281.46 757.40 701.20 6.14 -21.64 6,031,057.50 469,799.57 0.64 22.41 SR-Gyro-SS(1) 791.00 4.78 281.29 790.29 734.09 6.66 -24.23 6,031,058.03 469,796.98 1.12 25.02 SR-Gyro-SS(1) 853.00 5.29 282.35 852.05 795.85 7.78 -29.56 6,031,059.17 469,791.66 0.84 30.39 SR-Gyro-SS(1) 886.00 5.85 279.85 884.90 828.70 8.39 -32.70 6,031,059.79 469,788.52 1.85 33.55 SR-Gyro-SS(1) 948.00 6.88 279.90 946.51 890.31 9.57 -39.47 6,031,061.00 469,781.75 1.66 40.30 SR-Gyro-SS(1) 981.00 6.89 278.10 979.28 923.08 10.19 -43.38 6,031,061.64 469,777.85 0.65 44.17 SR-Gyro-SS(1) 1,027.53 6.83 276.30 1,025.47 969.27 10.89 -48.89 6,031,062.35 469,772.34 0.48 49.57 MWD+IFR2+MS+sag(2) 1,123.00 9.55 277.06 1,119.96 1,063.76 12.48 -62.40 6,031,064.01 469,758.84 2.85 62.76 SR-Gyro-SS(3) 1,174.43 9.71 277.20 1,170.67 1,114.47 13.55 -70.93 6,031,065.11 469,750.31 0.31 71.12 MWD+IFR2+MS+sag(4) 1,218.54 9.91 278.29 1,214.13 1,157.93 14.57 -78.38 6,031,066.15 469,742.87 0.62 78.45 MWD+IFR2+MS+sag(4) 1,314.10 9.75 271.65 1,308.29 1,252.09 15.98 -94.61 6,031,067.64 469,726.65 1.20 94.12 MWD+IFR2+MS+sag(4) 1,409.32 10.15 272.52 1,402.08 1,345.88 16.59 -111.05 6,031,068.30 469,710.21 0.45 109.70 MWD+IFR2+MS+sag(4) 1,504.37 10.95 274.95 1,495.52 1,439.32 17.73 -128.41 6,031,069.52 469,692.86 0.96 126.34 MWD+IFR2+MS+sag(4) 1,599.91 12.48 272.29 1,589.07 1,532.87 18.93 -147.77 6,031,070.80 469,673.51 1.70 144.86 MWD+IFR2+MS+sag(4) 1,631.69 12.76 273.11 1,620.08 1,563.88 19.26 -154.70 6,031,071.15 469,666.57 1.05 151.46 MWD+IFR2+MS+sag(4) 1,725.28 14.37 274.13 1,711.06 1,654.86 20.65 -176.61 6,031,072.64 469,644.68 1.74 172.44 MWD+IFR2+MS+sag(4) 1,821.10 13.44 273.34 1,804.07 1,747.87 22.16 -199.58 6,031,074.24 469,621.71 0.99 194.45 MWD+IFR2+MS+sag(4) 1,915.58 15.28 274.70 1,895.59 1,839.39 23.82 -222.95 6,031,075.99 469,598.35 1.98 216.89 MWD+IFR2+MS+sag(4) 2,011.74 15.85 275.48 1,988.23 1,932.03 26.11 -248.65 6,031,078.39 469,572.66 0.63 241.73 MWD+IFR2+MS+sag(4) 2,107.39 14.66 274.53 2,080.51 2,024.31 28.31 -273.72 6,031,080.69 469,547.60 1.27 265.95 MWD+IFR2+MS+sag(4) I W 2,202.94 13.62 277.80 2,173.16 2,116.96 30.80 -296.92 6,031,083.27 469,524.41 1.37 288.52 MD+IFR2+MS+sag(4) 2,241.41 13.96 276.43 2,210.52 2,154.32 31.93 -306.02 6,031,084.44 469,515.32 1.23 297.43 MWD+IFR2+MS+sag(4) 2,298.61 14.97 276.21 2,265.91 2,209.71 33.50 -320.22 6,031,086.07 469,501.13 1.77 311.26 MWD+IFR2+MS+sag(4) 2,333.40 15.89 274.27 2,299.44 2,243.24 34.34 -329.44 6,031,086.95 469,491.92 3.03 320.18 MWD+IFR2+MS+sag(4) 2,393.28 16.92 271.13 2,356.89 2,300.69 35.12 -346.33 6,031,087.80 469,475.03 2.27 336.24 MWD+IFR2+MS+sag(4) , 2,488.03 20.47 266.74 2,446.63 2,390.43 34.45 -376.67 6,031,087.25 469,444.70 4.03 364.37 MWD+IFR2+MS+sag(4) 2,583.22 24.38 267.73 2,534.60 2,478.40 32.73 -412.93 6,031,085.67 469,408.43 4.13 397.66 MWD+IFR2+MS+sag(4) 4 2,678.36 29.60 267.12 2,619.35 2,563.15 30.77 -456.05 6,031,083.89 469,365.31 5.49 437.27 MWD+IFR2+MS+sag(4) 2,773.39 32.86 268.44 2,700.60 2,644.40 28.89 -505.27 6,031,082.21 469,316.08 3.51 482.62 MWD+IFR2+MS+sag(4) 2,868.92 36.48 268.01 2,779.16 2,722.96 27.20 -559.58 6,031,080.73 469,261.77 3.80 532.79 MWD+IFR2+MS+sag(4) 2,963.62 38.66 267.56 2,854.21 2,798.01 24.96 -617.27 6,031,078.73 469,204.08 2.32 585.94 MWD+IFR2+MS+sag(4) 3,059.68 38.65 266.41 2,929.23 2,873.03 21.80 -677.19 6,031,075.82 469,144.15 0.75 640.83 MWD+IFR2+MS+sag(4) 3,155.09 41.44 265.51 3,002.26 2,946.06 17.46 -738.41 6,031,071.73 469,082.92 2.99 696.53 MWD+IFR2+MS+sag(4) i 3,249.55 42.15 264.91 3,072.68 3,016.48 3,344.92 46.28 265.36 3,141.02 3,084.82 12.20 -801.15 6,031,066.73 469,020.17 0.86 753.31 MWD+IFR2+MS+sag(4) 6.58 -867.40 6,031,061.37 468,953.90 4.34 813.25 MWD+IFR2+MS+sag(4) 3,439.63 48.20 265.43 3,205.32 3,149.12 0.99 -936.71 6,031,056.07 468,884.58 2.03 876.07 MWD+IFR2+MS+sag(4) 1/31/2011 9:36:16AM Page 3 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development ND Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB1 Database: .Pioneer 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) (°/700') (ft) Survey Tool Name 3,534.85 49.89 264.83 3,267.73 3,211.53 -5.12 -1,008.36 6,031,050.25 468,812.91 1.84 940.88 MWD+IFR2+MS+sag(4) 3,566.42 50.37 265.46 3,287.97 3,231.77 -7.17 -1,032.50 6,031,048.30 468,788.76 2.16 962.73 MWD+IFR2+MS+sag(4) 3,630.15 49.94 264.80 3,328.80 3,272.60 -11.32 -1,081.25 6,031,044.34 468,740.00 1.04 1,006.83 MWD+IFR2+MS+sag(5) 3,728.64 48.98 264.86 3,392.82 3,336.62 -18.06 -1,155.80 6,031,037.90 468,665.44 0.98 1,074.13 MWD+IFR2+MS+sag(5) 3,823.03 48.55 265.70 3,455.04 3,398.84 -23.91 -1,226.54 6,031,032.35 468,594.68 0.81 1,138.19 MWD+IFR2+MS+sag(5) 3,918.36 47.71 266.13 3,518.66 3,462.46 -28.97 -1,297.34 6,031,027.57 468,523.86 0.94 1,202.59 MWD+IFR2+MS+sag(5) 4,013.58 47.75 266.18 3,582.71 3,526.51 -33.69 -1,367.65 6,031,023.14 468,453.55 0.06 1,266.64 MWD+IFR2+MS+sag(5) 4,108.84 51.32 267.02 3,644.52 3,588.32 -37.97 -1,439.98 6,031,019.15 468,381.20 3.81 1,332.74 MWD+IFR2+MS+sag(5) 4,203.49 54.06 266.88 3,701.89 3,645.69 -41.98 -1,515.15 6,031,015.45 468,306.03 2.90 1,401.59 MWD+IFR2+MS+sag(5) 4,300.86 56.97 265.70 3,757.01 3,700.81 -47,19 -1,595.23 6,031,010.56 468,225.93 3.15 1,474.61 MWD+IFR2+MS+sag(5) 4,398.80 58.70 262.86 3,809.16 3,752.96 -55.47 -1,677.71 6,031,002.62 468,143.43 3.02 1,548.78 MWD+IFR2+MS+sag(5) 4,493.85 61.31 259.87 3,856.68 3,800.48 -67.85 -1,759.07 6,030,990.57 468,062.03 3.87 1,620.44 MWD+IFR2+MS+sag(5) 4,584.47 65.00 259.37 3,897.60 3,841.40 -82.42 -1,838.58 6,030,976.32 467,982.46 4.10 1,689.61 MWD+IFR2+MS+sag(5) 4,684.58 67.49 257.58 3,937.92 3,881.72 -100.74 -1,928.35 6,030,958.37 467,892.63 2.98 1,767.03 MWD+IFR2+MS+sag(5) 4,779.26 68.84 257.43 3,973.14 3,916.94 -119.76 -2,014.15 6,030,939.70 467,806.76 1.43 1,840.50 MWD+IFR2+MS+sag(5) 4,871.89 70.51 256.93 4,005.31 3,949.11 -139.03 -2,098.85 6,030,920.77 467,722.00 1.87 1,912.84 MWD+IFR2+MS+sag(5) 4,965.11 71.34 257.43 4,035.78 3,979.58 -158.58 -2,184.75 6,030,901.58 467,636.02 1.02 1,986.21 MWD+IFR2+MS+sag(5) 5,063.57 71.46 258.28 4,067.18 4,010.98 -178.21 -2,275.98 6,030,882.32 467,544.73 0.83 2,064.53 MWD+IFR2+MS+sag(5) 5,159.38 71.34 258.20 4,097.74 4,041.54 -196.72 -2,364.88 6,030,864.17 467,455.76 0.15 2,141.07 MWD+IFR2+MS+sag(5) 5,254.53 71.20 258.00 4,128.29 4,072.09 -215.30 -2,453.05 6,030,845.95 467,367.52 0.25 2,216.91 MWD+IFR2+MS+sag(5) 5,345.36 70.63 257.39 4,157.99 4,101.79 -2,536.92 6,030,828.00 467,283.59 0.89 2,288.82 MWD+IFR2+MS+sag(5) 5,441.12 71.23 257.83 4,189.28 4,133.08 -253.01 -2,625.31 6,030,808.94 467,195.13 0.76 2,364.57 MWD+IFR2+MS+sag(5) 5,536.74 71.07 258.19 4,220.17 4,163.97 -271.81 -2,713.83 6,030,790.51 467,106.54 0.39 2,440.65 MWD+IFR2+MS+sag(5) 5,631.50 70.36 258.20 4,251.47 4,195.27 -290.11 -2,801.38 6,030,772.57 467,018.93 0.75 2,516.00 MWD+IFR2+MS+sag(5) 5,727.44 70.95 258.18 4,283.25 4,227.05 -308.63 -2,889.99 6,030,754.40 466,930.25 0.62 2,592.26 MWD+IFR2+MS+sag(5) 5,824.68 70.61 258.07 4,315.26 4,259.06 -327.53 -2,979.84 6,030,735.87 466,840.33 0.37 2,669.56 MWD+IFR2+MS+sag(5) 5,917.59 70.86 257.56 4,345.92 4,289.72 -346.04 -3,065.57 6,030,717.71 466,754.54 0.58 2,743.14 MWD+IFR2+MS+sag(5) 6,011.23 71.05 257.12 4,376.47 4,320.27 -3,151.94 6,030,698.66 466,668.11 0.49 2,816.99 MWD+IFR2+MS+sag(5) 'r■ 6,109.85 70.29 255.57 4,409.12 4,352.92 -387.41 -3,242.36 6,030,677.07 466,577.60 1.67 2,893.74 MWD+IFR2+MS+sag(5) 6,206.00 70.35 256.98 4,441.50 4,385.30 -408.89 -3,330.31 6,030,655.95 466,489.58 1.38 2,968.33 MWD+IFR2+MS+sag(5) 6,296.96 70.47 257.77 4,472.00 4,415.80 -427.62 -3,413.93 6,030,637.56 466,405.89 0.83 3,039.86 MWD+IFR2+MS+sag(5) 6,392.50 70.96 258.81 4,503.55 4,447.35 -445.92 -3,502.23 6,030,619.62 466,317.52 1.15 3,115.92 MWD+IFR2+MS+sag(5) 6,487.74 71.03 259.25 4,534.57 4,478.37 -463.05 -3,590.63 6,030,602.84 466,229.06 0.44 3,192.48 MWD+IFR2+MS+sag(5) 6,582.74 70.87 258.69 4,565.57 4,509.37 -480.23 -3,678.77 6,030,586.02 466,140.86 0.58 3,268.78 MWD+IFR2+MS+sag(5) 6,677.75 70.73 259.06 4,596.82 4,540.62 -497.54 -3,766.81 6,030,569.07 466,052.76 0.40 3,344.94 MWD+IFR2+MS+sag(5) 6,773.48 71.16 258.45 4,628.07 4,571.87 -515.19 -3,855.56 6,030,551.79 465,963.95 0.75 3,421.65 MWD+IFR2+MS+sag(5) 6,868.81 71.27 257.68 4,658.77 4,602.57 -533.85 -3,943.86 6,030,533.48 465,875.59 0.77 3,497.57 MWD+IFR2+MS+sag(5) 6,964.81 70.80 259.14 4,689.97 4,633.77 -552.10 -4,032.79 6,030,515.61 465,786.59 1.52 3,574.24 MWD+IFR2+MS+sag(5) 7,058.66 71.73 258.75 4,720.12 4,663.92 -569.14 -4,120.02 6,030,498.92 465,699.30 1.07 3,649.74 MWD+IFR2+MS+sag(5) 7,155.94 70.48 258.65 4,751.62 4,695.42 -587.17 -4,210.27 6,030,481.25 465,608.99 1.29 3,727.72 MWD+IFR2+MS+sag(5) 1/31/2011 9:36:16AM Page 4 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB1 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 7,249.11 70.27 258.33 4,782.91 4,726.71 -604.68 -4,296.26 6,030,464.09 465,522.93 0.39 3,801.89 MWD+IFR2+MS+sag(5) 7,345.08 71.16 258.01 4,814.61 4,758.41 -623.25 -4,384.92 6,030,445.88 465,434.21 0.98 3,878.19 MWD+IFR2+MS+sag(5) 7,441.17 70.89 257.84 4,845.85 4,789.65 -642.26 -4,473.78 6,030,427.24 465,345.28 0.33 3,954.51 MWD+IFR2+MS+sag(5) 7,536.09 69.56 258.34 4,877.96 4,821.76 -660.70 -4,561.18 6,030,409.16 465,257.82 1.49 4,029.68 MWD+IFR2+MS+sag(5) 7,626.41 69.56 260.20 4,909.51 4,853.31 -676.45 -4,644.33 6,030,393.74 465,174.61 1.93 4,101.82 MWD+IFR2+MS+sag(5) 7,726.42 69.36 260.00 4,944.60 4,888.40 -692.56 -4,736.58 6,030,378.02 465,082.30 0.27 4,182.35 MWD+IFR2+MS+sag(5) 7,820.69 69.02 260.88 4,978.09 4,921.89 -707.19 -4,823.48 6,030,363.74 464,995.36 0.94 4,258.40 MWD+IFR2+MS+sag(5) 7,915.20 69.21 260.17 5,011.78 4,955.58 -721.73 -4,910.57 6,030,349.56 464,908.21 0.73 4,334.66 MWD+IFR2+MS+sag(5) 8,011.00 69.69 260.57 5,045.41 4,989.21 -736.73 -4,999.01 6,030,334.91 464,819.72 0.64 4,412.02 MWD+IFR2+MS+sag(5) 8,106.40 69.26 260.81 5,078.86 5,022.66 -751.19 -5,087.18 6,030,320.82 464,731.51 0.51 4,489.31 MWD+IFR2+MS+sag(5) 8,201.28 69.17 260.04 5,112.53 5,056.33 -765.94 -5,174.65 6,030,306.42 464,643.99 0.76 4,565.85 MWD+IFR2+MS+sag(5) 8,296.82 69.86 258.87 5,145.97 5,089.77 -782.32 -5,262.63 6,030,290.40 464,555.95 1.36 4,642.29 MWD+IFR2+MS+sag(5) 8,392.12 69.57 258.47 5,179.00 5,122.80 -799.88 -5,350.28 6,030,273.19 464,468.24 0.50 4,718.00 MWD+IFR2+MS+sag(5) 8,486.56 69.62 258.49 5,211.93 5,155.73 -817.56 -5,437.01 6,030,255.87 464,381.44 0.06 4,792.81 MWD+IFR2+MS+sag(5) 8,582.82 69.31 258.03 5,245.70 5,189.50 -835.90 -5,525.27 6,030,237.89 464,293.12 0.55 4,868.81 MWD+IFR2+MS+sag(5) 8,680.14 70.39 257.88 5,279.22 5,223.02 -854.97 -5,614.62 6,030,219.19 464,203.70 1.12 4,945.57 MWD+IFR2+MS+sag(5) 8,775.17 69.41 258.59 5,311.88 5,255.68 -873.16 -5,701.98 6,030,201.35 464,116.27 1.25 5,020.79 MWD+IFR2+MS+sag(5) 8,869.17 68.90 258.44 5,345.33 5,289.13 -890.66 -5,788.07 6,030,184.21 464,030.12 0.56 5,095.06 MWD+IFR2+MS+sag(5) 8,966.69 68.95 258.91 5,380.40 5,324.20 -908.53 -5,877.30 6,030,166.70 463,940.84 0.45 5,172.14 MWD+IFR2+MS+sag(5) 9,058.61 69.53 262.00 5,412.98 5,356.78 -922.77 -5,962.05 6,030,152.80 463,856.04 3.21 5,246.31 MWD+IFR2+MS+sag(5) 9,109.89 69.65 263.61 5,430.87 5,374.67 -928.79 -6,009.73 6,030,146.98 463,808.34 2.95 5,288.75 MWD+IFR2+MS+sag(5) 9,183.00 68.97 267.26 5,456.71 5,400.51 -934.24 -6,077.89 6,030,141.81 463,740.16 4.76 5,350.54 MWD+IFR2+MS+sag(6) 9,277.66 69.49 269.70 5,490.28 5,434.08 -936.58 -6,166.36 6,030,139.82 463,651.69 2.47 5,432.42 MWD+IFR2+MS+sag(6) 9,373.04 69.27 271.60 5,523.87 5,467.67 -935.57 -6,255.62 6,030,141.20 463,562.45 1.88 5,516.22 MWD+IFR2+MS+sag(6) 9,468.40 69.84 273.65 5,557.18 5,500.98 -931.48 -6,344.87 6,030,145.65 463,473.22 2.10 5,601.12 MWD+IFR2+MS+sag(6) 9,563.51 69.48 277.43 5,590.25 5,534.05 -922.87 -6,433.61 6,030,154.62 463,384.52 3.75 5,687.14 MWD+IFR2+MS+sag(6) 9,658.71 70.56 280.65 5,622.79 5,566.59 -908.81 -6,521.96 6,030,169.04 463,296.25 3.38 5,774.72 MWD+IFR2+MS+sag(6) 9,754.19 70.28 282.55 5,654.79 5,598.59 -890.72 -6,610.07 6,030,187.48 463,208.21 1.90 5,863.52 MWD+IFR2+MS+sag(6) 9,848.39 70.14 284.51 5,686.69 5,630.49 -6,696.24 6,030,208.56 463,122.14 1.96 5,951.44 MWD+IFR2+MS+sag(6) 9,943.55 70.74 288.01 5,718.55 5,662.35 -844.88 -6,782.31 6,030,234.02 463,036.18 3.52 6,040.81 MWD+IFR2+MS+sag(6) 10,038.11 71.33 290.47 5,749.29 5,693.09 -815.41 -6,866.73 6,030,263.82 462,951.89 2.54 6,130.19 MWD+IFR2+MS+sag(6) 10,133.74 71.78 292.74 5,779.55 5,723.35 -782.01 -6,951.07 6,030,297.57 462,867.70 2.30 6,220.90 MWD+IFR2+MS+sag(6) 10,229.44 73.13 296.75 5,808.41 5,752.21 -743.81 -7,033.91 6,030,336.09 462,785.02 4.24 6,311.90 MWD+IFR2+MS+sag(6) 10,324.07 74.43 300.97 5,834.85 5,778.65 -699.96 -7,113.46 6,030,380.27 462,705.66 4.50 6,401.84 MWD+IFR2+MS+sag(6) 10,419.48 74.23 301.99 5,860.62 5,804.42 -651.99 -7,191.80 6,030,428.55 462,627.52 1.05 6,492.11 MWD+IFR2+MS+sag(6) 10,515.22 74.05 303.89 5,886.79 5,830.59 -601.91 -7,269.09 6,030,478.93 462,550.44 1.92 6,582.13 MWD+IFR2+MS+sag(6) 10,609.62 75.40 306.68 5,911.66 5,855.46 -549.31 -7,343.41 6,030,531.83 462,476.34 3.19 6,670.29 MWD+IFR2+MS+sag(6) 10,705.95 76.48 309.31 5,935.07 5,878.87 -491.79 -7,417.04 6,030,589.64 462,402.96 2.88 6,759.54 MWD+IFR2+MS+sag(6) 10,800.40 77.68 312.11 5,956.19 5,899.99 -431.75 -7,486.81 6,030,649.96 462,333.44 3.16 6,846.08 MWD+IFR2+MS+sag(6) 10,895.77 76.91 316.41 5,977.18 5,920.98 -366.84 -7,553.42 6,030,715.13 462,267.09 4.47 6,931.39 MWD+IFR2+MS+sag(6) 1/312011 9:36:16AM Page 5 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB1 Database: .Pioneer 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 10,991.70 76.66 319.98 5,999.11 5,942.91 -297.24 -7,615.67 6,030,784.98 462,205.14 3.63 7,014.29 MWD+IFR2+MS+sag(6) 11,086.42 76.09 325.02 6,021.44 5,965.24 -224.24 -7,671.69 6,030,858.20 462,149.42 5.21 7,092.57 MWD+IFR2+MS+sag(6) 11,180.47 76.48 328.79 6,043.74 5,987.54 -147.71 -7,721.57 6,030,934.93 462,099.86 3.92 7,166.37 MWD+IFR2+MS+sag(6) 11,276.79 76.99 332.18 6,065.85 6,009,65 -66.13 -7,767.74 6,031,016.68 462,054.02 3.47 7,238.49 MWD+IFR2+MS+sag(6) 11,372.24 79.59 335.41 6,085.23 6,029.03 17.71 -7,809.00 6,031,100.68 462,013.11 4.29 7,306.82 MWD+IFR2+MS+sag(6) 11,467.58 80.82 335.40 6,101.45 6,045.25 103.13 -7,848.10 6,031,186.25 461,974.36 1.29 7,373.69 MWD+IFR2+MS+sag(6) 11,562.23 80.38 335.28 6,116.91 6,060.71 188.00 -7,887.06 6,031,271.26 461,935.75 0.48 7,440.24 MWD+IFR2+MS+sag(6) 11,657.90 80.01 336.55 6,133.20 6,077.00 274.06 -7,925.53 6,031,357.47 461,897.63 1.36 7,506.75 MWD+IFR2+MS+sag(6) 11,753.05 80.13 336.68 6,149.61 6,093.41 360.09 -7,962.73 6,031,443.64 461,860.78 0.18 7,572.06 MWD+IFR2+MS+sag(6) 11,847.02 80.62 336.06 6,165.32 6,109.12 444.96 -7,999.86 6,031,528.66 461,824.00 0.83 7,636.91 MWD+IFR2+MS+sag(6) 11,890.00 80.62 336.06 6,172.32 6,116.12 483.72 -8,017.07 6,031,567.48 461,806.95 0.00 7,666.75 PROJECTED to TD 1/312011 9:36:16AM Page 6 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5(copy)©56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB2 Database: .Pioneer 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 ODSN-18-Slot ODS-18 Well Position +N/-S 0.00 ft Northing: 6,031,051.27 ft Latitude: 70°29'45.254 N +El-W 0.00 ft Easting: 469,821.18 ft Longitude: 150°14'48.375 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft Wellbore ODSN-18 PB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) I IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-18 PN11 PB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,438.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 290.79 Survey Program Date 1/27/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 141.00 981.00 ODSN-18 PB1 Gyro 1 (ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 10/25/2010 • 1,027.50 1,027.50 ODSN-18 PB1 MWD 1 (ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/2/2010 1: 1,123.00 1,123.00 ODSN-18 PB1 Gyro 2(ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 11/2/2010 1: 1,174.40 3,566.40 ODSN-18 PB1 MWD 2(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/26/2010 3,630.10 8,392.12 ODSN-18 PB1 MWD 3(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/1/2010 1: 8,438.00 13,381.84 ODSN-18 PB2 MWD 4(ODSN-18 PB2) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/5/2010 1: i Survey Map Map Vertical MD Inc Azi ND 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 6,031,051.27 469,821.18 0.00 0.00 UNDEFINED 141.00 0.26 304.00 141.00 84.80 0.13 -0.19 6,031,051.40 469,820.99 0.26 0.22 SR-Gyro-SS(1) 199.00 0.27 348.71 199.00 142.80 0.33 -0.32 6,031,051.60 469,820.86 0.35 0.42 SR-Gyro-SS(1) 232.00 0.49 322.56 232.00 175.80 0.52 -0.42 6,031,051.79 469,820.76 0.83 0.58 SR-Gyro-SS(1) 290.00 0.48 322.52 290.00 233.80 0.91 -0.72 6,031,052.18 469,820.46 0.02 1.00 SR-Gyro-SS(1) 323.00 0.93 308.43 322.99 266.79 1.19 -1.02 6,031,052.46 469,820.17 1.45 1.37 SR-Gyro-SS(1) 382.00 1.25 295.72 381.98 325.78 1.76 -1.97 6,031,053.04 469,819.22 0.68 2.47 SR-Gyro-SS(1) 415.00 1.90 288.47 414.97 358.77 2.09 -2.81 6,031,053.38 469,818.38 2.06 3.37 SR-Gyro-SS(1) 472.00 2.17 284.07 471.93 415.73 2.66 -4.76 6,031,053.94 469,816.43 0.55 5.39 SR-Gyro-SS(1) 505.00 2.74 284.05 504.90 448.70 3.00 -6.13 6,031,054.29 469,815.06 1.73 6.79 SR-Gyro-SS(1) 1/312011 9:34:53AM Page 2 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB2 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 568.00 3.14 281.82 567.82 511.62 3.72 -9.28 6,031,055.03 469,811.92 0.66 9.99 SR-Gyro-SS(1) 601.00 3.54 281.44 600.76 544.56 4.11 -11.16 6,031,055.42 469,810.04 1.21 11.89 SR-Gyro-SS(1) 662.00 3.66 281.14 661.64 605.44 4.86 -14.92 6,031,056.19 469,806.28 0.20 15.67 SR-Gyro-SS(1) 685.00 3.95 280.22 684.59 628.39 5.14 -16.42 6,031,056.47 469,804.79 1.29 17.17 SR-Gyro-SS(1) 758.00 4.41 281.46 757.40 701.20 6.14 -21.64 6,031,057.50 469,799.57 0.64 22.41 SR-Gyro-SS(1) 791.00 4.78 281.29 790.29 734.09 6.66 -24.23 6,031,058.03 469,796.98 1.12 25.02 SR-Gyro-SS(1) 853.00 5.29 282.35 852.05 795.85 7.78 -29.56 6,031,059.17 469,791.66 0.84 30.39 SR-Gyro-SS(1) 886.00 5.85 279.85 884.90 828.70 8.39 -32.70 6,031,059.79 469,788.52 1.85 33.55 SR-Gyro-SS(1) 948.00 6.88 279.90 946.51 890.31 9.57 -39.47 6,031,061.00 469,781.75 1.66 40.30 SR-Gyro-SS(1) 981.00 6.89 278.10 979.28 923.08 10.19 -43.38 6,031,061.64 469,777.85 0.65 44.17 SR-Gyro-SS(1) 1,027.53 6.83 276.30 1,025.47 969.27 10.89 -48.89 6,031,062.35 469,772.34 0.48 49.57 MWD+IFR2+MS+sag(2) 1,123.00 9.55 277.06 1,119.96 1,063.76 12.48 -62.40 6,031,064.01 469,758.84 2.85 62.76 SR-Gyro-SS(3) I 1,174.43 9.71 277.20 1,170.67 1,114.47 13.55 -70.93 6,031,065.11 469,750.31 0.31 71.12 MWD+IFR2+MS+sag(4) 1,218.54 9.91 278.29 1,214.13 1,157.93 14.57 -78.38 6,031,066.15 469,742.87 0.62 78.45 MWD+IFR2+MS+sag(4) 1,314.10 9.75 271.65 1,308.29 1,252.09 15.98 -94.61 6,031,067.64 469,726.65 1.20 94.12 MWD+IFR2+MS+sag(4) 1,409.32 10.15 272.52 1,402.08 1,345.88 16.59 -111.05 6,031,068.30 469,710.21 0.45 109.70 MWD+IFR2+MS+sag(4) 1,504.37 10.95 274.95 1,495.52 1,439.32 17.73 -128.41 6,031,069.52 469,692.86 0.96 126.34 MWD+IFR2+MS+sag(4) 1,599.91 12.48 272.29 1,589.07 1,532.87 18.93 -147.77 6,031,070.80 469,673.51 1.70 144.86 MWD+IFR2+MS+sag(4) 1,631.69 12.76 273.11 1,620.08 1,563.88 19.26 -154.70 6,031,071,15 469,666.57 1.05 151.46 MWD+IFR2+MS+sag(4) 1,725.28 14.37 274.13 1,711.06 1,654.86 20.65 -176.61 6,031,072.64 469,644.68 1.74 172.44 MWD+IFR2+MS+sag(4) 1,821.10 13.44 273.34 1,804.07 1,747.87 22.16 -199.58 6,031,074.24 469,621.71 0.99 194.45 MWD+IFR2+MS+sag(4) 1,915.58 15.28 274.70 1,895.59 1,839.39 23.82 -222.95 6,031,075.99 469,598.35 1.98 216.89 MWD+IFR2+MS+sag(4) 2,011.74 15.85 275.48 1,988.23 1,932.03 26.11 -248.65 6,031,078.39 469,572.66 0.63 241.73 MWD+IFR2+MS+sag(4) 2,107.39 14.66 274.53 2,080.51 2,024.31 28.31 -273.72 6,031,080.69 469,547.60 1.27 265.95 MWD+IFR2+MS+sag(4) 2,202.94 13.62 277.80 2,173.16 2,116.96 30.80 -296.92 6,031,083.27 469,524.41 1.37 288.52 MWD+IFR2+MS+sag(4) 2,241.41 13.96 276.43 2,210.52 2,154.32 31.93 -306.02 6,031,084.44 469,515.32 1.23 297.43 MWD+IFR2+MS+sag(4) 2,298.61 14.97 276.21 2,265.91 2,209.71 33.50 -320.22 6,031,086.07 469,501.13 1.77 311.26 MWD+IFR2+MS+sag(4) 2,333.40 15.89 274.27 2,299.44 2,243.24 34.34 -329.44 6,031,086.95 469,491.92 3.03 320.18 MWD+IFR2+MS+sag(4) 2,393.28 16.92 271.13 2,356.89 2,300.69 35.12 -346.33 6,031,087.80 469,475.03 2.27 336.24 MWD+IFR2+MS+sag(4) 2,488.03 20.47 266.74 2,446.63 2,390.43 34.45 -376.67 6,031,087.25 469,444.70 4.03 364.37 MWD+IFR2+MS+sag(4) 2,583.22 24.38 267.73 2,534.60 2,478.40 32.73 -412.93 6,031,085.67 469,408.43 4.13 397.66 MWD+IFR2+MS+sag(4) 2,678.36 29.60 267.12 2,619.35 2,563.15 30.77 -456.05 6,031,083.89 469,365.31 5.49 437.27 MWD+IFR2+MS+sag(4) 2,773.39 32.86 268.44 2,700.60 2,644.40 28.89 -505.27 6,031,082.21 469,316.08 3.51 482.62 MWD+IFR2+MS+sag(4) 2,868.92 36.48 268.01 2,779.16 2,722.96 27.20 -559.58 6,031,080.73 469,261.77 3.80 532.79 MWD+IFR2+MS+sag(4) 2,963.62 38.66 267.56 2,854.21 2,798.01 24.96 -617.27 6,031,078.73 469,204.08 2.32 585.94 MWD+IFR2+MS+sag(4) 3,059.68 38.65 266.41 2,929.23 2,873.03 21.80 -677.19 6,031,075.82 469,144.15 0.75 640.83 MWD+IFR2+MS+sag(4) 3,155.09 41.44 265.51 3,002.26 2,946.06 17.46 -738.41 6,031,071.73 469,082.92 2.99 696.53 MWD+IFR2+MS+sag(4) 3,249.55 42.15 264.91 3,072.68 3,016.48 12.20 -801.15 6,031,066.73 469,020.17 0.86 753.31 MWD+IFR2+MS+sag(4) 3,344.92 46.28 265.36 3,141.02 3,084.82 6.58 -867.40 6,031,061.37 468,953.90 4.34 813.25 MWD+IFR2+MS+sag(4) 3,439.63 48.20 265.43 3,205.32 3,149.12 0.99 -936.71 6,031,056.07 468,884.58 2.03 876.07 MWD+IFR2+MS+sag(4) 1/31/2011 9:34:53AM Page 3 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB2 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 3,534.85 49.89 264.83 3,267.73 3,211.53 -5.12 -1,008.36 6,031,050.25 468,812.91 1.84 940.88 MWD+IFR2+MS+sag(4) 3,566.42 50.37 265.46 3,287.97 3,231.77 -7.17 -1,032.50 6,031,048.30 468,788.76 2.16 962.73 MWD+IFR2+MS+sag(4) 3,630.15 49.94 264.80 3,328.80 3,272.60 -11.32 -1,081.25 6,031,044.34 468,740.00 1.04 1,006.83 MWD+IFR2+MS+sag(5) 3,728.64 48.98 264.86 3,392.82 3,336.62 -18.06 -1,155.80 6,031,037.90 468,665.44 0.98 1,074.13 MWD+IFR2+MS+sag(5) 3,823.03 48.55 265.70 3,455.04 3,398.84 -23.91 -1,226.54 6,031,032.35 468,594.68 0.81 1,138.19 MWD+IFR2+MS+sag(5) 3,918.36 47.71 266.13 3,518.66 3,462.46 -28.97 -1,297.34 6,031,027.57 468,523.86 0.94 1,202.59 MWD+IFR2+MS+sag(5) 4,013.58 47.75 266.18 3,582.71 3,526.51 -33.69 -1,367.65 6,031,023.14 468,453.55 0.06 1,266.64 MWD+IFR2+MS+sag(5) 4,108.84 51.32 267.02 3,644.52 3,588.32 -37.97 -1,439.98 6,031,019.15 468,381.20 3.81 1,332.74 MWD+IFR2+MS+sag(5) 4,203.49 54.06 266.88 3,701.89 3,645.69 -41.98 -1,515.15 6,031,015.45 468,306.03 2.90 1,401.59 MWD+IFR2+MS+sag(5) 4,300.86 56.97 265.70 3,757.01 3,700.81 -47.19 -1,595.23 6,031,010.56 468,225.93 3.15 1,474.61 MWD+IFR2+MS+sag(5) 4,398.80 58.70 262.86 3,809.16 3,752.96 -55.47 -1,677.71 6,031,002.62 468,143.43 3.02 1,548.78 MWD+IFR2+MS+sag(5) 4,493.85 61.31 259.87 3,856.68 3,800.48 -67.85 -1,759.07 6,030,990.57 468,062.03 3.87 1,620.44 MWD+IFR2+MS+sag(5) 4,584.47 65.00 259.37 3,897.60 3,841.40 -82.42 -1,838.58 6,030,976.32 467,982.46 4.10 1,689.61 MWD+IFR2+MS+sag(5) 4,684.58 67.49 257.58 3,937.92 3,881.72 -100.74 -1,928.35 6,030,958.37 467,892.63 2.98 1,767.03 MWD+IFR2+MS+sag(5) 4,779.26 68.84 257.43 3,973.14 3,916.94 -119.76 -2,014.15 6,030,939.70 467,806.76 1.43 1,840.50 MWD+IFR2+MS+sag(5) 4,871.89 70.51 256.93 4,005.31 3,949.11 -139.03 -2,098.85 6,030,920.77 467,722.00 1.87 1,912.84 MWD+IFR2+MS+sag(5) 4,965.11 71.34 257.43 4,035.78 3,979.58 -158.58 -2,184.75 6,030,901.58 467,636.02 1.02 1,986.21 MWD+IFR2+MS+sag(5) 5,063.57 71.46 258.28 4,067.18 4,010.98 -178.21 -2,275.98 6,030,882.32 467,544.73 0.83 2,064.53 MWD+IFR2+MS+sag(5) 5,159.38 71.34 258.20 4,097.74 4,041.54 -196.72 -2,364.88 6,030,864.17 467,455.76 0.15 2,141.07 MWD+IFR2+MS+sag(5) 5,254.53 71.20 258.00 4,128.29 4,072.09 -215.30 -2,453.05 6,030,845.95 467,367.52 0.25 2,216.91 MWD+IFR2+MS+sag(5) 5,345.36 70.63 257.39 4,157.99 4,101.79 -233.59 -2,536.92 6,030,828.00 467,283.59 0.89 2,288.82 MWD+IFR2+MS+sag(5) 5,441.12 71.23 257.83 4,189.28 4,133.08 -253.01 -2,625.31 6,030,808.94 467,195.13 0.76 2,364.57 MWD+IFR2+MS+sag(5) 5,536.74 71.07 258.19 4,220.17 4,163.97 -271.81 -2,713.83 6,030,790.51 467,106.54 0.39 2,440.65 MWD+IFR2+MS+sag(5) 5,631.50 70.36 258.20 4,251.47 4,195.27 -290.11 -2,801.38 6,030,772.57 467,018.93 0.75 2,516.00 MWD+IFR2+MS+sag(5) 5,727.44 70.95 258.18 4,283.25 4,227.05 -308.63 -2,889.99 6,030,754.40 466,930.25 0.62 2,592.26 MWD+IFR2+MS+sag(5) 5,824.68 70.61 258.07 4,315.26 4,259.06 -327.53 -2,979.84 6,030,735.87 466,840.33 0.37 2,669.56 MWD+IFR2+MS+sag(5) 5,917.59 70.86 257.56 4,345.92 4,289.72 -346.04 -3,065.57 6,030,717.71 466,754.54 0.58 2,743.14 MWD+IFR2+MS+sag(5) 6,011.23 71.05 257.12 4,376.47 4,320.27 -365.44 -3,151.94 6,030,698.66 466,668.11 0.49 2,816.99 MWD+IFR2+MS+sag(5) 6,109.85 70.29 255.57 4,409.12 4,352.92 -387.41 -3,242.36 6,030,677.07 466,577.60 1.67 2,893.74 MWD+IFR2+MS+sag(5) 6,206.00 70.35 256.98 4,441.50 4,385.30 -408.89 -3,330.31 6,030,655.95 466,489.58 1.38 2,968.33 MWD+IFR2+MS+sag(5) 6,296.96 70.47 257.77 4,472.00 4,415.80 -427.62 -3,413.93 6,030,637.56 466,405.89 0.83 3,039.86 MWD+IFR2+MS+sag(5) 6,392.50 70.96 258.81 4,503.55 4,447.35 -445.92 -3,502.23 6,030,619.62 466,317.52 1.15 3,115.92 MWD+IFR2+MS+sag(5) 6,487.74 71.03 259.25 4,534.57 4,478.37 -463.05 -3,590.63 6,030,602.84 466,229.06 0.44 3,192.48 MWD+IFR2+MS+sag(5) 6,582.74 70.87 258.69 4,565.57 4,509.37 -480.23 -3,678.77 6,030,586.02 466,140.86 0.58 3,268.78 MWD+IFR2+MS+sag(5) 6,677.75 70.73 259.06 4,596.82 4,540.62 -497.54 -3,766.81 6,030,569.07 466,052.76 0.40 3,344.94 MWD+IFR2+MS+sag(5) 6,773.48 71.16 258.45 4,628.07 4,571.87 -515.19 -3,855.56 6,030,551.79 465,963.95 0.75 3,421.65 MWD+IFR2+MS+sag(5) 6,868.81 71.27 257.68 4,658.77 4,602.57 -533.85 -3,943.86 6,030,533.48 465,875.59 0.77 3,497.57 MWD+IFR2+MS+sag(5) 6,964.81 70.80 259.14 4,689.97 4,633.77 -552.10 -4,032.79 6,030,515.61 465,786.59 1.52 3,574.24 MWD+IFR2+MS+sag(5) 7,058.66 71.73 258.75 4,720.12 4,663.92 -569.14 -4,120.02 6,030,498.92 465,699.30 1.07 3,649.74 MWD+IFR2+MS+sag(5) 7,155.94 70.48 258.65 4,751.62 4,695.42 -587.17 -4,210.27 6,030,481.25 465,608.99 1.29 3,727.72 MWD+IFR2+MS+sag(5) 1/31!2011 9:34:53AM Page 4 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB2 Database: .Pioneer 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 7,249.11 70.27 258.33 4,782.91 4,726.71 -604.68 -4,296.26 6,030,464.09 465,522.93 0.39 3,801.89 MWD+IFR2+MS+sag(5) 7,345.08 71.16 258.01 4,814.61 4,758.41 -623.25 -4,384.92 6,030,445.88 465,434.21 0.98 3,878.19 MWD+IFR2+MS+sag(5) 7,441.17 70.89 257.84 4,845.85 4,789.65 -642.26 -4,473.78 6,030,427.24 465,345.28 0.33 3,954.51 MWD+IFR2+MS+sag(5) 7,536.09 69.56 258.34 4,877.96 4,821.76 -660.70 -4,561.18 6,030,409.16 465,257.82 1.49 4,029.68 MWD+IFR2+MS+sag(5) 7,626.41 69.56 260.20 4,909.51 4,853.31 -676.45 -4,644.33 6,030,393.74 465,174.61 1.93 4,101.82 MWD+IFR2+MS+sag(5) 7,726.42 69.36 260.00 4,944.60 4,888.40 -692.56 -4,736.58 6,030,378.02 465,082.30 0.27 4,182.35 MWD+IFR2+MS+sag(5) 7,820.69 69.02 260.88 4,978.09 4,921.89 -707.19 -4,823.48 6,030,363.74 464,995.36 0.94 4,258.40 MWD+IFR2+MS+sag(5) 7,915.20 69.21 260.17 5,011.78 4,955.58 -721.73 -4,910.57 6,030,349.56 464,908.21 0.73 4,334.66 MWD+IFR2+MS+sag(5) 8,011.00 69.69 260.57 5,045.41 4,989.21 -736.73 -4,999.01 6,030,334.91 464,819.72 0.64 4,412.02 MWD+IFR2+MS+sag(5) 8,106.40 69.26 260.81 5,078.86 5,022.66 -751.19 -5,087.18 6,030,320.82 464,731.51 0.51 4,489.31 MWD+IFR2+MS+sag(5) 8,201.28 69.17 260.04 5,112.53 5,056.33 -765.94 -5,174.65 6,030,306.42 464,643.99 0.76 4,565.85 MWD+IFR2+MS+sag(5) 8,296.82 69.86 258.87 5,145.97 5,089.77 -782.32 -5,262.63 6,030,290.40 464,555.95 1.36 4,642.29 MWD+IFR2+MS+sag(5) 8,392.12 69.57 258.47 5,179.00 5,122.80 -799.88 -5,350.28 6,030,273.19 464,468.24 0.50 4,718.00 MWD+IFR2+MS+sag(5) 8,438.00 69.60 258.48 5,195.01 5,138.81 -808.47 -5,392.41 6,030,264.77 464,426.07 0.07 4,754.33 MWD+IFR2+MS+sag(6) 8,529.05 72.36 255.25 5,224.69 5,168.49 -828.05 -5,476.21 6,030,245.54 464,342.20 4.52 4,825.73 MWD+IFR2+MS+sag(6) 8,575.56 73.36 254.40 5,238.39 5,182.19 -839.68 -5,519.11 6,030,234.08 464,299.27 2.77 4,861.70 MWD+IFR2+MS+sag(6) 8,670.27 74.48 252.70 5,264.63 5,208.43 -865.46 -5,606.38 6,030,208.67 464,211.90 2.09 4,934.14 MWD+IFR2+MS+sag(6) 8,718.63 74.39 251.47 5,277.60 5,221.40 -879.79 -5,650.71 6,030,194.52 464,167.52 2.46 4,970.50 MWD+IFR2+MS+sag(6) 8,785.71 74.04 252.09 5,295.85 5,239.65 -899.97 -5,712.02 6,030,174.59 464,106.13 1.03 5,020.66 MWD+IFR2+MS+sag(6) 8,881.94 73.38 251.52 5,322.84 5,266.64 -928.81 -5,799.77 6,030,146.10 464,018.28 0.89 5,092.45 MWD+IFR2+MS+sag(6) 8,977.86 73.11 252.53 5,350.50 5,294.30 -957.15 -5,887.13 6,030,118.12 463,930.81 1.05 5,164.07 MWD+IFR2+MS+sag(6) 9,072.22 72.75 254.47 5,378.20 5,322.00 -982.77 -5,973.61 6,030,092.85 463,844.23 2.00 5,235.83 MWD+IFR2+MS+sag(6) 9,168.00 72.53 256.55 5,406.78 5,350.58 -1,005.65 -6,062.12 6,030,070.34 463,755.64 2.09 5,310.45 MWD+IFR2+MS+sag(6) 9,262.77 72.47 260.99 5,435.29 5,379.09 -1,023.24 -6,150.74 6,030,053.11 463,666.95 4.47 5,387.06 MWD+IFR2+MS+sag(6) 9,357.47 72.46 264.53 5,463.83 5,407.63 -1,034.62 -6,240.31 6,030,042.09 463,577.35 3.56 5,466.75 MWD+IFR2+MS+sag(6) 9,452.53 71.85 267.34 5,492.97 5,436.77 -1,041.04 -6,330.55 6,030,036.04 463,487.09 2.89 5,548.84 MWD+IFR2+MS+sag(6) 9,547.64 72.27 271.43 5,522.27 5,466.07 -1,042.01 -6,421.01 6,030,035.44 463,396.64 4.11 5,633.07 MWD+IFR2+MS+sag(6) 9,642.41 72.06 275.01 5,551.31 5,495.11 -1,036.94 -6,511.07 6,030,040.87 463,306.61 3.60 5,719.06 MWD+IFR2+MS+sag(6) 9,737.67 71.99 278.14 5,580.71 5,524.51 -1,026.57 -6,601.07 6,030,051.61 463,216.66 3.13 5,806.88 MWD+IFR2+MS+sag(6) 9,833.18 71.37 281.53 5,610.74 5,554.54 -1,011.09 -6,690.39 6,030,067.45 463,127.42 3.43 5,895.88 MWD+IFR2+MS+sag(6) 9,929.57 71.41 286.08 5,641.51 5,585.31 -989.30 -6,779.07 6,030,089.60 463,038.83 4.47 5,986.53 MWD+IFR2+MS+sag(6) 10,024.64 71.38 289.64 5,671.85 5,615.65 -961.67 -6,864.82 6,030,117.57 462,953.21 3.55 6,076.49 MWD+IFR2+MS+sag(6) 10,118.68 72.08 292.42 5,701.34 5,645.14 -929.62 -6,948.16 6,030,149.95 462,870.01 2.90 6,165.78 MWD+IFR2+MS+sag(6) 10,214.27 72.08 296.36 5,730.76 5,674.56 -892.07 -7,030.97 6,030,187.83 462,787.35 3.92 6,256.53 MWD+IFR2+MS+sag(6) 10,309.31 71.94 299.25 5,760.12 5,703.92 -849.92 -7,110.92 6,030,230.31 462,707.59 2.90 6,346.24 MWD+IFR2+MS+sag(6) 10,404.13 72.22 300.94 5,789.30 5,733.10 -804.68 -7,188.97 6,030,275.86 462,629.73 1.72 6,435.27 MWD+IFR2+MS+sag(6) 10,498.75 73.56 303.93 5,817.14 5,760.94 -756.17 -7,265.28 6,030,324.67 462,553.62 3.34 6,523.82 MWD+IFR2+MS+sag(6) 10,593.70 74.26 308.42 5,843.47 5,787.27 -702.34 -7,338.90 6,030,378.80 462,480.23 4.60 6,611.75 MWD+IFR2+MS+sag(6) 10,689.51 74.46 309.71 5,869.30 5,813.10 -644.19 -7,410.53 6,030,437.23 462,408.84 1.31 6,699.36 MWD+IFR2+MS+sag(6) 10,784.19 74.92 311.89 5,894.30 5,838.10 -584.53 -7,479.65 6,030,497.17 462,339.97 2.27 6,785.16 MWD+IFR2+MS+sag(6) 1/312011 9:34:53AM Page 5 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB2 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 10,879.86 74.40 314.18 5,919.61 5,863.41 -521.57 -7,547.09 6,030,560.39 462,272.80 2.37 6,870.55 MWD+IFR2+MS+sag(6) 10,975.10 74.72 315.49 5,944.97 5,888.77 -456.84 -7,612.19 6,030,625.38 462,207.97 1.37 6,954.38 MWD+IFR2+MS+sag(6) 11,070.33 75.73 317.97 5,969.26 5,913.06 -389.80 -7,675.29 6,030,692.67 462,145.14 2.73 7,037.18 MWD+IFR2+MS+sag(6) 11,166.35 75.55 321.26 5,993.08 5,936.88 -318.96 -7,735.55 6,030,763.75 462,085.18 3.32 7,118.66 MWD+IFR2+MS+sag(6) 11,261.96 75.75 324.90 6,016.78 5,960.58 -244.92 -7,791.18 6,030,838.01 462,029.85 3.69 7,196.95 MWD+IFR2+MS+sag(6) 11,357.50 76.88 328.38 6,039.39 5,983.19 -167.40 -7,842.21 6,030,915.73 461,979.14 3.73 7,272.17 MWD+IFR2+MS+sag(6) 11,451.93 77.90 332.01 6,060.02 6,003.82 -87.45 -7,888.00 6,030,995.85 461,933.68 3.90 7,343.36 MWD+IFR2+MS+sag(6) 11,547.13 79.28 336.17 6,078.86 6,022.66 -3.53 -7,928.76 6,031,079.93 461,893.27 4.52 7,411.25 MWD+IFR2+MS+sag(6) 11,642.52 79.79 339.06 6,096.19 6,039.99 83.20 -7,964.48 6,031,166.79 461,857.91 3.03 7,475.42 MWD+IFR2+MS+sag(6) 11,736.96 79.85 338.89 6,112.88 6,056.68 169.96 -7,997.83 6,031,253.68 461,824.91 0.19 7,537.40 MWD+IFR2+MS+sag(6) 11,831.99 79.89 339.14 6,129.59 6,073.39 257.31 -8,031.33 6,031,341.15 461,791.77 0.26 7,599.72 MWD+IFR2+MS+sag(6) 11,927.00 79.58 341.03 6,146.52 6,090.32 345.20 -8,063.17 6,031,429.17 461,760.29 1.98 7,660.69 MWD+IFR2+MS+sag(6) 12,022.53 80.09 342.27 6,163.38 6,107.18 434.45 -8,092.78 6,031,518.52 461,731.05 1.38 7,720.04 MWD+IFR2+MS+sag(6) 12,067.94 80.08 343.26 6,171.20 6,115.00 477.17 -8,106.03 6,031,561.30 461,717.97 2.15 7,747.59 MWD+IFR2+MS+sag(6) 12,130.35 80.46 344.34 6,181.75 6,125.55 536.24 -8,123.19 6,031,620.43 461,701.05 1.81 7,784.60 MWD+IFR2+MS+sag(6) 12,226.85 78.05 345.06 6,199.74 6,143.54 627.68 -8,148.21 6,031,711.96 461,676.41 2.60 7,840.45 MWD+IFR2+MS+sag(6) 12,323.13 79.90 344.39 6,218.15 6,161.95 718.84 -8,173.11 6,031,803.21 461,651.89 2.04 7,896.08 MWD+IFR2+MS+sag(6) 12,419.53 83.34 341.67 6,232.20 6,176.00 810.03 -8,200.94 6,031,894.51 461,624.42 4.53 7,954.48 MWD+IFR2+MS+sag(6) 12,515.15 85.33 338.85 6,241.64 6,185.44 899.58 -8,233.08 6,031,984.17 461,592.65 3.60 8,016.30 MWD+IFR2+MS+sag(6) 12,611.86 86.43 338.69 6,248.59 6,192.39 989.49 -8,268.01 6,032,074.22 461,558.09 1.15 8,080.87 MWD+IFR2+MS+sag(6) 12,709.02 86.05 335.00 6,254.96 6,198.76 1,078.62 -8,306.13 6,032,163.49 461,520.34 3.81 8,148.14 MWD+IFR2+MS+sag(6) 12,756.65 88.94 333.98 6,257.05 6,200.85 1,121.56 -8,326.62 6,032,206.51 461,500.03 6.43 8,182.54 MWD+IFR2+MS+sag(6) 12,805.33 88.59 332.68 6,258.10 6,201.90 1,165.05 -8,348.46 6,032,250.08 461,478.36 2.76 8,218.40 MWD+IFR2+MS+sag(6) 12,858.81 84.34 333.33 6,261.39 6,205.19 1,212.60 -8,372.69 6,032,297.72 461,454.33 8.04 8,257.92 MWD+IFR2+MS+sag(6) 12,900.82 83.69 333.14 6,265.77 6,209.57 1,249.90 -8,391.50 6,032,335.10 461,435.67 1.61 8,288.75 MWD+IFR2+MS+sag(6) 12,954.44 84.76 333.80 6,271.17 6,214.97 1,297.63 -8,415.33 6,032,382.92 461,412.04 2.34 8,327.97 MWD+IFR2+MS+sag(6) 12,998.29 88.76 333.26 6,273.65 6,217.45 1,336.81 -8,434.84 6,032,422.18 461,392.69 9.20 8,360.12 MWD+IFR2+MS+sag(6) 13,051.34 91.03 333.55 6,273.74 6,217.54 1,384.25 -8,458.59 6,032,469.70 461,369.14 4.31 8,399.16 MWD+IFR2+MS+sag(6) 13,093.81 90.88 332.65 6,273.03 6,216.83 1,422.12 -8,477.80 6,032,507.65 461,350.08 2.15 8,430.56 MWD+IFR2+MS+sag(6) 13,191.37 91.50 329.19 6,271.01 6,214.81 1,507.35 -8,525.20 6,032,593.06 461,303.03 3.60 8,505.12 MWD+IFR2+MS+sag(6) 13,287.26 92.68 329.55 6,267.51 6,211.31 1,589.80 -8,574.02 6,032,675.70 461,254.55 1.29 8,580.03 MWD+IFR2+MS+sag(6) 13,381.84 93.67 330.17 6,262.27 6,206.07 1,671.47 -8,621.44 6,032,757.55 461,207.47 1.23 8,653.35 MWD+IFR2+MS+sag(6) 1/31/2011 9:34:53AM Page 6 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development ND Reference: 42.7'+13.5(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB3 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB3 Database: .Pioneer 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 ODSN-18-Slot ODS-18 Well Position +N/-S 0.00 ft Northing: 6,031,051.27 ft Latitude: 70°29'45.254 N +EI-W 0.00 ft Easting: 469,821.18 ft Longitude: 150°14'48.375 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft Wellbore ODSN-18 PB3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-18 PN11 PB3 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,090.00 I Vertical Section: Depth From(ND) +NI-S +E/-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 273.96 Survey Program Date 1/27/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 141.00 981.00 ODSN-18 PB1 Gyro 1 (ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 10/25/2010 1,027.53 1,027.53 ODSN-18 PBI MWD 1 (ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/2/2010 1: 1,123.00 1,123.00 ODSN-18 PB1 Gyro 2(ODSN-18 PBI) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 11/2/2010 1: 1,174.40 3,566.42 ODSN-18 PB1 MWD 2(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/26/2010 • 3,630.15 8,392.10 ODSN-18 PB1 MWD 3(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/1/2010 1: 8,438.00 12,090.00 ODSN-18 PB2 MWD 4(ODSN-18 PB2) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/5/2010 1: 12,122.46 13,831.22 ODSN-18 PB3 MWD 5(ODSN-18 PB3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/22/2010 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +EI-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 6,031,051.27 469,821.18 0.00 0.00 UNDEFINED 141.00 0.26 304.00 141.00 84.80 0.13 -0.19 6,031,051.40 469,820.99 0.26 0.19 SR-Gyro-SS(1) 199.00 0.27 348.71 199.00 142.80 0.33 -0.32 6,031,051.60 469,820.86 0.35 0.34 SR-Gyro-SS(1) 232.00 0.49 322.56 232.00 175.80 0.52 -0.42 6,031,051.79 469,820.76 0.83 0.46 SR-Gyro-SS(1) 290.00 0.48 322.52 290.00 233.80 0.91 -0.72 6,031,052.18 469,820.46 0.02 0.78 SR-Gyro-SS(1) 323.00 0.93 308.43 322.99 266.79 1.19 -1.02 6,031,052.46 469,820.17 1.45 1.09 SR-Gyro-SS(1) 382.00 1.25 295.72 381.98 325.78 1.76 -1.97 6,031,053.04 469,819.22 0.68 2.09 SR-Gyro-SS(1) 415.00 1.90 288.47 414.97 358.77 2.09 -2.81 6,031,053.38 469,818.38 2.06 2.95 SR-Gyro-SS(1) 472.00 2.17 284.07 471.93 415.73 2.66 -4.76 6,031,053.94 469,816.43 0.55 4.93 SR-Gyro-SS(1) 1/31/2011 9:33:25AM Page 2 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB3 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB3 Database: .Pioneer 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 505.00 2.74 284.05 504.90 448.70 3.00 -6.13 6,031,054.29 469,815.06 1.73 6.32 SR-Gyro-SS(1) 568.00 3.14 281.82 567.82 511.62 3.72 -9.28 6,031,055.03 469,811.92 0.66 9.51 SR-Gyro-SS(1) 601.00 3.54 281.44 600.76 544.56 4.11 -11.16 6,031,055.42 469,810.04 1.21 11.42 SR-Gyro-SS(1) 662.00 3.66 281.14 661.64 605.44 4.86 -14.92 6,031,056.19 469,806.28 0.20 15.22 SR-Gyro-SS(1) 685.00 3.95 280.22 684.59 628.39 5.14 -16.42 6,031,056.47 469,804.79 1.29 16.73 SR-Gyro-SS(1) 758.00 4.41 281.46 757.40 701.20 6.14 -21.64 6,031,057.50 469,799.57 0.64 22.01 SR-Gyro-SS(1) 791.00 4.78 281.29 790.29 734.09 6.66 -24.23 6,031,058.03 469,796.98 1.12 24.63 SR-Gyro-SS(1) 853.00 5.29 282.35 852.05 795.85 7.78 -29.56 6,031,059.17 469,791.66 0.84 30.02 SR-Gyro-SS(1) 886.00 5.85 279.85 884.90 828.70 8.39 -32.70 6,031,059.79 469,788.52 1.85 33.20 SR-Gyro-SS(1) 948.00 6.88 279.90 946.51 890.31 9.57 -39.47 6,031,061.00 469,781.75 1.66 40.04 SR-Gyro-SS(1) 981.00 6.89 278.10 979.28 923.08 10.19 -43.38 6,031,061.64 469,777.85 0.65 43.98 SR-Gyro-SS(1) 1,027.53 6.83 276.30 1,025.47 969.27 10.89 -48.89 6,031,062.35 469,772.34 0.48 49.53 MWD+IFR2+MS+sag(2) 1,123.00 9.55 277.06 1,119.96 1,063.76 12.48 -62.40 6,031,064.01 469,758.84 2.85 63.11 SR-Gyro-SS(3) 1,174.43 9.71 277.20 1,170.67 1,114.47 13.55 -70.93 6,031,065.11 469,750.31 0.31 71.70 MWD+IFR2+MS+sag(4) 1,218.54 9.91 278.29 1,214.13 1,157.93 14.57 -78.38 6,031,066.15 469,742.87 0.62 79.20 MWD+IFR2+MS+sag(4) 1,314.10 9.75 271.65 1,308.29 1,252.09 15.98 -94.61 6,031,067.64 469,726.65 1.20 95.48 MWD+IFR2+MS+sag(4) 1,409.32 10.15 272.52 1,402.08 1,345.88 16.59 -111.05 6,031,068.30 469,710.21 0.45 111.93 MWD+IFR2+MS+sag(4) 1,504.37 10.95 274.95 1,495.52 1,439.32 17.73 -128.41 6,031,069.52 469,692.86 0.96 129.33 MWD+IFR2+MS+sag(4) 1,599.91 12.48 272.29 1,589.07 1,532.87 18.93 -147.77 6,031,070.80 469,673.51 1.70 148.72 MWD+IFR2+MS+sag(4) 1,631.69 12.76 273.11 1,620.08 1,563.88 19.26 -154.70 6,031,071.15 469,666.57 1.05 155.66 MWD+IFR2+MS+sag(4) 1,725.28 14.37 274.13 1,711.06 1,654.86 20.65 -176.61 6,031,072.64 469,644.68 1.74 177.61 MWD+IFR2+MS+sag(4) 1,821.10 13.44 273.34 1,804.07 1,747.87 22.16 -199.58 6,031,074.24 469,621.71 0.99 200.64 MWD+IFR2+MS+sag(4) `fEl 1,915.58 15.28 274.70 1,895.59 1,839.39 23.82 -222.95 6,031,075.99 469,598.35 1.98 224.07 MWD+IFR2+MS+sag(4) 2,011.74 15.85 275.48 1,988.23 1,932.03 26.11 -248.65 6,031,078.39 469,572.66 0.63 249.86 MWD+IFR2+MS+sag(4) 2,107.39 14.66 274.53 2,080.51 2,024.31 28.31 -273.72 6,031,080.69 469,547.60 1.27 275.02 MWD+IFR2+MS+sag(4) 2,202.94 13.62 277.80 2,173.16 2,116.96 30.80 -296.92 6,031,083.27 469,524.41 1.37 298.34 MWD+IFR2+MS+sag(4) 2,241.41 13.96 276.43 2,210.52 2,154.32 31.93 -306.02 6,031,084.44 469,515.32 1.23 307.50 MWD+IFR2+MS+sag(4) 2,298.61 14.97 276.21 2,265.91 2,209.71 33.50 -320.22 6,031,086.07 469,501.13 1.77 321.77 MWD+IFR2+MS+sag(4) 2,333.40 15.89 274.27 2,299.44 2,243.24 34.34 -329.44 6,031,086.95 469,491.92 3.03 331.02 MWD+IFR2+MS+sag(4) i 2,393.28 16.92 271.13 2,356.89 2,300.69 35.12 -346.33 6,031,087.80 469,475.03 2.27 347.93 MWD+IFR2+MS+sag(4) 2,488.03 20.47 266.74 2,446.63 2,390.43 34.45 -376.67 6,031,087.25 469,444.70 4.03 378.14 MWD+IFR2+MS+sag(4) 2,583.22 24.38 267.73 2,534.60 2,478.40 32.73 -412.93 6,031,085.67 469,408.43 4.13 414.20 MWD+IFR2+MS+sag(4) 2,678.36 29.60 267.12 2,619.35 2,563.15 30.77 -456.05 6,031,083.89 469,365.31 5.49 457.08 MWD+IFR2+MS+sag(4) 2,773.39 32.86 268.44 2,700.60 2,644.40 28.89 -505.27 6,031,082.21 469,316.08 3.51 506.06 MWD+IFR2+MS+sag(4) 2,868.92 36.48 268.01 2,779.16 2,722.96 27.20 -559.58 6,031,080.73 469,261.77 3.80 560.12 MWD+IFR2+MS+sag(4) ` 2,963.62 38.66 267.56 2,854.21 2,798.01 24.96 -617.27 6,031,078.73 469,204.08 2.32 617.52 MWD+IFR2+MS+sag(4) ! 3,059.68 38.65 266.41 2,929.23 2,873.03 21.80 -677.19 6,031,075.82 469,144.15 0.75 677.08 MWD+IFR2+MS+sag(4) 3,155.09 41.44 265.51 3,002.26 2,946.06 17.46 -738.41 6,031,071.73 469,082.92 2.99 737.85 MWD+IFR2+MS+sag(4) 3,249.55 42.15 264.91 3,072.68 3,016.48 12.20 -801.15 6,031,066.73 469,020.17 0.86 800.07 MWD+IFR2+MS+sag(4) 3,344.92 46.28 265.36 3,141.02 3,084.82 6.58 -867.40 6,031,061.37 468,953.90 4.34 865.78 MWD+IFR2+MS+sag(4) 1/31/2011 9:33:25AM Page 3 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB3 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB3 Database: .Pioneer Alaska i Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section 11 (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) envy) (ft) Survey Tool Name 3,439.63 48.20 265.43 3,205.32 3,149.12 0.99 -936.71 6,031,056.07 468,884.58 2.03 934.54 MWD+IFR2+MS+sag(4) 3,534.85 49.89 264.83 3,267.73 3,211.53 -5.12 -1,008.36 6,031,050.25 468,812.91 1.84 1,005.59 MWD+IFR2+MS+sag(4) 3,566.42 50.37 265.46 3,287.97 3,231.77 -7.17 -1,032.50 6,031,048.30 468,788.76 2.16 1,029.54 MWD+IFR2+MS+sag(4) 3,630.15 49.94 264.80 3,328.80 3,272.60 -11.32 -1,081.25 6,031,044.34 468,740.00 1.04 1,077.89 MWD+IFR2+MS+sag(5) 3,728.64 48.98 264.86 3,392.82 3,336.62 -18.06 -1,155.80 6,031,037.90 468,665.44 0.98 1,151.78 MWD+IFR2+MS+sag(5) 3,823.03 48.55 265.70 3,455.04 3,398.84 -23.91 -1,226.54 6,031,032.35 468,594.68 0.81 1,221.95 MWD+IFR2+MS+sag(5) 3,918.36 47.71 266.13 3,518.66 3,462.46 -28.97 -1,297.34 6,031,027.57 468,523.86 0.94 1,292.24 MWD+IFR2+MS+sag(5) 4,013.58 47.75 266.18 3,582.71 3,526.51 -33.69 -1,367.65 6,031,023.14 468,453.55 0.06 1,362.05 MWD+IFR2+MS+sag(5) 4,108.84 51.32 267.02 3,644.52 3,588.32 -37.97 -1,439.98 6,031,019.15 468,381.20 3.81 1,433.91 MWD+IFR2+MS+sag(5) 4,203.49 54.06 266.88 3,701.89 3,645.69 -41.98 -1,515.15 6,031,015.45 468,306.03 2.90 1,508.62 MWD+IFR2+MS+sag(5) 4,300.86 56.97 265.70 3,757.01 3,700.81 -47.19 -1,595.23 6,031,010.56 468,225.93 3.15 1,588.15 MWD+IFR2+MS+sag(5) 4,398.80 58.70 262.86 3,809.16 3,752.96 -55.47 -1,677.71 6,031,002.62 468,143.43 3.02 1,669.86 MWD+IFR2+MS+sag(5) 4,493.85 61.31 259.87 3,856.68 3,800.48 -67.85 -1,759.07 6,030,990.57 468,062.03 3.87 1,750.17 MWD+IFR2+MS+sag(5) 4,584.47 65.00 259.37 3,897.60 3,841.40 -82.42 -1,838.58 6,030,976.32 467,982.46 4.10 1,828.49 MWD+IFR2+MS+sag(5) 4,684.58 67.49 257.58 3,937.92 3,881.72 -100.74 -1,928.35 6,030,958.37 467,892.63 2.98 1,916.78 MWD+IFR2+MS+sag(5) 4,779.26 68.84 257.43 3,973.14 3,916.94 -119.76 -2,014.15 6,030,939.70 467,806.76 1.43 2,001.06 MWD+IFR2+MS+sag(5) 4,871.89 70.51 256.93 4,005.31 3,949.11 -139.03 -2,098.85 6,030,920.77 467,722.00 1.87 2,084.22 MWD+IFR2+MS+sag(5) 4,965.11 71.34 257.43 4,035.78 3,979.58 -158.58 -2,184.75 6,030,901.58 467,636.02 1.02 2,168.57 MWD+IFR2+MS+sag(5) 5,063.57 71.46 258.28 4,067.18 4,010.98 -178.21 -2,275.98 6,030,882.32 467,544.73 0.83 2,258.22 MWD+IFR2+MS+sag(5) 5,159.38 71.34 258.20 4,097.74 4,041.54 -196.72 -2,364.88 6,030,864.17 467,455.76 0.15 2,345.63 MWD+IFR2+MS+sag(5) 5,254.53 71.20 258.00 4,128.29 4,072.09 -215.30 -2,453.05 6,030,845.95 467,367.52 0.25 2,432.31 MWD+IFR2+MS+sag(5) 5,345.36 70.63 257.39 4,157.99 4,101.79 -233.59 -2,536.92 6,030,828.00 467,283.59 0.89 2,514.71 MWD+IFR2+MS+sag(5) 5,441.12 71.23 257.83 4,189.28 4,133.08 -253.01 -2,625.31 6,030,808.94 467,195.13 0.76 2,601.55 MWD+IFR2+MS+sag(5) 5,536.74 71.07 258.19 4,220.17 4,163.97 -271.81 -2,713.83 6,030,790.51 467,106.54 0.39 2,688.56 MWD+IFR2+MS+sag(5) 5,631.50 70.36 258.20 4,251.47 4,195.27 -290.11 -2,801.38 6,030,772.57 467,018.93 0.75 2,774.64 MWD+IFR2+MS+sag(5) 5,727.44 70.95 258.18 4,283.25 4,227.05 -308.63 -2,889.99 6,030,754.40 466,930.25 0.62 2,861.75 MWD+IFR2+MS+sag(5) 5,824.68 70.61 258.07 4,315.26 4,259.06 -327.53 -2,979.84 6,030,735.87 466,840.33 0.37 2,950.09 MWD+IFR2+MS+sag(5) 5,917.59 70.86 257.56 4,345.92 4,289.72 -346.04 -3,065.57 6,030,717.71 466,754.54 0.58 3,034.33 MWD+IFR2+MS+sag(5) 6,011.23 71.05 257.12 4,376.47 4,320.27 -365.44 -3,151.94 6,030,698.66 466,668.11 0.49 3,119.15 MWD+IFR2+MS+sag(5) 6,109.85 70.29 255.57 4,409.12 4,352.92 -387.41 -3,242.36 6,030,677.07 466,577.60 1.67 3,207.84 MWD+IFR2+MS+sag(5) 6,206.00 70.35 256.98 4,441.50 4,385.30 -408.89 -3,330.31 6,030,655.95 466,489.58 1.38 3,294.09 MWD+IFR2+MS+sag(5) 6,296.96 70.47 257.77 4,472.00 4,415.80 -427.62 -3,413.93 6,030,637.56 466,405.89 0.83 3,376.22 MWD+IFR2+MS+sag(5) 6,392.50 70.96 258.81 4,503.55 4,447.35 -445.92 -3,502.23 6,030,619.62 466,317.52 1.15 3,463.04 MWD+IFR2+MS+sag(5) 6,487.74 71.03 259.25 4,534.57 4,478.37 -463.05 -3,590.63 6,030,602.84 466,229.06 0.44 3,550.05 MWD+IFR2+MS+sag(5) 6,582.74 70.87 258.69 4,565.57 4,509.37 -480.23 -3,678.77 6,030,586.02 466,140.86 0.58 3,636.79 MWD+IFR2+MS+sag(5) 6,677.75 70.73 259.06 4,596.82 4,540.62 -497.54 -3,766.81 6,030,569.07 466,052.76 0.40 3,723.42 MWD+IFR2+MS+sag(5) 6,773.48 71.16 258.45 4,628.07 4,571.87 -515.19 -3,855.56 6,030,551.79 465,963.95 0.75 3,810.74 MWD+IFR2+MS+sag(5) 6,868.81 71.27 257.68 4,658.77 4,602.57 -533.85 -3,943.86 6,030,533.48 465,875.59 0.77 3,897.54 MWD+IFR2+MS+sag(5) 6,964.81 70.80 259.14 4,689.97 4,633.77 -552.10 -4,032.79 6,030,515.61 465,786.59 1.52 3,985.00 MWD+IFR2+MS+sag(5) 7,058.66 71.73 258.75 4,720.12 4,663.92 569.14 4,120.02 6,030,498.92 465,699.30 1.07 4,070.84 MWD+IFR2+MS+sag(5) 1/31/2011 9:33:25AM Page 4 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB3 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB3 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 7,155.94 70.48 258.65 4,751.62 4,695.42 -587.17 -4,210.27 6,030,481.25 465,608.99 1.29 4,159.63 MWD+IFR2+MS+sag(5) 7,249.11 70.27 258.33 4,782.91 4,726.71 -604.68 -4,296.26 6,030,464.09 465,522.93 0.39 4,244.21 MWD+IFR2+MS+sag(5) 7,345.08 71.16 258.01 4,814.61 4,758.41 -623.25 -4,384.92 6,030,445.88 465,434.21 0.98 4,331.37 MWD+IFR2+MS+sag(5) 7,441.17 70.89 257.84 4,845.85 4,789.65 -642.26 -4,473.78 6,030,427.24 465,345.28 0.33 4,418.70 MWD+IFR2+MS+sag(5) 7,536.09 69.56 258.34 4,877.96 4,821.76 -660.70 -4,561.18 6,030,409.16 465,257.82 1.49 4,504.62 MWD+IFR2+MS+sag(5) 7,626.41 69.56 260.20 4,909.51 4,853.31 -676.45 -4,644.33 6,030,393.74 465,174.61 1.93 4,586.48 MWD+IFR2+MS+sag(5) 7,726.42 69.36 260.00 4,944.60 4,888.40 -692.56 -4,736.58 6,030,378.02 465,082.30 0.27 4,677.40 MWD+IFR2+MS+sag(5) 7,820.69 69.02 260.88 4,978.09 4,921.89 -707.19 -4,823.48 6,030,363.74 464,995.36 0.94 4,763.08 MWD+IFR2+MS+sag(5) 7,915.20 69.21 260.17 5,011.78 4,955.58 -721.73 -4,910.57 6,030,349.56 464,908.21 0.73 4,848.96 MWD+IFR2+MS+sag(5) 8,011.00 69.69 260.57 5,045.41 4,989.21 -736.73 -4,999.01 6,030,334.91 464,819.72 0.64 4,936.15 MWD+IFR2+MS+sag(5) 8,106.40 69.26 260.81 5,078.86 5,022.66 -751.19 -5,087.18 6,030,320.82 464,731.51 0.51 5,023.11 MWD+IFR2+MS+sag(5) 8,201.28 69.17 260.04 5,112.53 5,056.33 -765.94 -5,174.65 6,030,306.42 464,643.99 0.76 5,109.35 MWD+IFR2+MS+sag(5) 8,296.82 69.86 258.87 5,145.97 5,089.77 -782.32 -5,262.63 6,030,290.40 464,555.95 1.36 5,195.99 MWD+IFR2+MS+sag(5) 8,392.12 69.57 258.47 5,179.00 5,122.80 -799.88 -5,350.28 6,030,273.19 464,468.24 0.50 5,282.22 MWD+IFR2+MS+sag(5) 8,438.00 69.60 258.48 5,195.01 5,138.81 -808.47 -5,392.41 6,030,264.77 464,426.07 0.07 5,323.65 MWD+IFR2+MS+sag(6) 8,529.05 72.36 255.25 5,224.69 5,168.49 -828.05 -5,476.21 6,030,245.54 464,342.20 4.52 5,405.90 MWD+IFR2+MS+sag(6) 8,575.56 73.36 254.40 5,238.39 5,182.19 -839.68 -5,519.11 6,030,234.08 464,299.27 2.77 5,447.89 MWD+IFR2+MS+sag(6) 8,670.27 74.48 252.70 5,264.63 5,208.43 -865.46 -5,606.38 6,030,208.67 464,211.90 2.09 5,533.17 MWD+IFR2+MS+sag(6) 8,718.63 74.39 251.47 5,277.60 5,221.40 -879.79 -5,650.71 6,030,194.52 464,167.52 2.46 5,576.40 MWD+IFR2+MS+sag(6) 8,785.71 74.04 252.09 5,295.85 5,239.65 -899.97 -5,712.02 6,030,174.59 464,106.13 1.03 5,636.18 MWD+IFR2+MS+sag(6) 8,881.94 73.38 251.52 5,322.84 5,266.64 -928.81 -5,799.77 6,030,146.10 464,018.28 0.89 5,721.72 MWD+IFR2+MS+sag(6) 8,977.86 73.11 252.53 5,350.50 5,294.30 -957.15 -5,887.13 6,030,118.12 463,930.81 1.05 5,806.92 MWD+IFR2+MS+sag(6) 9,072.22 72.75 254.47 5,378.20 5,322.00 -982.77 -5,973.61 6,030,092.85 463,844.23 2.00 5,891.42 MWD+IFR2+MS+sag(6) 9,168.00 72.53 256.55 5,406.78 5,350.58 -1,005.65 -6,062.12 6,030,070.34 463,755.64 2.09 5,978.13 MWD+IFR2+MS+sag(6) 9,262.77 72.47 260.99 5,435.29 5,379.09 -1,023.24 -6,150.74 6,030,053.11 463,666.95 4.47 6,065.33 MWD+IFR2+MS+sag(6) 9,357.47 72.46 264.53 5,463.83 5,407.63 -1,034.62 -6,240.31 6,030,042.09 463,577.35 3.56 6,153.90 MWD+IFR2+MS+sag(6) 9,452.53 71.85 267.34 5,492.97 5,436.77 -1,041.04 -6,330.55 6,030,036.04 463,487.09 2.89 6,243.48 MWD+IFR2+MS+sag(6) 9,547.64 72.27 271.43 5,522.27 5,466.07 -1,042.01 -6,421.01 6,030,035.44 463,396.64 4.11 6,333.66 MWD+IFR2+MS+sag(6) 9,642.41 72.06 275.01 5,551.31 5,495.11 -1,036.94 -6,511.07 6,030,040.87 463,306.61 3.60 6,423.85 MWD+IFR2+MS+sag(6) 9,737.67 71.99 278.14 5,580.71 5,524.51 -1,026.57 -6,601.07 6,030,051.61 463,216.66 3.13 6,514.35 MWD+IFR2+MS+sag(6) 9,833.18 71.37 281.53 5,610.74 5,554.54 -1,011.09 -6,690.39 6,030,067.45 463,127.42 3.43 6,604.53 MWD+IFR2+MS+sag(6) 9,929.57 71.41 286.08 5,641.51 5,585.31 -989.30 -6,779.07 6,030,089.60 463,038.83 4.47 6,694.51 MWD+IFR2+MS+sag(6) 10,024.64 71.38 289.64 5,671.85 5,615.65 -961.67 -6,864.82 6,030,117.57 462,953.21 3.55 6,781.95 MWD+IFR2+MS+sag(6) 10,118.68 72.08 292.42 5,701.34 5,645.14 -929.62 -6,948.16 6,030,149.95 462,870.01 2.90 6,867.31 MWD+IFR2+MS+sag(6) 10,214.27 72.08 296.36 5,730.76 5,674.56 -892.07 -7,030.97 6,030,187.83 462,787.35 3.92 6,952.52 MWD+IFR2+MS+sag(6) 10,309.31 71.94 299.25 5,760.12 5,703.92 -849.92 -7,110.92 6,030,230.31 462,707.59 2.90 7,035.19 MWD+IFR2+MS+sag(6) 10,404.13 72.22 300.94 5,789.30 5,733.10 -804.68 -7,188.97 6,030,275.86 462,629.73 1.72 7,116.18 MWD+IFR2+MS+sag(6) 10,498.75 73.56 303.93 5,817.14 5,760.94 -756.17 -7,265.28 6,030,324.67 462,553.62 3.34 7,195.66 MWD+IFR2+MS+sag(6) 10,593.70 74.26 308.42 5,843.47 5,787.27 -702.34 -7,338.90 6,030,378.80 462,480.23 4.60 7,272.82 MWD+IFR2+MS+sag(6) 10,689.51 74.46 309.71 5,869.30 5,813.10 -644.19 -7,410.53 6,030,437.23 462,408.84 1.31 7,348.30 MWD+IFR2+MS+sag(6) 1/31/2011 9:33:25AM Page 5 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB3 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB3 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,784.19 74.92 311.89 5,894.30 5,838.10 -584.53 -7,479.65 6,030,497.17 462,339.97 2.27 7,421.38 MWD+IFR2+MS+sag(6) 10,879.86 74.40 314.18 5,919.61 5,863.41 -521.57 -7,547.09 6,030,560.39 462,272.80 2.37 7,493.01 MWD+IFR2+MS+sag(6) 10,975.10 74.72 315.49 5,944.97 5,888.77 -456.84 -7,612.19 6,030,625.38 462,207.97 1.37 7,562.42 MWD+IFR2+MS+sag(6) 11,070.33 75.73 317.97 5,969.26 5,913.06 -389.80 -7,675.29 6,030,692.67 462,145.14 2.73 7,630.01 MWD+IFR2+MS+sag(6) 11,166.35 75.55 321.26 5,993.08 5,936.88 -318.96 -7,735.55 6,030,763.75 462,085.18 3.32 7,695.02 MWD+IFR2+MS+sag(6) 11,261.96 75.75 324.90 6,016.78 5,960.58 -244.92 -7,791.18 6,030,838.01 462,029.85 3.69 7,755.63 MWD+IFR2+MS+sag(6) 11,357.50 76.88 328.38 6,039.39 5,983.19 -167.40 -7,842.21 6,030,915.73 461,979.14 3.73 7,811.90 MWD+IFR2+MS+sag(6) 11,451.93 77.90 332.01 6,060.02 6,003.82 -87.45 -7,888.00 6,030,995.85 461,933.68 3.90 7,863.11 MWD+IFR2+MS+sag(6) 11,547.13 79.28 336.17 6,078.86 6,022.66 -3.53 -7,928.76 6,031,079.93 461,893.27 4.52 7,909.57 MWD+IFR2+MS+sag(6) 11,642.52 79.79 339.06 6,096.19 6,039.99 83.20 -7,964.48 6,031,166.79 461,857.91 3.03 7,951.19 MWD+IFR2+MS+sag(6) 11,736.96 79.85 338.89 6,112.88 6,056.68 169.96 -7,997.83 6,031,253.68 461,824.91 0.19 7,990.45 MWD+IFR2+MS+sag(6) 11,831.99 79.89 339.14 6,129.59 6,073.39 257.31 -8,031.33 6,031,341.15 461,791.77 0.26 8,029.91 MWD+IFR2+MS+sag(6) 11,927.00 79.58 341.03 6,146.52 6,090.32 345.20 -8,063.17 6,031,429.17 461,760.29 1.98 8,067.75 MWD+IFR2+MS+sag(6) 12,022.53 80.09 342.27 6,163.38 6,107.18 434.45 -8,092.78 6,031,518.52 461,731.05 1.38 8,103.45 MWD+IFR2+MS+sag(6) 12,067.94 80.08 343.26 6,171.20 6,115.00 477.17 -8,106.03 6,031,561.30 461,717.97 2.15 8,119.63 MWD+IFR2+MS+sag(6) 12,090.00 80.21 343.64 6,174.98 6,118.78 498.01 -8,112.22 6,031,582.15 461,711.87 1.81 8,127.24 MWD+IFR2+MS+sag(6) 12,122.46 80.82 341.19 6,180.33 6,124.13 528.52 -8,121.89 6,031,612.71 461,702.32 7.68 8,139.00 MWD+IFR2+MS+sag(7) 12,148.55 81.79 338.20 6,184.27 6,128.07 552.71 -8,130.84 6,031,636.92 461,693.47 11.92 8,149.60 MWD+IFR2+MS+sag(7) 12,196.49 83.40 336.52 6,190.45 6,134.25 596.58 -8,149.14 6,031,680.87 461,675.35 4.83 8,170.89 MWD+IFR2+MS+sag(7) 12,245.45 84.40 336.18 6,195.65 6,139.45 641.17 -8,168.67 6,031,725.53 461,656.00 2.16 8,193.45 MWD+IFR2+MS+sag(7) 12,289.71 84.07 336.40 6,200.10 6,143.90 681.49 -8,186.38 6,031,765.92 461,638.46 0.89 8,213.90 MWD+IFR2+MS+sag(7) 12,386.42 84.01 338.03 6,210.14 6,153.94 770.17 -8,223.63 6,031,854.74 461,601.58 1.68 8,257.19 MWD+IFR2+MS+sag(7) 12,483.58 83.89 342.52 6,220.39 6,164.19 861.10 -8,256.23 6,031,945.79 461,569.35 4.60 8,295.99 MWD+IFR2+MS+sag(7) 12,532.01 87.52 342.90 6,224.01 6,167.81 907.20 -8,270.58 6,031,991.95 461,555.19 7.54 8,313.50 MWD+IFR2+MS+sag(7) 12,579.25 88.92 342.40 6,225.48 6,169.28 952.27 -8,284.66 6,032,037.07 461,541.29 3.15 8,330.66 MWD+IFR2+MS+sag(7) 12,676.17 91.88 340.53 6,224.80 6,168.60 1,044.15 -8,315.46 6,032,129.06 461,510.86 3.61 8,367.74 MWD+IFR2+MS+sag(7) 12,771.79 93.54 338.11 6,220.28 6,164.08 1,133.49 -8,349.19 6,032,218.53 461,477.50 3.07 8,407.56 MWD+IFR2+MS+sag(7) 12,867.97 93.29 335.98 6,214.55 6,158.35 1,221.90 -8,386.63 6,032,307.08 461,440.43 2.23 8,451.02 MWD+IFR2+MS+sag(7) 12,964.98 94.47 334.09 6,207.99 6,151.79 1,309.64 -8,427.48 6,032,394.97 461,399.94 2.29 8,497.83 MWD+IFR2+MS+sag(7) 13,060.50 93.10 329.05 6,201.68 6,145.48 1,393.42 -8,472.84 6,032,478.93 461,354.92 5.46 8,548.87 MWD+IFR2+MS+sag(7) 13,157.22 93.54 323.98 6,196.07 6,139.87 1,473.93 -8,526.10 6,032,559.65 461,302.00 5.25 8,607.56 MWD+IFR2+MS+sag(7) 13,253.93 92.85 326.30 6,190.68 6,134.48 1,553.15 -8,581.28 6,032,639.09 461,247.14 2.50 8,668.09 MWD+IFR2+MS+sag(7) 13,350.10 94.35 326.92 6,184.64 6,128.44 1,633.29 -8,634.10 6,032,719.43 461,194.65 1.69 8,726.32 MWD+IFR2+MS+sag(7) 13,445.74 92.47 326.08 6,178.96 6,122.76 1,712.90 -8,686.79 6,032,799.24 461,142.29 2.15 8,784.39 MWD+IFR2+MS+sag(7) 13,542.36 88.76 325.39 6,177.92 6,121.72 1,792.73 -8,741.18 6,032,879.29 461,088.23 3.91 8,844.16 MWD+IFR2+MS+sag(7) 13,640.95 85.11 324.65 6,183.19 6,126.99 1,873.38 -8,797.61 6,032,960.16 461,032.14 3.78 8,906.03 MWD+IFR2+MS+sag(7) 13,735.11 81.38 323.29 6,194.26 6,138.06 1,948.99 -8,852.60 6,033,035.98 460,977.46 4.21 8,966.11 MWD+IFR2+MS+sag(7) 13,831.22 81.47 320.84 6,208.60 6,152.40 2,023.93 -8,911.02 6,033,111.16 460,919.35 2.52 9,029.57 MWD+IFR2+MS+sag(7) 1/312011 9:33:25AM Page 6 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)©56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)©56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB4 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB4 Database: .Pioneer 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 ODSN-18-Slot ODS-18 Well Position +N/-S 0.00 ft Northing: 6,031,051.27 ft Latitude: 70°29'45.254 N +E/-W 0.00 ft Easting: 469,821.18 ft Longitude: 150° 14'48.375 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft Wellbore ODSN-18 PB4 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-18 PN11 PB4 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,771.79 Vertical Section: Depth From(ND) +N/-S +EI-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 277.72 Survey Program Date 1/27/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 141.00 981.00 ODSN-18 PB1 Gyro 1 (ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 10/25/2010 • 1,027.53 1,027.53 ODSN-18 PB1 MWD 1 (ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/2/2010 1: 1,123.00 1,123.00 ODSN-18 PB1 Gyro 2(ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 11/2/2010 1: 1,174.40 3,566.42 ODSN-18 PB1 MWD 2(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/26/2010 3,630.15 8,392.10 ODSN-18 PB1 MWD 3(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/1/2010 1: 8,438.00 12,090.00 ODSN-18 PB2 MWD 4(ODSN-18 PB2) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/5/2010 1: 12,122.46 12,771.79 ODSN-18 PB3 MWD 5(ODSN-18 PB3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/22/2010 12,850.00 13,736.40 ODSN-18 PB4 MWD 6(ODSN-18 PB4) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/30/2010 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-5 +EI-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 6,031,051.27 469,821.18 0.00 0.00 UNDEFINED 141.00 0.26 304.00 141.00 84.80 0.13 -0.19 6,031,051.40 469,820.99 0.26 0.20 SR-Gyro-SS(1) 199.00 0.27 348.71 199.00 142.80 0.33 -0.32 6,031,051.60 469,820.86 0.35 0.36 SR-Gyro-SS(1) 232.00 0.49 322.56 232.00 175.80 0.52 -0.42 6,031,051.79 469,820.76 0.83 0.49 SR-Gyro-SS(1) 290.00 0.48 322.52 290.00 233.80 0.91 0.72 6,031,052.18 469,820.46 0.02 0.84 SR-Gyro-SS(1) 323.00 0.93 308.43 322.99 266.79 1.19 -1.02 6,031,052.46 469,820.17 1.45 1.16 SR-Gyro-SS(1) 382.00 1.25 295.72 381.98 325.78 1.76 -1.97 6,031,053.04 469,819.22 0.68 2.19 SR-Gyro-SS(1) 415.00 1.90 288.47 414.97 358.77 2.09 -2.81 6,031,053.38 469,818.38 2.06 3.07 SR-Gyro-SS(1) 1/31/2011 9:31:53AM Page 2 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB4 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB4 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 472.00 2.17 284.07 471.93 415.73 2.66 -4.76 6,031,053.94 469,816.43 0.55 5.07 SR-Gyro-SS(1) 505.00 2.74 284.05 504.90 448.70 3.00 -6.13 6,031,054.29 469,815.06 1.73 6.47 SR-Gyro-SS(1) 568.00 3.14 281.82 567.82 511.62 3.72 -9.28 6,031,055.03 469,811.92 0.66 9.69 SR-Gyro-SS(1) 601.00 3.54 281.44 600.76 544.56 4.11 -11.16 6,031,055.42 469,810.04 1.21 11.61 SR-Gyro-SS(1) 662.00 3.66 281.14 661.64 605.44 4.86 -14.92 6,031,056.19 469,806.28 0.20 15.43 SR-Gyro-SS(1) 685.00 3.95 280.22 684.59 628.39 5.14 -16.42 6,031,056.47 469,804.79 1.29 16.96 SR-Gyro-SS(1) 758.00 4.41 281.46 757.40 701.20 6.14 -21.64 6,031,057.50 469,799.57 0.64 22.27 SR-Gyro-SS(1) 791.00 4.78 281.29 790.29 734.09 6.66 -24.23 6,031,058.03 469,796.98 1.12 24.91 SR-Gyro-SS(1) 853.00 5.29 282.35 852.05 795.85 7.78 -29.56 6,031,059.17 469,791.66 0.84 30.33 SR-Gyro-SS(1) 886.00 5.85 279.85 884.90 828.70 8.39 -32.70 6,031,059.79 469,788.52 1.85 33.53 SR-Gyro-SS(1) 948.00 6.88 279.90 946.51 890.31 9.57 -39.47 6,031,061.00 469,781.75 1.66 40.40 SR-Gyro-SS(1) 981.00 6.89 278.10 979.28 923.08 10.19 -43.38 6,031,061.64 469,777.85 0.65 44.35 SR-Gyro-SS(1) 1,027.53 6.83 276.30 1,025.47 969.27 10.89 -48.89 6,031,062.35 469,772.34 0.48 49.91 MWD+IFR2+MS+sag(2) 1,123.00 9.55 277.06 1,119.96 1,063.76 12.48 -62.40 6,031,064.01 469,758.84 2.85 63.51 SR-Gyro-SS(3) 1,174.43 9.71 277.20 1,170.67 1,114.47 13.55 -70.93 6,031,065.11 469,750.31 0.31 72.11 MWD+IFR2+MS+sag(4) 1,218.54 9.91 278.29 1,214.13 1,157.93 14.57 -78.38 6,031,066.15 469,742.87 0.62 79.63 MWD+IFR2+MS+sag(4) 1,314.10 9.75 271.65 1,308.29 1,252.09 15.98 -94.61 6,031,067.64 469,726.65 1.20 95.90 MWD+IFR2+MS+sag(4) 1,409.32 10.15 272.52 1,402.08 1,345.88 16.59 -111.05 6,031,068.30 469,710.21 0.45 112.27 MWD+IFR2+MS+sag(4) 1,504.37 10.95 274.95 1,495.52 1,439.32 17.73 -128.41 6,031,069.52 469,692.86 0.96 129.63 MWD+IFR2+MS+sag(4) 1,599.91 12.48 272.29 1,589.07 1,532.87 18.93 -147.77 6,031,070.80 469,673.51 1.70 148.97 MWD+IFR2+MS+sag(4) 1,631.69 12.76 273.11 1,620.08 1,563.88 19.26 -154.70 6,031,071.15 469,666.57 1.05 155.88 MWD+IFR2+MS+sag(4) 1,725.28 14.37 274.13 1,711.06 1,654.86 20.65 -176.61 6,031,072.64 469,644.68 1.74 177.78 MWD+IFR2+MS+sag(4) 1,821.10 13.44 273.34 1,804.07 1,747.87 22.16 -199.58 6,031,074.24 469,621.71 0.99 200.75 MWD+IFR2+MS+sag(4) 1,915.58 15.28 274.70 1,895.59 1,839.39 23.82 -222.95 6,031,075.99 469,598.35 1.98 224.13 MWD+IFR2+MS+sag(4) 2,011.74 15.85 275.48 1,988.23 1,932.03 26.11 -248.65 6,031,078.39 469,572.66 0.63 249.91 MWD+IFR2+MS+sag(4) 2,107.39 14.66 274.53 2,080.51 2,024.31 28.31 -273.72 6,031,080.69 469,547.60 1.27 275.04 MWD+IFR2+MS+sag(4) 2,202.94 13.62 277.80 2,173.16 2,116.96 30.80 -296.92 6,031,083.27 469,524.41 1.37 298.37 MWD+IFR2+MS+sag(4) 2,241.41 13.96 276.43 2,210.52 2,154.32 31.93 -306.02 6,031,084.44 469,515.32 1.23 307.54 MWD+IFR2+MS+sag(4) 2,298.61 14.97 276.21 2,265.91 2,209.71 33.50 -320.22 6,031,086.07 469,501.13 1.77 321.82 MWD+IFR2+MS+sag(4) 2,333.40 15.89 274.27 2,299.44 2,243.24 34.34 -329.44 6,031,086.95 469,491.92 3.03 331.07 MWD+IFR2+MS+sag(4) 2,393.28 16.92 271.13 2,356.89 2,300.69 35.12 -346.33 6,031,087.80 469,475.03 2.27 347.90 MWD+IFR2+MS+sag(4) 2,488.03 20.47 266.74 2,446.63 2,390.43 34.45 -376.67 6,031,087.25 469,444.70 4.03 377.88 MWD+IFR2+MS+sag(4) 2,583.22 24.38 267.73 2,534.60 2,478.40 32.73 -412.93 6,031,085.67 469,408.43 4.13 413.58 MWD+IFR2+MS+sag(4) 2,678.36 29.60 267.12 2,619.35 2,563.15 30.77 -456.05 6,031,083.89 469,365.31 5.49 456.04 MWD+IFR2+MS+sag(4) 2,773.39 32.86 268.44 2,700.60 2,644.40 28.89 -505.27 6,031,082.21 469,316.08 3.51 504.57 MWD+IFR2+MS+sag(4) 2,868.92 36.48 268.01 2,779.16 2,722.96 27.20 -559.58 6,031,080.73 469,261.77 3.80 558.15 MWD+IFR2+MS+sag(4) 2,963.62 38.66 267.56 2,854.21 2,798.01 24.96 -617.27 6,031,078.73 469,204.08 2.32 615.02 MWD+IFR2+MS+sag(4) 3,059.68 38.65 266.41 2,929.23 2,873.03 21.80 -677.19 6,031,075.82 469,144.15 0.75 673.97 MWD+IFR2+MS+sag(4) 3,155.09 41.44 265.51 3,002.26 2,946.06 17.46 -738.41 6,031,071.73 469,082.92 2.99 734.06 MWD+IFR2+MS+sag(4) 3,249.55 42.15 264.91 3,072.68 3,016.48 12.20 -801.15 6,031,066.73 469,020.17 0.86 795.52 MWD+IFR2+MS+sag(4) 1/31/2011 9:31:53AM Page 3 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)©56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB4 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB4 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 3,344.92 46.28 265.36 3,141.02 3,084.82 6.58 -867.40 6,031,061.37 468,953.90 4.34 860.41 MWD+IFR2+MS+sag(4) 3,439.63 48.20 265.43 3,205.32 3,149.12 0.99 -936.71 6,031,056.07 468,884.58 2.03 928.34 MWD+IFR2+MS+sag(4) 3,534.85 49.89 264.83 3,267.73 3,211.53 -5.12 -1,008.36 6,031,050.25 468,812.91 1.84 998.52 MWD+IFR2+MS+sag(4) 3,566.42 50.37 265.46 3,287.97 3,231.77 -7.17 -1,032.50 6,031,048.30 468,788.76 2.16 1,022.17 MWD+IFR2+MS+sag(4) 3,630.15 49.94 264.80 3,328.80 3,272.60 -11.32 -1,081.25 6,031,044.34 468,740.00 1.04 1,069.92 MWD+IFR2+MS+sag(5) 3,728.64 48.98 264.86 3,392.82 3,336.62 -18.06 -1,155.80 6,031,037.90 468,665.44 0.98 1,142.88 MWD+IFR2+MS+sag(5) 3,823.03 48.55 265.70 3,455.04 3,398.84 -23.91 -1,226.54 6,031,032.35 468,594.68 0.81 1,212.19 MWD+IFR2+MS+sag(5) 3,918.36 47.71 266.13 3,518.66 3,462.46 -28.97 -1,297.34 6,031,027.57 468,523.86 0.94 1,281.68 MWD+IFR2+MS+sag(5) 4,013.58 47.75 266.18 3,582.71 3,526.51 -33.69 -1,367.65 6,031,023.14 468,453.55 0.06 1,350.71 MWD+IFR2+MS+sag(5) 4,108.84 51.32 267.02 3,644.52 3,588.32 -37.97 -1,439.98 6,031,019.15 468,381.20 3.81 1,421.81 MWD+IFR2+MS+sag(5) 4,203.49 54.06 266.88 3,701.89 3,645.69 -41.98 -1,515.15 6,031,015.45 468,306.03 2.90 1,495.75 MWD+IFR2+MS+sag(5) 4,300.86 56.97 265.70 3,757.01 3,700.81 -47.19 -1,595.23 6,031,010.56 468,225.93 3.15 1,574.41 MWD+IFR2+MS+sag(5) 4,398.80 58.70 262.86 3,809.16 3,752.96 -55.47 -1,677.71 6,031,002.62 468,143.43 3.02 1,655.02 MWD+IFR2+MS+sag(5) 4,493.85 61.31 259.87 3,856.68 3,800.48 -67.85 -1,759.07 6,030,990.57 468,062.03 3.87 1,733.98 MWD+IFR2+MS+sag(5) 4,584.47 65.00 259.37 3,897.60 3,841.40 -82.42 -1,838.58 6,030,976.32 467,982.46 4.10 1,810.82 MWD+IFR2+MS+sag(5) 4,684.58 67.49 257.58 3,937.92 3,881.72 -100.74 -1,928.35 6,030,958.37 467,892.63 2.98 1,897.31 MWD+IFR2+MS+sag(5) 4,779.26 68.84 257.43 3,973.14 3,916.94 -119.76 -2,014.15 6,030,939.70 467,806.76 1.43 1,979.77 MWD+IFR2+MS+sag(5) 4,871.89 70.51 256.93 4,005.31 3,949.11 -139.03 -2,098.85 6,030,920.77 467,722.00 1.87 2,061.11 MWD+IFR2+MS+sag(5) 4,965.11 71.34 257.43 4,035.78 3,979.58 -158.58 -2,184.75 6,030,901.58 467,636.02 1.02 2,143.61 MWD+IFR2+MS+sag(5) 5,063.57 71.46 258.28 4,067.18 4,010.98 -178.21 -2,275.98 6,030,882.32 467,544.73 0.83 2,231.37 MWD+IFR2+MS+sag(5) 5,159.38 71.34 258.20 4,097.74 4,041.54 -196.72 -2,364.88 6,030,864.17 467,455.76 0.15 2,316.97 MWD+IFR2+MS+sag(5) 5,254.53 71.20 258.00 4,128.29 4,072.09 -215.30 -2,453.05 6,030,845.95 467,367.52 0.25 2,401.85 MWD+IFR2+MS+sag(5) 5,345.36 70.63 257.39 4,157.99 4,101.79 -233.59 -2,536.92 6,030,828.00 467,283.59 0.89 2,482.49 MWD+IFR2+MS+sag(5) 5,441.12 71.23 257.83 4,189.28 4,133.08 -253.01 -2,625.31 6,030,808.94 467,195.13 0.76 2,567.48 MWD+IFR2+MS+sag(5) 5,536.74 71.07 258.19 4,220.17 4,163.97 -271.81 -2,713.83 6,030,790.51 467,106.54 0.39 2,652.66 MWD+IFR2+MS+sag(5) 5,631.50 70.36 258.20 4,251.47 4,195.27 -290.11 -2,801.38 6,030,772.57 467,018.93 0.75 2,736.96 MWD+IFR2+MS+sag(5) 5,727.44 70.95 258.18 4,283.25 4,227.05 -308.63 -2,889.99 6,030,754.40 466,930.25 0.62 2,822.27 MWD+IFR2+MS+sag(5) 5,824.68 70.61 258.07 4,315.26 4,259.06 -327.53 -2,979.84 6,030,735.87 466,840.33 0.37 2,908.77 MWD+IFR2+MS+sag(5) 5,917.59 70.86 257.56 4,345.92 4,289.72 -346.04 -3,065.57 6,030,717.71 466,754.54 0.58 2,991.24 MWD+IFR2+MS+sag(5) 6,011.23 71.05 257.12 4,376.47 4,320.27 -365.44 -3,151.94 6,030,698.66 466,668.11 0.49 3,074.21 MWD+IFR2+MS+sag(5) 6,109.85 70.29 255.57 4,409.12 4,352.92 -387.41 -3,242.36 6,030,677.07 466,577.60 1.67 3,160.86 MWD+IFR2+MS+sag(5) 6,206.00 70.35 256.98 4,441.50 4,385.30 -408.89 -3,330.31 6,030,655.95 466,489.58 1.38 3,245.12 MWD+IFR2+MS+sag(5) 6,296.96 70.47 257.77 4,472.00 4,415.80 -427.62 -3,413.93 6,030,637.56 466,405.89 0.83 3,325.47 MWD+IFR2+MS+sag(5) 6,392.50 70.96 258.81 4,503.55 4,447.35 -445.92 -3,502.23 6,030,619.62 466,317.52 1.15 3,410.51 MWD+IFR2+MS+sag(5) 6,487.74 71.03 259.25 4,534.57 4,478.37 -463.05 -3,590.63 6,030,602.84 466,229.06 0.44 3,495.80 MWD+IFR2+MS+sag(5) 6,582.74 70.87 258.69 4,565.57 4,509.37 -480.23 -3,678.77 6,030,586.02 466,140.86 0.58 3,580.83 MWD+IFR2+MS+sag(5) 6,677.75 70.73 259.06 4,596.82 4,540.62 -497.54 -3,766.81 6,030,569.07 466,052.76 0.40 3,665.75 MWD+IFR2+MS+sag(5) 6,773.48 71.16 258.45 4,628.07 4,571.87 -515.19 -3,855.56 6,030,551.79 465,963.95 0.75 3,751.32 MWD+IFR2+MS+sag(5) 6,868.81 71.27 257.68 4,658.77 4,602.57 -533.85 -3,943.86 6,030,533.48 465,875.59 0.77 3,836.31 MWD+IFR2+MS+sag(5) 6,964.81 70.80 259.14 4,689.97 4,633.77 -552.10 -4,032.79 6,030,515.61 465,786.59 1.52 3,921.98 MWD+IFR2+MS+sag(5) 1/312011 9:31:53AM Page 4 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB4 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB4 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 7,058.66 71.73 258.75 4,720.12 4,663.92 -569.14 -4,120.02 6,030,498.92 465,699.30 1.07 4,006.12 MWD+IFR2+MS+sag(5) 7,155.94 70.48 258.65 4,751.62 4,695.42 -587.17 -4,210.27 6,030,481.25 465,608.99 1.29 4,093.13 MWD+IFR2+MS+sag(5) 7,249.11 70.27 258.33 4,782.91 4,726.71 -604.68 -4,296.26 6,030,464.09 465,522.93 0.39 4,175.99 MWD+IFR2+MS+sag(5) 7,345.08 71.16 258.01 4,814.61 4,758.41 -623.25 -4,384.92 6,030,445.88 465,434.21 0.98 4,261.35 MWD+IFR2+MS+sag(5) 7,441.17 70.89 257.84 4,845.85 4,789.65 -642.26 -4,473.78 6,030,427.24 465,345.28 0.33 4,346.85 MWD+IFR2+MS+sag(5) 7,536.09 69.56 258.34 4,877.96 4,821.76 -660.70 -4,561.18 6,030,409.16 465,257.82 1.49 4,430.97 MWD+IFR2+MS+sag(5) 7,626.41 69.56 260.20 4,909.51 4,853.31 -676.45 -4,644.33 6,030,393.74 465,174.61 1.93 4,511.25 MWD+IFR2+MS+sag(5) 7,726.42 69.36 260.00 4,944.60 4,888.40 -692.56 -4,736.58 6,030,378.02 465,082.30 0.27 4,600.51 MWD+IFR2+MS+sag(5) 7,820.69 69.02 260.88 4,978.09 4,921.89 -707.19 -4,823.48 6,030,363.74 464,995.36 0.94 4,684.64 MWD+IFR2+MS+sag(5) 7,915.20 69.21 260.17 5,011.78 4,955.58 -721.73 -4,910.57 6,030,349.56 464,908.21 0.73 4,769.00 MWD+IFR2+MS+sag(5) 8,011.00 69.69 260.57 5,045.41 4,989.21 -736.73 -4,999.01 6,030,334.91 464,819.72 0.64 4,854.62 MWD+IFR2+MS+sag(5) 8,106.40 69.26 260.81 5,078.86 5,022.66 -751.19 -5,087.18 6,030,320.82 464,731.51 0.51 4,940.04 MWD+IFR2+MS+sag(5) 8,201.28 69.17 260.04 5,112.53 5,056.33 -765.94 -5,174.65 6,030,306.42 464,643.99 0.76 5,024.73 MWD+IFR2+MS+sag(5) 8,296.82 69.86 258.87 5,145.97 5,089.77 -782.32 -5,262.63 6,030,290.40 464,555.95 1.36 5,109.71 MWD+IFR2+MS+sag(5) 8,392.12 69.57 258.47 5,179.00 5,122.80 -799.88 -5,350.28 6,030,273.19 464,468.24 0.50 5,194.21 MWD+IFR2+MS+sag(5) 8,438.00 69.60 258.48 5,195.01 5,138.81 -808.47 -5,392.41 6,030,264.77 464,426.07 0.07 5,234.80 MWD+IFR2+MS+sag(6) 8,529.05 72.36 255.25 5,224.69 5,168.49 -828.05 -5,476.21 6,030,245.54 464,342.20 4.52 5,315.21 MWD+IFR2+MS+sag(6) 8,575.56 73.36 254.40 5,238.39 5,182.19 -839.68 -5,519.11 6,030,234.08 464,299.27 2.77 5,356.15 MWD+IFR2+MS+sag(6) 8,670.27 74.48 252.70 5,264.63 5,208.43 -865.46 -5,606.38 6,030,208.67 464,211.90 2.09 5,439.17 MWD+IFR2+MS+sag(6) 8,718.63 74.39 251.47 5,277.60 5,221.40 -879.79 -5,650.71 6,030,194.52 464,167.52 2.46 5,481.16 MWD+IFR2+MS+sag(6) 8,785.71 74.04 252.09 5,295.85 5,239.65 -899.97 -5,712.02 6,030,174.59 464,106.13 1.03 5,539.21 MWD+IFR2+MS+sag(6) 8,881.94 73.38 251.52 5,322.84 5,266.64 -928.81 -5,799.77 6,030,146.10 464,018.28 0.89 5,622.28 MWD+IFR2+MS+sag(6) 8,977.86 73.11 252.53 5,350.50 5,294.30 -957.15 -5,887.13 6,030,118.12 463,930.81 1.05 5,705.04 MWD+IFR2+MS+sag(6) 9,072.22 72.75 254.47 5,378.20 5,322.00 -982.77 -5,973.61 6,030,092.85 463,844.23 2.00 5,787.30 MWD+IFR2+MS+sag(6) 9,168.00 72.53 256.55 5,406.78 5,350.58 -1,005.65 -6,062.12 6,030,070.34 463,755.64 2.09 5,871.92 MWD+IFR2+MS+sag(6) 9,262.77 72.47 260.99 5,435.29 5,379.09 -1,023.24 -6,150.74 6,030,053.11 463,666.95 4.47 5,957.38 MWD+IFR2+MS+sag(6) 9,357.47 72.46 264.53 5,463.83 5,407.63 -1,034.62 -6,240.31 6,030,042.09 463,577.35 3.56 6,044.60 MWD+IFR2+MS+sag(6) 9,452.53 71.85 267.34 5,492.97 5,436.77 -1,041.04 -6,330.55 6,030,036.04 463,487.09 2.89 6,133.17 MWD+IFR2+MS+sag(6) 9,547.64 72.27 271.43 5,522.27 5,466.07 -1,042.01 -6,421.01 6,030,035.44 463,396.64 4.11 6,222.67 MWD+IFR2+MS+sag(6) 9,642.41 72.06 275.01 5,551.31 5,495.11 -1,036.94 -6,511.07 6,030,040.87 463,306.61 3.60 6,312.59 MWD+IFR2+MS+sag(6) 9,737.67 71.99 278.14 5,580.71 5,524.51 -1,026.57 -6,601.07 6,030,051.61 463,216.66 3.13 6,403.17 MWD+IFR2+MS+sag(6) 9,833.18 71.37 281.53 5,610.74 5,554.54 -1,011.09 -6,690.39 6,030,067.45 463,127.42 3.43 6,493.76 MWD+IFR2+MS+sag(6) 9,929.57 71.41 286.08 5,641.51 5,585.31 -989.30 -6,779.07 6,030,089.60 463,038.83 4.47 6,584.57 MWD+IFR2+MS+sag(6) 10,024.64 71.38 289.64 5,671.85 5,615.65 -961.67 -6,864.82 6,030,117.57 462,953.21 3.55 6,673.25 MWD+IFR2+MS+sag(6) 10,118.68 72.08 292.42 5,701.34 5,645.14 -929.62 -6,948.16 6,030,149.95 462,870.01 2.90 6,760.14 MWD+IFR2+MS+sag(6) 10,214.27 72.08 296.36 5,730.76 5,674.56 -892.07 -7,030.97 6,030,187.83 462,787.35 3.92 6,847.25 MWD+IFR2+MS+sag(6) 10,309.31 71.94 299.25 5,760.12 5,703.92 -849.92 -7,110.92 6,030,230.31 462,707.59 2.90 6,932.14 MWD+IFR2+MS+sag(6) 10,404.13 72.22 300.94 5,789.30 5,733.10 -804.68 -7,188.97 6,030,275.86 462,629.73 1.72 7,015.57 MWD+IFR2+MS+sag(6) 10,498.75 73.56 303.93 5,817.14 5,760.94 -756.17 -7,265.28 6,030,324.67 462,553.62 3.34 7,097.70 MWD+IFR2+MS+sag(6) 10,593.70 74.26 308.42 5,843.47 5,787.27 -702.34 -7,338.90 6,030,378.80 462,480.23 4.60 7,177.89 MWD+IFR2+MS+sag(6) 1/31/2011 9:31:53AM Page 5 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB4 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB4 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 10,689.51 74.46 309.71 5,869.30 5,813.10 -644.19 -7,410.53 6,030,437.23 462,408.84 1.31 7,256.69 MWD+IFR2+MS+sag(6) 10,784.19 74.92 311.89 5,894.30 5,838.10 -584.53 -7,479.65 6,030,497.17 462,339.97 2.27 7,333.20 MWD+IFR2+MS+sag(6) 10,879.86 74.40 314.18 5,919.61 5,863.41 -521.57 -7,547.09 6,030,560.39 462,272.80 2.37 7,408.49 MWD+IFR2+MS+sag(6) 10,975.10 74.72 315.49 5,944.97 5,888.77 -456.84 -7,612.19 6,030,625.38 462,207.97 1.37 7,481.70 MWD+IFR2+MS+sag(6) 11,070.33 75.73 317.97 5,969.26 5,913.06 -389.80 -7,675.29 6,030,692.67 462,145.14 2.73 7,553.24 MWD+IFR2+MS+sag(6) 11,166.35 75.55 321.26 5,993.08 5,936.88 -318.96 -7,735.55 6,030,763.75 462,085.18 3.32 7,622.48 MWD+IFR2+MS+sag(6) 11,261.96 75.75 324.90 6,016.78 5,960.58 -244.92 -7,791.18 6,030,838.01 462,029.85 3.69 7,687.55 MWD+IFR2+MS+sag(6) 11,357.50 76.88 328.38 6,039.39 5,983.19 -167.40 -7,842.21 6,030,915.73 461,979.14 3.73 7,748.54 MWD+IFR2+MS+sag(6) 11,451.93 77.90 332.01 6,060.02 6,003.82 -87.45 -7,888.00 6,030,995.85 461,933.68 3.90 7,804.66 MWD+IFR2+MS+sag(6) 11,547.13 79.28 336.17 6,078.86 6,022.66 -3.53 -7,928.76 6,031,079.93 461,893.27 4.52 7,856.33 MWD+IFR2+MS+sag(6) 11,642.52 79.79 339.06 6,096.19 6,039.99 83.20 -7,964.48 6,031,166.79 461,857.91 3.03 7,903.38 MWD+IFR2+MS+sag(6) 11,736.96 79.85 338.89 6,112.88 6,056.68 169.96 -7,997.83 6,031,253.68 461,824.91 0.19 7,948.09 MWD+IFR2+MS+sag(6) 11,831.99 79.89 339.14 6,129.59 6,073.39 257.31 -8,031.33 6,031,341.15 461,791.77 0.26 7,993.03 MWD+IFR2+MS+sag(6) 11,927.00 79.58 341.03 6,146.52 6,090.32 345.20 -8,063.17 6,031,429.17 461,760.29 1.98 8,036.40 MWD+IFR2+MS+sag(6) 12,022.53 80.09 342.27 6,163.38 6,107.18 434.45 -8,092.78 6,031,518.52 461,731.05 1.38 8,077.73 MWD+IFR2+MS+sag(6) 12,067.94 80.08 343.26 6,171.20 6,115.00 477.17 -8,106.03 6,031,561.30 461,717.97 2.15 8,096.60 MWD+IFR2+MS+sag(6) 12,090.00 80.21 343.64 6,174.98 6,118.78 498.01 -8,112.22 6,031,582.15 461,711.87 1.81 8,105.54 MWD+IFR2+MS+sag(6) 12,122.46 80.82 341.19 6,180.33 6,124.13 528.52 -8,121.89 6,031,612.71 461,702.32 7.68 8,119.23 MWD+IFR2+MS+sag(7) 12,148.55 81.79 338.20 6,184.27 6,128.07 552.71 -8,130.84 6,031,636.92 461,693.47 11.92 8,131.34 MWD+IFR2+MS+sag(7) 12,196.49 83.40 336.52 6,190.45 6,134.25 596.58 -8,149.14 6,031,680.87 461,675.35 4.83 8,155.38 MWD+IFR2+MS+sag(7) 12,245.45 84.40 336.18 6,195.65 6,139.45 641.17 -8,168.67 6,031,725.53 461,656.00 2.16 8,180.72 MWD+IFR2+MS+sag(7) 12,289.71 84.07 336.40 6,200.10 6,143.90 681.49 -8,186.38 6,031,765.92 461,638.46 0.89 8,203.69 MWD+IFR2+MS+sag(7) 12,386.42 84.01 338.03 6,210.14 6,153.94 770.17 -8,223.63 6,031,854.74 461,601.58 1.68 8,252.52 MWD+IFR2+MS+sag(7) 12,483.58 83.89 342.52 6,220.39 6,164.19 861.10 -8,256.23 6,031,945.79 461,569.35 4.60 8,297.05 MWD+IFR2+MS+sag(7) 12,532.01 87.52 342.90 6,224.01 6,167.81 907.20 -8,270.58 6,031,991.95 461,555.19 7.54 8,317.46 MWD+IFR2+MS+sag(7) 12,579.25 88.92 342.40 6,225.48 6,169.28 952.27 -8,284.66 6,032,037.07 461,541.29 3.15 8,337.47 MWD+IFR2+MS+sag(7) 12,676.17 91.88 340.53 6,224.80 6,168.60 1,044.15 -8,315.46 6,032,129.06 461,510.86 3.61 8,380.35 MWD+IFR2+MS+sag(7) 12,771.79 93.54 338.11 6,220.28 6,164.08 1,133.49 -8,349.19 6,032,218.53 461,477.50 3.07 8,425.78 MWD+IFR2+MS+sag(7) 12,850.00 93.34 336.38 6,215.59 6,159.39 1,205.48 -8,379.38 6,032,290.64 461,447.60 2.22 8,465.38 MWD+IFR2+MS+sag(8) 12,867.91 92.47 337.25 6,214.68 6,158.48 1,221.93 -8,386.43 6,032,307.11 461,440.63 6.87 8,474.56 MWD+IFR2+MS+sag(8) 12,965.10 91.18 329.71 6,211.58 6,155.38 1,308.78 -8,429.77 6,032,394.13 461,397.64 7.87 8,529.19 MWD+IFR2+MS+sag(8) 13,061.01 90.94 326.12 6,209.81 6,153.61 1,390.01 -8,480.70 6,032,475.56 461,347.05 3.75 8,590.57 MWD+IFR2+MS+sag(8) 13,156.84 91.87 325.44 6,207.46 6,151.26 1,469.23 -8,534.57 6,032,554.98 461,293.50 1.20 8,654.61 MWD+IFR2+MS+sag(8) 13,253.35 89.57 323.76 6,206.24 6,150.04 1,547.88 -8,590.47 6,032,633.86 461,237.93 2.95 8,720.57 MWD+IFR2+MS+sag(8) 13,350.54 90.76 320.72 6,205.96 6,149.76 1,624.71 -8,649.98 6,032,710.92 461,178.74 3.36 8,789.86 MWD+IFR2+MS+sag(8) 13,446.19 94.36 320.50 6,201.69 6,145.49 1,698.55 -8,710.60 6,032,784.99 461,118.42 3.77 8,859.87 MWD+IFR2+MS+sag(8) 13,544.30 96.90 320.37 6,192.07 6,135.87 1,773.81 -8,772.79 6,032,860.50 461,056.55 2.59 8,931.60 MWD+IFR2+MS+sag(8) 13,639.07 97.39 320.51 6,180.28 6,124.08 1,846.30 -8,832.68 6,032,933.23 460,996.96 0.54 9,000.69 MWD+IFR2+MS+sag(8) 13,736.40 97.94 321.09 6,167.30 6,111.10 1,921.05 -8,893.64 6,033,008.22 460,936.31 0.82 9,071.15 MWD+IFR2+MS+sag(8) 1/312011 9:31:53AM Page 6 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)©56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)©56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB5 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB5 Database: .Pioneer 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 I Well ODSN-18-Slot ODS-18 ` Well Position +N/-S 0.00 ft Northing: 6,031,051.27 ft Latitude: 70°29'45.254 N +E/-W 0.00 ft Easting: 469,821.18 ft Longitude: 150°14'48.375 W 'Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft Wellbore ODSN-18 PB5 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-18 PN11 PB5 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 13,350.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 290.79 Survey Program Date 1/27/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 141.00 981.00 ODSN-18 PB1 Gyro 1 (ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 10/25/2010 1,027.53 1,027.53 ODSN-18 PB1 MWD 1 (ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/2/2010 t 1,123.00 1,123.00 ODSN-18 PB1 Gyro 2(ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 11/2/2010 1: 1,174.40 3,566.42 ODSN-18 PB1 MWD 2(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/26/2010 3,630.15 8,392.10 ODSN-18 PB1 MWD 3(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/1/2010 1: 8,438.00 12,090.00 ODSN-18 PB2 MWD 4(ODSN-18 PB2) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/5/2010 1: 12,122.46 12,771.79 ODSN-18 PB3 MWD 5(ODSN-18 PB3) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/22/2010 12,850.00 13,350.00 ODSN-18 PB4 MWD 6(ODSN-18 PB4) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/30/2010 13,375.00 14,796.87 ODSN-18 PB5 MWD 7(ODSN-18 PB5)MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 1/1/2011 12: 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 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,051.27 469,821.18 0.00 0.00 UNDEFINED 141.00 0.26 304.00 141.00 84.80 0.13 -0.19 6,031,051.40 469,820.99 0.26 0.22 SR-Gyro-SS(1) 199.00 0.27 348.71 199.00 142.80 0.33 -0.32 6,031,051.60 469,820.86 0.35 0.42 SR-Gyro-SS(1) 232.00 0.49 322.56 232.00 175.80 0.52 -0.42 6,031,051.79 469,820.76 0.83 0.58 SR-Gyro-SS(1) 290.00 0.48 322.52 290.00 233.80 0.91 -0.72 6,031,052.18 469,820.46 0.02 1.00 SR-Gyro-SS(1) 323.00 0.93 308.43 322.99 266.79 1.19 -1.02 6,031,052.46 469,820.17 1.45 1.37 SR-Gyro-SS(1) 382.00 1.25 295.72 381.98 325.78 1.76 -1.97 6,031,053.04 469,819.22 0.68 2.47 SR-Gyro-SS(1) 1/31t2011 9:29:49AM Page 2 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB5 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB5 Database: .Pioneer 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) (°I100') (ft) Survey Tool Name 415.00 1.90 288.47 414.97 358.77 2.09 -2.81 6,031,053.38 469,818.38 2.06 3.37 SR-Gyro-SS(1) 472.00 2.17 284.07 471.93 415.73 2.66 -4.76 6,031,053.94 469,816.43 0.55 5.39 SR-Gyro-SS(1) 505.00 2.74 284.05 504.90 448.70 3.00 -6.13 6,031,054.29 469,815.06 1.73 6.79 SR-Gyro-SS(1) 568.00 3.14 281.82 567.82 511.62 3.72 -9.28 6,031,055.03 469,811.92 0.66 9.99 SR-Gyro-SS(1) 601.00 3.54 281.44 600.76 544.56 4.11 -11.16 6,031,055.42 469,810.04 1.21 11.89 SR-Gyro-SS(1) 662.00 3.66 281.14 661.64 605.44 4.86 -14.92 6,031,056.19 469,806.28 0.20 15.67 SR-Gyro-SS(1) 685.00 3.95 280.22 684.59 628.39 5.14 -16.42 6,031,056.47 469,804.79 1.29 17.17 SR-Gyro-SS(1) 758.00 4.41 281.46 757.40 701.20 6.14 -21.64 6,031,057.50 469,799.57 0.64 22.41 SR-Gyro-SS(1) 791.00 4.78 281.29 790.29 734.09 6.66 -24.23 6,031,058.03 469,796.98 1.12 25.02 SR-Gyro-SS(1) 853.00 5.29 282.35 852.05 795.85 7.78 -29.56 6,031,059.17 469,791.66 0.84 30.39 SR-Gyro-SS(1) 886.00 5.85 279.85 884.90 828.70 8.39 -32.70 6,031,059.79 469,788.52 1.85 33.55 SR-Gyro-SS(1) 948.00 6.88 279.90 946.51 890.31 9.57 -39.47 6,031,061.00 469,781.75 1.66 40.30 SR-Gyro-SS(1) 981.00 6.89 278.10 979.28 923.08 10.19 -43.38 6,031,061.64 469,777.85 0.65 44.17 SR-Gyro-SS(1) 1,027.53 6.83 276.30 1,025.47 969.27 10.89 -48.89 6,031,062.35 469,772.34 0.48 49.57 MWD+IFR2+MS+sag(2) 1,123.00 9.55 277.06 1,119.96 1,063.76 12.48 -62.40 6,031,064.01 469,758.84 2.85 62.76 SR-Gyro-SS(3) 1,174.43 9.71 277.20 1,170.67 1,114.47 13.55 -70.93 6,031,065.11 469,750.31 0.31 71.12 MWD+IFR2+MS+sag(4) 1,218.54 9.91 278.29 1,214.13 1,157.93 14.57 -78.38 6,031,066.15 469,742.87 0.62 78.45 MWD+IFR2+MS+sag(4) 1,314.10 9.75 271.65 1,308.29 1,252.09 15.98 -94.61 6,031,067.64 469,726.65 1.20 94.12 MWD+IFR2+MS+sag(4) 1,409.32 10.15 272.52 1,402.08 1,345.88 16.59 -111.05 6,031,068.30 469,710.21 0.45 109.70 MWD+IFR2+MS+sag(4) 1,504.37 10.95 274.95 1,495.52 1,439.32 17.73 -128.41 6,031,069.52 469,692.86 0.96 126.34 MWD+IFR2+MS+sag(4) 1,599.91 12.48 272.29 1,589.07 1,532.87 18.93 -147.77 6,031,070.80 469,673.51 1.70 144.86 MWD+IFR2+MS+sag(4) 1,631.69 12.76 273.11 1,620.08 1,563.88 19.26 -154.70 6,031,071.15 469,666.57 1.05 151.46 MWD+IFR2+MS+sag(4) 1,725.28 14.37 274.13 1,711.06 1,654.86 20.65 -176.61 6,031,072.64 469,644.68 1.74 172.44 MWD+IFR2+MS+sag(4) 1,821.10 13.44 273.34 1,804.07 1,747.87 22.16 -199.58 6,031,074.24 469,621.71 0.99 194.45 MWD+IFR2+MS+sag(4) 1,915.58 15.28 274.70 1,895.59 1,839.39 23.82 -222.95 6,031,075.99 469,598.35 1.98 216.89 MWD+IFR2+MS+sag(4) 2,011.74 15.85 275.48 1,988.23 1,932.03 26.11 -248.65 6,031,078.39 469,572.66 0.63 241.73 MWD+IFR2+MS+sag(4) 2,107.39 14.66 274.53 2,080.51 2,024.31 28.31 -273.72 6,031,080.69 469,547.60 1.27 265.95 MWD+IFR2+MS+sag(4) 2,202.94 13.62 277.80 2,173.16 2,116.96 30.80 -296.92 6,031,083.27 469,524.41 1.37 288.52 MWD+IFR2+MS+sag(4) 2,241.41 13.96 276.43 2,210.52 2,154.32 31.93 -306.02 6,031,084.44 469,515.32 1.23 297.43 MWD+IFR2+MS+sag(4) 2,298.61 14.97 276.21 2,265.91 2,209.71 33.50 -320.22 6,031,086.07 469,501.13 1.77 311.26 MWD+IFR2+MS+sag(4) 2,333.40 15.89 274.27 2,299.44 2,243.24 34.34 -329.44 6,031,086.95 469,491.92 3.03 320.18 MWD+IFR2+MS+sag(4) 2,393.28 16.92 271.13 2,356.89 2,300.69 35.12 -346.33 6,031,087.80 469,475.03 2.27 336.24 MWD+IFR2+MS+sag(4) 2,488.03 20.47 266.74 2,446.63 2,390.43 34.45 -376.67 6,031,087.25 469,444.70 4.03 364.37 MWD+IFR2+MS+sag(4) 2,583.22 24.38 267.73 2,534.60 2,478.40 32.73 -412.93 6,031,085.67 469,408.43 4.13 397.66 MWD+IFR2+MS+sag(4) 2,678.36 29.60 267.12 2,619.35 2,563.15 30.77 -456.05 6,031,083.89 469,365.31 5.49 437.27 MWD+IFR2+MS+sag(4) 2,773.39 32.86 268.44 2,700.60 2,644.40 28.89 -505.27 6,031,082.21 469,316.08 3.51 482.62 MWD+IFR2+MS+sag(4) 2,868.92 36.48 268.01 2,779.16 2,722.96 27.20 -559.58 6,031,080.73 469,261.77 3.80 532.79 MWD+IFR2+MS+sag(4) 2,963.62 38.66 267.56 2,854.21 2,798.01 24.96 -617.27 6,031,078.73 469,204.08 2.32 585.94 MWD+IFR2+MS+sag(4) 3,059.68 38.65 266.41 2,929.23 2,873.03 21.80 -677.19 6,031,075.82 469,144.15 0.75 640.83 MWD+IFR2+MS+sag(4) 3,155.09 41.44 265.51 3,002.26 2,946.06 17.46 -738.41 6,031,071.73 469,082.92 2.99 696.53 MWD+IFR2+MS+sag(4) 1/31/2011 9:29:49AM Page 3 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development ND Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB5 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB5 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 3,249.55 42.15 264.91 3,072.68 3,016.48 12.20 -801.15 6,031,066.73 469,020.17 0.86 753.31 MWD+IFR2+MS+sag(4) 3,344.92 46.28 265.36 3,141.02 3,084.82 6.58 -867.40 6,031,061.37 468,953.90 4.34 813.25 MWD+IFR2+MS+sag(4) 3,439.63 48.20 265.43 3,205.32 3,149.12 0.99 -936.71 6,031,056.07 468,884.58 2.03 876.07 MWD+IFR2+MS+sag(4) 3,534.85 49.89 264.83 3,267.73 3,211.53 -5.12 -1,008.36 6,031,050.25 468,812.91 1.84 940.88 MWD+IFR2+MS+sag(4) 3,566.42 50.37 265.46 3,287.97 3,231.77 -7.17 -1,032.50 6,031,048.30 468,788.76 2.16 962.73 MWD+IFR2+MS+sag(4) 3,630.15 49.94 264.80 3,328.80 3,272.60 -11.32 -1,081.25 6,031,044.34 468,740.00 1.04 1,006.83 MWD+IFR2+MS+sag(5) 3,728.64 48.98 264.86 3,392.82 3,336.62 -18.06 -1,155.80 6,031,037.90 468,665.44 0.98 1,074.13 MWD+IFR2+MS+sag(5) 3,823.03 48.55 265.70 3,455.04 3,398.84 -23.91 -1,226.54 6,031,032.35 468,594.68 0.81 1,138.19 MWD+IFR2+MS+sag(5) 3,918.36 47.71 266.13 3,518.66 3,462.46 -28.97 -1,297.34 6,031,027.57 468,523.86 0.94 1,202.59 MWD+IFR2+MS+sag(5) 4,013.58 47.75 266.18 3,582.71 3,526.51 -33.69 -1,367.65 6,031,023.14 468,453.55 0.06 1,266.64 MWD+IFR2+MS+sag(5) 4,108.84 51.32 267.02 3,644.52 3,588.32 -37.97 -1,439.98 6,031,019.15 468,381.20 3.81 1,332.74 MWD+IFR2+MS+sag(5) 4,203.49 54.06 266.88 3,701.89 3,645.69 -41.98 -1,515.15 6,031,015.45 468,306.03 2.90 1,401.59 MWD+IFR2+MS+sag(5) 4,300.86 56.97 265.70 3,757.01 3,700.81 -47.19 -1,595.23 6,031,010.56 468,225.93 3.15 1,474.61 MWD+IFR2+MS+sag(5) 4,398.80 58.70 262.86 3,809.16 3,752.96 -55.47 -1,677.71 6,031,002.62 468,143.43 3.02 1,548.78 MWD+IFR2+MS+sag(5) 4,493.85 61.31 259.87 3,856.68 3,800.48 -67.85 -1,759.07 6,030,990.57 468,062.03 3.87 1,620.44 MWD+IFR2+MS+sag(5) 4,584.47 65.00 259.37 3,897.60 3,841.40 -82.42 -1,838.58 6,030,976.32 467,982.46 4.10 1,689.61 MWD+IFR2+MS+sag(5) 4,684.58 67.49 257.58 3,937.92 3,881.72 -100.74 -1,928.35 6,030,958.37 467,892.63 2.98 1,767.03 MWD+IFR2+MS+sag(5) 4,779.26 68.84 257.43 3,973.14 3,916.94 -119.76 -2,014.15 6,030,939.70 467,806.76 1.43 1,840.50 MWD+IFR2+MS+sag(5) 4,871.89 70.51 256.93 4,005.31 3,949.11 -139.03 -2,098.85 6,030,920.77 467,722.00 1.87 1,912.84 MWD+IFR2+MS+sag(5) 4,965.11 71.34 257.43 4,035.78 3,979.58 -158.58 -2,184.75 6,030,901.58 467,636.02 1.02 1,986.21 MWD+IFR2+MS+sag(5) 5,063.57 71.46 258.28 4,067.18 4,010.98 -178.21 -2,275.98 6,030,882.32 467,544.73 0.83 2,064.53 MWD+IFR2+MS+sag(5) 5,159.38 71.34 258.20 4,097.74 4,041.54 -196.72 -2,364.88 6,030,864.17 467,455.76 0.15 2,141.07 MWD+IFR2+MS+sag(5) 5,254.53 71.20 258.00 4,128.29 4,072.09 -215.30 -2,453.05 6,030,845.95 467,367.52 0.25 2,216.91 MWD+IFR2+MS+sag(5) 5,345.36 70.63 257.39 4,157.99 4,101.79 -233.59 -2,536.92 6,030,828.00 467,283.59 0.89 2,288.82 MWD+IFR2+MS+sag(5) 5,441.12 71.23 257.83 4,189.28 4,133.08 -253.01 -2,625.31 6,030,808.94 467,195.13 0.76 2,364.57 MWD+IFR2+MS+sag(5) 5,536.74 71.07 258.19 4,220.17 4,163.97 -271.81 -2,713.83 6,030,790.51 467,106.54 0.39 2,440.65 MWD+IFR2+MS+sag(5) 5,631.50 70.36 258.20 4,251.47 4,195.27 -290.11 -2,801.38 6,030,772.57 467,018.93 0.75 2,516.00 MWD+IFR2+MS+sag(5) 5,727.44 70.95 258.18 4,283.25 4,227.05 -308.63 -2,889.99 6,030,754.40 466,930.25 0.62 2,592.26 MWD+IFR2+MS+sag(5) 5,824.68 70.61 258.07 4,315.26 4,259.06 -327.53 -2,979.84 6,030,735.87 466,840.33 0.37 2,669.56 MWD+IFR2+MS+sag(5) 5,917.59 70.86 257.56 4,345.92 4,289.72 -346.04 -3,065.57 6,030,717.71 466,754.54 0.58 2,743.14 MWD+IFR2+MS+sag(5) 6,011.23 71.05 257.12 4,376.47 4,320.27 -365.44 -3,151.94 6,030,698.66 466,668.11 0.49 2,816.99 MWD+IFR2+MS+sag(5) 6,109.85 70.29 255.57 4,409.12 4,352.92 -387.41 -3,242.36 6,030,677.07 466,577.60 1.67 2,893.74 MWD+IFR2+MS+sag(5) 6,206.00 70.35 256.98 4,441.50 4,385.30 -408.89 -3,330.31 6,030,655.95 466,489.58 1.38 2,968.33 MWD+IFR2+MS+sag(5) 6,296.96 70.47 257.77 4,472.00 4,415.80 -427.62 -3,413.93 6,030,637.56 466,405.89 0.83 3,039.86 MWD+IFR2+MS+sag(5) 6,392.50 70.96 258.81 4,503.55 4,447.35 -445.92 -3,502.23 6,030,619.62 466,317.52 1.15 3,115.92 MWD+IFR2+MS+sag(5) 6,487.74 71.03 259.25 4,534.57 4,478.37 -463.05 -3,590.63 6,030,602.84 466,229.06 0.44 3,192.48 MWD+IFR2+MS+sag(5) 6,582.74 70.87 258.69 4,565.57 4,509.37 -480.23 -3,678.77 6,030,586.02 466,140.86 0.58 3,268.78 MWD+IFR2+MS+sag(5) 6,677.75 70.73 259.06 4,596.82 4,540.62 -497.54 -3,766.81 6,030,569.07 466,052.76 0.40 3,344.94 MWD+IFR2+MS+sag(5) 6,773.48 71.16 258.45 4,628.07 4,571.87 -515.19 -3,855.56 6,030,551.79 465,963.95 0.75 3,421.65 MWD+IFR2+MS+sag(5) 6,868.81 71.27 257.68 4,658.77 4,602.57 -533.85 -3,943.86 6,030,533.48 465,875.59 0.77 3,497.57 MWD+IFR2+MS+sag(5) 1/312011 9:29:49AM Page 4 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB5 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB5 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 6,964.81 70.80 259.14 4,689.97 4,633.77 -552.10 -4,032.79 6,030,515.61 465,786.59 1.52 3,574.24 MWD+IFR2+MS+sag(5) 7,058.66 71.73 258.75 4,720.12 4,663.92 -569.14 -4,120.02 6,030,498.92 465,699.30 1.07 3,649.74 MWD+IFR2+MS+sag(5) 7,155.94 70.48 258.65 4,751.62 4,695.42 -587.17 -4,210.27 6,030,481.25 465,608.99 1.29 3,727.72 MWD+IFR2+MS+sag(5) 7,249.11 70.27 258.33 4,782.91 4,726.71 -604.68 -4,296.26 6,030,464.09 465,522.93 0.39 3,801.89 MWD+IFR2+MS+sag(5) 7,345.08 71.16 258.01 4,814.61 4,758.41 -623.25 -4,384.92 6,030,445.88 465,434.21 0.98 3,878.19 MWD+IFR2+MS+sag(5) 7,441.17 70.89 257.84 4,845.85 4,789.65 -642.26 -4,473.78 6,030,427.24 465,345.28 0.33 3,954.51 MWD+IFR2+MS+sag(5) 7,536.09 69.56 258.34 4,877.96 4,821.76 -660.70 -4,561.18 6,030,409.16 465,257.82 1.49 4,029.68 MWD+IFR2+MS+sag(5) 7,626,41 69.56 260.20 4,909.51 4,853.31 -676.45 -4,644.33 6,030,393.74 465,174.61 1.93 4,101.82 MWD+IFR2+MS+sag(5) 7,726.42 69.36 260.00 4,944.60 4,888.40 -692.56 -4,736.58 6,030,378.02 465,082.30 0.27 4,182.35 MWD+IFR2+MS+sag(5) 7,820.69 69.02 260.88 4,978.09 4,921.89 -707.19 -4,823.48 6,030,363.74 464,995.36 0.94 4,258.40 MWD+IFR2+MS+sag(5) 7,915.20 69.21 260.17 5,011.78 4,955.58 -721.73 -4,910.57 6,030,349.56 464,908.21 0.73 4,334.66 MWD+IFR2+MS+sag(5) 8,011.00 69.69 260.57 5,045.41 4,989.21 -736.73 -4,999.01 6,030,334.91 464,819.72 0.64 4,412.02 MWD+IFR2+MS+sag(5) 8,106.40 69.26 260.81 5,078.86 5,022.66 -751.19 -5,087.18 6,030,320.82 464,731.51 0.51 4,489.31 MWD+IFR2+MS+sag(5) 8,201.28 69.17 260.04 5,112.53 5,056.33 -765.94 -5,174.65 6,030,306.42 464,643.99 0.76 4,565.85 MWD+IFR2+MS+sag(5) 8,296.82 69.86 258.87 5,145.97 5,089.77 -782.32 -5,262.63 6,030,290.40 464,555.95 1.36 4,642.29 MWD+IFR2+MS+sag(5) 8,392.12 69.57 258.47 5,179.00 5,122.80 -799.88 -5,350.28 6,030,273.19 464,468.24 0.50 4,718.00 MWD+IFR2+MS+sag(5) 8,438.00 69.60 258.48 5,195.01 5,138.81 -808.47 -5,392.41 6,030,264.77 464,426.07 0.07 4,754.33 MWD+IFR2+MS+sag(6) 8,529.05 72.36 255.25 5,224.69 5,168.49 -828.05 -5,476.21 6,030,245.54 464,342.20 4.52 4,825.73 MWD+IFR2+MS+sag(6) 8,575.56 73.36 254.40 5,238.39 5,182.19 -839.68 -5,519.11 6,030,234.08 464,299.27 2.77 4,861.70 MWD+IFR2+MS+sag(6) 8,670.27 74.48 252.70 5,264.63 5,208.43 -865.46 -5,606.38 6,030,208.67 464,211.90 2.09 4,934.14 MWD+IFR2+MS+sag(6) 8,718.63 74.39 251.47 5,277.60 5,221.40 -879.79 -5,650.71 6,030,194.52 464,167.52 2.46 4,970.50 MWD+IFR2+MS+sag(6) 8,785.71 74.04 252.09 5,295.85 5,239.65 -899.97 -5,712.02 6,030,174.59 464,106.13 1.03 5,020.66 MWD+IFR2+MS+sag(6) 8,881.94 73.38 251.52 5,322.84 5,266.64 -928.81 -5,799.77 6,030,146.10 464,018.28 0.89 5,092.45 MWD+IFR2+MS+sag(6) 8,977.86 73.11 252.53 5,350.50 5,294.30 -957.15 -5,887.13 6,030,118.12 463,930.81 1.05 5,164.07 MW0+1FR2+MS+sag(6) 9,072.22 72.75 254.47 5,378.20 5,322.00 -982.77 -5,973.61 6,030,092.85 463,844.23 2.00 5,235.83 MWD+IFR2+MS+sag(6) 9,168.00 72.53 256.55 5,406.78 5,350.58 -1,005.65 -6,062.12 6,030,070.34 463,755.64 2.09 5,310.45 MWD+IFR2+MS+sag(6) 9,262.77 72.47 260.99 5,435.29 5,379.09 -1,023.24 -6,150.74 6,030,053.11 463,666.95 4.47 5,387.06 MWD+IFR2+MS+sag(6) 9,357.47 72.46 264.53 5,463.83 5,407.63 -1,034.62 -6,240.31 6,030,042.09 463,577.35 3.56 5,466.75 MWD+IFR2+MS+sag(6) 9,452.53 71.85 267.34 5,492.97 5,436.77 -1,041.04 -6,330.55 6,030,036.04 463,487.09 2.89 5,548.84 MWD+IFR2+MS+sag(6) 9,547.64 72.27 271.43 5,522.27 5,466.07 -1,042.01 -6,421.01 6,030,035.44 463,396.64 4.11 5,633.07 MWD+IFR2+MS+sag(6) 9,642.41 72.06 275.01 5,551.31 5,495.11 -1,036.94 -6,511.07 6,030,040.87 463,306.61 3.60 5,719.06 MWD+IFR2+MS+sag(6) 9,737.67 71.99 278.14 5,580.71 5,524.51 -1,026.57 -6,601.07 6,030,051.61 463,216.66 3.13 5,806.88 MWD+IFR2+MS+sag(6) 9,833.18 71.37 281.53 5,610.74 5,554.54 -1,011.09 -6,690.39 6,030,067.45 463,127.42 3.43 5,895.88 MWD+IFR2+MS+sag(6) 9,929.57 71.41 286.08 5,641.51 5,585.31 -989.30 -6,779.07 6,030,089.60 463,038.83 4.47 5,986.53 MWD+IFR2+MS+sag(6) 10,024.64 71.38 289.64 5,671.85 5,615.65 -961.67 -6,864.82 6,030,117.57 462,953.21 3.55 6,076.49 MWD+IFR2+MS+sag(6) 10,118.68 72.08 292.42 5,701.34 5,645.14 -929.62 -6,948.16 6,030,149.95 462,870.01 2.90 6,165.78 MWD+IFR2+MS+sag(6) 10,214.27 72.08 296.36 5,730.76 5,674.56 -892.07 -7,030.97 6,030,187.83 462,787.35 3.92 6,256.53 MWD+IFR2+MS+sag(6) 10,309.31 71.94 299.25 5,760.12 5,703.92 -849.92 -7,110.92 6,030,230.31 462,707.59 2.90 6,346.24 MWD+IFR2+MS+sag(6) 10,404.13 72.22 300.94 5,789.30 5,733.10 -804.68 -7,188.97 6,030,275.86 462,629.73 1.72 6,435.27 MWD+IFR2+MS+sag(6) 10,498.75 73.56 303.93 5,817.14 5,760.94 -756.17 -7,265.28 6,030,324.67 462,553.62 3.34 6,523.82 MWD+IFR2+MS+sag(6) 1/3112011 9:29:49AM Page 5 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB5 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB5 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,593.70 74.26 308.42 5,843.47 5,787.27 -702.34 -7,338.90 6,030,378.80 462,480.23 4.60 6,611.75 MWD+IFR2+MS+sag(6) 10,689.51 74.46 309.71 5,869.30 5,813.10 -644.19 -7,410.53 6,030,437.23 462,408.84 1.31 6,699.36 MWD+IFR2+MS+sag(6) 10,784.19 74.92 311.89 5,894.30 5,838.10 -584.53 -7,479.65 6,030,497.17 462,339.97 2.27 6,785.16 MWD+IFR2+MS+sag(6) 10,879.86 74.40 314.18 5,919.61 5,863.41 -521.57 -7,547.09 6,030,560.39 462,272.80 2.37 6,870.55 MWD+IFR2+MS+sag(6) 10,975.10 74.72 315.49 5,944.97 5,888.77 -456.84 -7,612.19 6,030,625.38 462,207.97 1.37 6,954.38 MWD+IFR2+MS+sag(6) 11,070.33 75.73 317.97 5,969.26 5,913.06 -389.80 -7,675.29 6,030,692.67 462,145.14 2.73 7,037.18 MWD+IFR2+MS+sag(6) 11,166.35 75.55 321.26 5,993.08 5,936.88 -318.96 -7,735.55 6,030,763.75 462,085.18 3.32 7,118.66 MWD+IFR2+MS+sag(6) 11,261.96 75.75 324.90 6,016.78 5,960.58 -244.92 -7,791.18 6,030,838.01 462,029.85 3.69 7,196.95 MWD+IFR2+MS+sag(6) 11,357.50 76.88 328.38 6,039.39 5,983.19 -167.40 -7,842.21 6,030,915.73 461,979.14 3.73 7,272.17 MWD+IFR2+MS+sag(6) 11,451.93 77.90 332.01 6,060.02 6,003.82 -87.45 -7,888.00 6,030,995.85 461,933.68 3.90 7,343.36 MWD+IFR2+MS+sag(6) 11,547.13 79.28 336.17 6,078.86 6,022.66 -3.53 -7,928.76 6,031,079.93 461,893.27 4.52 7,411.25 MWD+IFR2+MS+sag(6) 11,642.52 79.79 339.06 6,096.19 6,039.99 83.20 -7,964.48 6,031,166.79 461,857.91 3.03 7,475.42 MWD+IFR2+MS+sag(6) 11,736.96 79.85 338.89 6,112.88 6,056.68 169.96 -7,997.83 6,031,253.68 461,824.91 0.19 7,537.40 MWD+IFR2+MS+sag(6) 11,831.99 79.89 339.14 6,129.59 6,073.39 257.31 -8,031.33 6,031,341.15 461,791.77 0.26 7,599.72 MWD+IFR2+MS+sag(6) 11,927.00 79.58 341.03 6,146.52 6,090.32 345.20 -8,063.17 6,031,429.17 461,760.29 1.98 7,660.69 MWD+IFR2+MS+sag(6) 12,022.53 80.09 342.27 6,163.38 6,107.18 434.45 -8,092.78 6,031,518.52 461,731.05 1.38 7,720.04 MWD+IFR2+MS+sag(6) 12,067.94 80.08 343.26 6,171.20 6,115.00 477.17 -8,106.03 6,031,561.30 461,717.97 2.15 7,747.59 MWD+IFR2+MS+sag(6) 12,090.00 80.21 343.64 6,174.98 6,118.78 498.01 -8,112.22 6,031,582.15 461,711.87 1.81 7,760.78 MWD+IFR2+MS+sag(6) 12,122.46 80.82 341.19 6,180.33 6,124.13 528.52 -8,121.89 6,031,612.71 461,702.32 7.68 7,780.65 MWD+IFR2+MS+sag(7) 12,148.55 81.79 338.20 6,184.27 6,128.07 552.71 -8,130.84 6,031,636.92 461,693.47 11.92 7,797.60 MWD+IFR2+MS+sag(7) 12,196.49 83.40 336.52 6,190.45 6,134.25 596.58 -8,149.14 6,031,680.87 461,675.35 4.83 7,830.28 MWD+IFR2+MS+sag(7) 12,245.45 84.40 336.18 6,195.65 6,139.45 641.17 -8,168.67 6,031,725.53 461,656.00 2.16 7,864.37 MWD+IFR2+MS+sag(7) 12,289.71 84.07 336.40 6,200.10 6,143.90 681.49 -8,186.38 6,031,765.92 461,638.46 0.89 7,895.23 MWD+IFR2+MS+sag(7) 12,386.42 84.01 338.03 6,210.14 6,153.94 770.17 -8,223.63 6,031,854.74 461,601.58 1.68 7,961.53 MWD+IFR2+MS+sag(7) 12,483.58 83.89 342.52 6,220.39 6,164.19 861.10 -8,256.23 6,031,945.79 461,569.35 4.60 8,024.29 MWD+IFR2+MS+sag(7) 12,532.01 87.52 342.90 6,224.01 6,167.81 907.20 -8,270.58 6,031,991.95 461,555.19 7.54 8,054.07 MWD+IFR2+MS+sag(7) 12,579.25 88.92 342.40 6,225.48 6,169.28 952.27 -8,284.66 6,032,037.07 461,541.29 3.15 8,083.23 MWD+IFR2+MS+sag(7) 12,676.17 91.88 340.53 6,224.80 6,168.60 1,044.15 -8,315.46 6,032,129.06 461,510.86 3.61 8,144.63 MWD+IFR2+MS+sag(7) 12,771.79 93.54 338.11 6,220.28 6,164.08 1,133.49 -8,349.19 6,032,218.53 461,477.50 3.07 8,207.88 MWD+IFR2+MS+sag(7) 12,850.00 93.34 336.38 6,215.59 6,159.39 1,205.48 -8,379.38 6,032,290.64 461,447.60 2.22 8,261.66 MWD+IFR2+MS+sag(8) 12,867.91 92.47 337.25 6,214.68 6,158.48 1,221.93 -8,386.43 6,032,307.11 461,440.63 6.87 8,274.08 MWD+IFR2+MS+sag(8) 12,965.10 91.18 329.71 6,211.58 6,155.38 1,308.78 -8,429.77 6,032,394.13 461,397.64 7.87 8,345.43 MWD+IFR2+MS+sag(8) 13,061.01 90.94 326.12 6,209.81 6,153.61 1,390.01 -8,480.70 6,032,475.56 461,347.05 3.75 8,421.87 MWD+IFR2+MS+sag(8) 13,156.84 91.87 325.44 6,207.46 6,151.26 1,469.23 -8,534.57 6,032,554.98 461,293.50 1.20 8,500.36 MWD+IFR2+MS+sag(8) 13,253.35 89.57 323.76 6,206.24 6,150.04 1,547.88 -8,590.47 6,032,633.86 461,237.93 2.95 8,580.53 MWD+IFR2+MS+sag(8) 13,375.00 91.68 320.68 6,204.92 6,148.72 1,644.01 -8,664.98 6,032,730.27 461,163.82 3.07 8,684.31 MWD+IFR2+MS+sag(9) 13,446.88 90.87 317.43 6,203.32 6,147.12 1,698.28 -8,712.07 6,032,784.73 461,116.96 4.66 8,747.59 MWD+IFR2+MS+sag(9) 13,543.96 91.45 317.15 6,201.35 6,145.15 1,769.60 -8,777.90 6,032,856.31 461,051.42 0.66 8,834.46 MWD+IFR2+MS+sag(9) 13,641.29 94.56 317.18 6,196.25 6,140.05 1,840.87 -8,843.97 6,032,927.84 460,985.64 3.20 8,921.52 MWD+IFR2+MS+sag(9) 13,739.42 93.61 316.67 6,189.26 6,133.06 1,912.36 -8,910.82 6,032,999.60 460,919.09 1.10 9,009.40 MWD+IFR2+MS+sag(9) 1/31/2011 9:29:49AM Page 6 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)©56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)©56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 PB5 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 PB5 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name ( 13,834.13 94.61 317.01 6,182.47 6,126.27 1,981.27 -8,975.44 6,033,068.76 460,854.76 1.11 9,094.27 MWD+IFR2+MS+sag(9) 13,931.48 94.29 317.29 6,174.92 6,118.72 2,052.43 -9,041.45 6,033,140.18 460,789.05 0.44 9,181.23 MWD+IFR2+MS+sag(9) 14,027.23 94.23 318.52 6,167.81 6,111.61 2,123.28 -9,105.45 6,033,211.28 460,725.34 1.28 9,266.22 MWD+IFR2+MS+sag(9) 14,123.13 93.79 319.76 6,161.10 6,104.90 2,195.63 -9,168.04 6,033,283.88 460,663.06 1.37 9,350.41 MWD+IFR2+MS+sag(9) 14,218.72 89.45 320.37 6,158.40 6,102.20 2,268.88 -9,229.36 6,033,357.37 460,602.04 4.58 9,433.74 MWD+IFR2+MS+sag(9) 14,315.07 86.86 319.79 6,161.50 6,105.30 2,342.73 -9,291.15 6,033,431.46 460,540.55 2.75 9,517.72 MWD+IFR2+MS+sag(9) 14,411.34 85.57 318.65 6,167.85 6,111.65 2,415.47 -9,353.89 6,033,504.44 460,478.12 1.79 9,602.19 MWD+IFR2+MS+sag(9) 14,507.77 86.70 319.05 6,174.35 6,118.15 2,487.91 -9,417.20 6,033,577.14 460,415.11 1.24 9,687.09 MWD+IFR2+MS+sag(9) 14,604.45 81.76 320.25 6,184.07 6,127.87 2,561.19 -9,479.46 6,033,650.66 460,353.15 5.26 9,771.31 MWD+IFR2+MS+sag(9) 14,700.67 82.59 319.87 6,197.17 6,140.97 2,634.28 -9,540.66 6,033,723.99 460,292.26 0.95 9,854.46 MWD+IFR2+MS+sag(9) 14,796.87 82.15 317.76 6,209.95 6,153.75 2,706.03 -9,603.44 6,033,795.99 460,229.78 2.22 9,938.62 MWD+IFR2+MS+sag(9) 14,843.00 82.15 317.76 6,216.25 6,160.05 2,739.86 -9,634.16 6,033,829.94 460,199.20 0.00 9,979.35 PROJECTED to TD 1/31/2011 9:29:49AM Page 7 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development ND Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 Database: .Pioneer 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 ODSN-18-Slot ODS-18 Well Position +N/-S 0.00 ft Northing: 6,031,051.27 ft Latitude: 70°29'45.254 N +E/-W 0.00 ft Easting: 469,821.18 ft Longitude: 150°14'48.375 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft [Wellbore ODSN-18 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-18 PN11 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 13,156.84 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 290.79 Survey Program Date 1/27/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 141.00 981.00 ODSN-18 PB1 Gyro 1 (ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 10/25/2010 1,027.53 1,027.53 ODSN-18 PB1 MWD 1 (ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/2/2010 1: 1,123.00 1,123.00 ODSN-18 PB1 Gyro 2(ODSN-18 PB1) SR-Gyro-SS Fixed:v2:surface readout gyro single shot 11/2/2010 t 1,174.43 3,566.42 ODSN-18 PB1 MWD 2(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/26/2010 • • 3,630.15 8,392.12 ODSN-18 PB1 MWD 3(ODSN-18 PB1) MWD+IFR2+MS+sag Fixed:v2:lIFR dec&3-axis correction+sag 11/1/2010 1: 8,438.00 12,090.00 ODSN-18 PB2 MWD 4(ODSN-18 PB2) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/5/2010 1: 12,122.46 12,771.79 ODSN-18 PB3 MWD 5(ODSN-18 P63) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/22/2010 • i 12,850.00 13,156.84 ODSN-18 PB4 MWD 6(ODSN-18 PB4) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 12/30/2010 • 13,250.00 16,630.89 ODSN-18 MWD 8(ODSN-18) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 1/6/2011 12: 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 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,051.27 469,821.18 0.00 0.00 UNDEFINED 141.00 0.26 304.00 141.00 84.80 0.13 -0.19 6,031,051.40 469,820.99 0.26 0.22 SR-Gyro-SS(1) 199.00 0.27 348.71 199.00 142.80 0.33 -0.32 6,031,051.60 469,820.86 0.35 0.42 SR-Gyro-SS(1) 232.00 0.49 322.56 232.00 175.80 0.52 -0.42 6,031,051.79 469,820.76 0.83 0.58 SR-Gyro-SS(1) 290.00 0.48 322.52 290.00 233.80 0.91 -0.72 6,031,052.18 469,820.46 0.02 1.00 SR-Gyro-SS(1) 323.00 0.93 308.43 322.99 266.79 1.19 -1.02 6,031,052.46 469,820.17 1.45 1.37 SR-Gyro-SS(1) 382.00 1.25 295.72 381.98 325.78 1.76 -1.97 6,031,053.04 469,819.22 0.68 2.47 SR-Gyro-SS(1) 1/312011 9:37:37AM Page 2 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+ 13.5'(copy)©56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'(copy)©56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 415.00 1.90 288.47 414.97 358.77 2.09 -2.81 6,031,053.38 469,818.38 2.06 3.37 SR-Gyro-SS(1) 472.00 2.17 284.07 471.93 415.73 2.66 -4.76 6,031,053.94 469,816.43 0.55 5.39 SR-Gyro-SS(1) 505.00 2.74 284.05 504.90 448.70 3.00 -6.13 6,031,054.29 469,815.06 1.73 6.79 SR-Gyro-SS(1) 568.00 3.14 281.82 567.82 511.62 3.72 -9.28 6,031,055.03 469,811.92 0.66 9.99 SR-Gyro-SS(1) 601.00 3.54 281.44 600.76 544.56 4.11 -11.16 6,031,055.42 469,810.04 1.21 11.89 SR-Gyro-SS(1) 662.00 3.66 281.14 661.64 605.44 4.86 -14.92 6,031,056.19 469,806.28 0.20 15.67 SR-Gyro-SS(1) 685.00 3.95 280.22 684.59 628.39 5.14 -16.42 6,031,056.47 469,804.79 1.29 17.17 SR-Gyro-SS(1) 758.00 4.41 281.46 757.40 701.20 6.14 -21.64 6,031,057.50 469,799.57 0.64 22.41 SR-Gyro-SS(1) I 791.00 4.78 281.29 790.29 734.09 6.66 -24.23 6,031,058.03 469,796.98 1.12 25.02 SR-Gyro-SS(1) 853.00 5.29 282.35 852.05 795.85 7.78 -29.56 6,031,059.17 469,791.66 0.84 30.39 SR-Gyro-SS(1) 886.00 5.85 279.85 884.90 828.70 8.39 -32.70 6,031,059.79 469,788.52 1.85 33.55 SR-Gyro-SS(1) 948.00 6.88 279.90 946.51 890.31 9.57 -39.47 6,031,061.00 469,781.75 1.66 40.30 SR-Gyro-SS(1) 981.00 6.89 278.10 979.28 923.08 10.19 -43.38 6,031,061.64 469,777.85 0.65 44.17 SR-Gyro-SS(1) 1,027.53 6.83 276.30 1,025.47 969.27 10.89 -48.89 6,031,062.35 469,772.34 0.48 49.57 MWD+IFR2+MS+sag(2) 1,123.00 9.55 277.06 1,119.96 1,063.76 12.48 -62.40 6,031,064.01 469,758.84 2.85 62.76 SR-Gyro-SS(3) 1,174.43 9.71 277.20 1,170.67 1,114.47 13.55 -70.93 6,031,065.11 469,750.31 0.31 71.12 MWD+IFR2+MS+sag(4) 1,218.54 9.91 278.29 1,214.13 1,157.93 14.57 -78.38 6,031,066.15 469,742.87 0.62 78.45 MWD+IFR2+MS+sag(4) 1,314.10 9.75 271.65 1,308.29 1,252.09 15.98 -94.61 6,031,067.64 469,726.65 1.20 94.12 MWD+IFR2+MS+sag(4) 1,409.32 10.15 272.52 1,402.08 1,345.88 16.59 -111.05 6,031,068.30 469,710.21 0.45 109.70 MWD+IFR2+MS+sag(4) 1,504.37 10.95 274.95 1,495.52 1,439.32 17.73 -128.41 6,031,069.52 469,692.86 0.96 126.34 MWD+IFR2+MS+sag(4) 1,599.91 12.48 272.29 1,589.07 1,532.87 18.93 -147.77 6,031,070.80 469,673.51 1.70 144.86 MWD+IFR2+MS+sag(4) 1,631.69 12.76 273.11 1,620.08 1,563.88 19.26 -154.70 6,031,071.15 469,666.57 1.05 151.46 MWD+IFR2+MS+sag(4) 1,725.28 14.37 274.13 1,711.06 1,654.86 20.65 -176.61 6,031,072.64 469,644.68 1.74 172.44 MWD+IFR2+MS+sag(4) 1,821.10 13.44 273.34 1,804.07 1,747.87 22.16 -199.58 6,031,074.24 469,621.71 0.99 194.45 MWD+IFR2+MS+sag(4) 1,915.58 15.28 274.70 1,895.59 1,839.39 23.82 -222.95 6,031,075.99 469,598.35 1.98 216.89 MWD+IFR2+MS+sag(4) 2,011.74 15.85 275.48 1,988.23 1,932.03 26.11 -248.65 6,031,078.39 469,572.66 0.63 241.73 MWD+IFR2+MS+sag(4) 2,107.39 14.66 274.53 2,080.51 2,024.31 28.31 -273.72 6,031,080.69 469,547.60 1.27 265.95 MWD+IFR2+MS+sag(4) 2,202.94 13.62 277.80 2,173.16 2,116.96 30.80 -296.92 6,031,083.27 469,524.41 1.37 288.52 MWD+IFR2+MS+sag(4) 2,241.41 13.96 276.43 2,210.52 2,154.32 31.93 -306.02 6,031,084.44 469,515.32 1.23 297.43 MWD+IFR2+MS+sag(4) 2,298.61 14.97 276.21 2,265.91 2,209.71 33.50 -320.22 6,031,086.07 469,501.13 1.77 311.26 MWD+IFR2+MS+sag(4) 2,333.40 15.89 274.27 2,299.44 2,243.24 34.34 -329.44 6,031,086.95 469,491.92 3.03 320.18 MWD+IFR2+MS+sag(4) 2,393.28 16.92 271.13 2,356.89 2,300.69 35.12 -346.33 6,031,087.80 469,475.03 2.27 336.24 MWD+IFR2+MS+sag(4) 2,488.03 20.47 266.74 2,446.63 2,390.43 34.45 -376.67 6,031,087.25 469,444.70 4.03 364.37 MWD+IFR2+MS+sag(4) 2,583.22 24.38 267.73 2,534.60 2,478.40 32.73 -412.93 6,031,085.67 469,408.43 4.13 397.66 MWD+IFR2+MS+sag(4) 12,678.36 29.60 267.12 2,619.35 2,563.15 30.77 -456.05 6,031,083.89 469,365.31 5.49 437.27 MWD+IFR2+MS+sag(4) 2,773.39 32.86 268.44 2,700.60 2,644.40 28.89 -505.27 6,031,082.21 469,316.08 3.51 482.62 MWD+IFR2+MS+sag(4) 2,868.92 36.48 268.01 2,779.16 2,722.96 27.20 -559.58 6,031,080.73 469,261.77 3.80 532.79 MWD+IFR2+MS+sag(4) 2,963.62 38.66 267.56 2,854.21 2,798.01 24.96 -617.27 6,031,078.73 469,204.08 2.32 585.94 MWD+IFR2+MS+sag(4) 3,059.68 38.65 266.41 2,929.23 2,873.03 21.80 -677.19 6,031,075.82 469,144.15 0.75 640.83 MWD+IFR2+MS+sag(4) 3,155.09 41.44 265.51 3,002.26 2,946.06 17.46 -738.41 6,031,071.73 469,082.92 2.99 696.53 MWD+IFR2+MS+sag(4) 1/312011 9:37:37AM Page 3 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 Database: .Pioneer 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 3,249.55 42.15 264.91 3,072.68 3,016.48 12.20 -801.15 6,031,066.73 469,020.17 0.86 753.31 MWD+IFR2+MS+sag(4) 3,344.92 46.28 265.36 3,141.02 3,084.82 6.58 -867.40 6,031,061.37 468,953.90 4.34 813.25 MWD+IFR2+MS+sag(4) 3,439.63 48.20 265.43 3,205.32 3,149.12 0.99 -936.71 6,031,056.07 468,884.58 2.03 876.07 MWD+IFR2+MS+sag(4) 3,534.85 49.89 264.83 3,267.73 3,211.53 -5.12 -1,008.36 6,031,050.25 468,812.91 1.84 940.88 MWD+IFR2+MS+sag(4) 3,566.42 50.37 265.46 3,287.97 3,231.77 -7.17 -1,032.50 6,031,048.30 468,788.76 2.16 962.73 MWD+IFR2+MS+sag(4) 3,630.15 49.94 264.80 3,328.80 3,272.60 -11.32 -1,081.25 6,031,044.34 468,740.00 1.04 1,006.83 MWD+IFR2+MS+sag(5) 3,728.64 48.98 264.86 3,392.82 3,336.62 -18.06 -1,155.80 6,031,037.90 468,665.44 0.98 1,074.13 MWD+IFR2+MS+sag(5) 3,823.03 48.55 265.70 3,455.04 3,398.84 -23.91 -1,226.54 6,031,032.35 468,594.68 0.81 1,138.19 MWD+IFR2+MS+sag(5) 3,918.36 47.71 266.13 3,518.66 3,462.46 -28.97 -1,297.34 6,031,027.57 468,523.86 0.94 1,202.59 MWD+IFR2+MS+sag(5) 4,013.58 47.75 266.18 3,582.71 3,526.51 -33.69 -1,367.65 6,031,023.14 468,453.55 0.06 1,266.64 MWD+IFR2+MS+sag(5) 4,108.84 51.32 267.02 3,644.52 3,588.32 -37.97 -1,439.98 6,031,019.15 468,381.20 3.81 1,332.74 MWD+IFR2+MS+sag(5) 4,203.49 54.06 266.88 3,701.89 3,645.69 -41.98 -1,515.15 6,031,015.45 468,306.03 2.90 1,401.59 MWD+IFR2+MS+sag(5) 4,300.86 56.97 265.70 3,757.01 3,700.81 -47.19 -1,595.23 6,031,010.56 468,225.93 3.15 1,474.61 MWD+IFR2+MS+sag(5) 4,398.80 58.70 262.86 3,809.16 3,752.96 -55.47 -1,677.71 6,031,002.62 468,143.43 3.02 1,548.78 MWD+IFR2+MS+sag(5) 4,493.85 61.31 259.87 3,856.68 3,800.48 -67.85 -1,759.07 6,030,990.57 468,062.03 3.87 1,620.44 MWD+IFR2+MS+sag(5) 4,584.47 65.00 259.37 3,897.60 3,841.40 -82.42 -1,838.58 6,030,976.32 467,982.46 4.10 1,689.61 MWD+IFR2+MS+sag(5) 4,684.58 67.49 257.58 3,937.92 3,881.72 -100.74 -1,928.35 6,030,958.37 467,892.63 2.98 1,767.03 MWD+IFR2+MS+sag(5) 4,779.26 68.84 257.43 3,973.14 3,916.94 -119.76 -2,014.15 6,030,939.70 467,806.76 1.43 1,840.50 MWD+IFR2+MS+sag(5) 4,871.89 70.51 256.93 4,005.31 3,949.11 -139.03 -2,098.85 6,030,920.77 467,722.00 1.87 1,912.84 MWD+IFR2+MS+sag(5) 4,965.11 71.34 257.43 4,035.78 3,979.58 -158.58 -2,184.75 6,030,901.58 467,636.02 1.02 1,986.21 MWD+IFR2+MS+sag(5) 5,063.57 71.46 258.28 4,067.18 4,010.98 -178.21 -2,275.98 6,030,882.32 467,544.73 0.83 2,064.53 MWD+IFR2+MS+sag(5) 5,159.38 71.34 258.20 4,097.74 4,041.54 -196.72 -2,364.88 6,030,864.17 467,455.76 0.15 2,141.07 MWD+IFR2+MS+sag(5) 5,254.53 71.20 258.00 4,128.29 4,072.09 -215.30 -2,453.05 6,030,845.95 467,367.52 0.25 2,216.91 MWD+IFR2+MS+sag(5) 5,345.36 70.63 257.39 4,157.99 4,101.79 -233.59 -2,536.92 6,030,828.00 467,283.59 0.89 2,288.82 MWD+IFR2+MS+sag(5) 5,441.12 71.23 257.83 4,189.28 4,133.08 -253.01 -2,625.31 6,030,808.94 467,195.13 0.76 2,364.57 MWD+IFR2+MS+sag(5) 5,536.74 71.07 258.19 4,220.17 4,163.97 -271.81 -2,713.83 6,030,790.51 467,106.54 0.39 2,440.65 MWD+IFR2+MS+sag(5) 5,631.50 70.36 258.20 4,251.47 4,195.27 -290.11 -2,801.38 6,030,772.57 467,018.93 0.75 2,516.00 MWD+IFR2+MS+sag(5) 5,727.44 70.95 258.18 4,283.25 4,227.05 -308.63 -2,889.99 6,030,754.40 466,930.25 0.62 2,592.26 MWD+IFR2+MS+sag(5) 5,824.68 70.61 258.07 4,315.26 4,259.06 -327.53 -2,979.84 6,030,735.87 466,840.33 0.37 2,669.56 MWD+IFR2+MS+sag(5) 5,917.59 70.86 257.56 4,345.92 4,289.72 -346.04 -3,065.57 6,030,717.71 466,754.54 0.58 2,743.14 MWD+IFR2+MS+sag(5) 6,011.23 71.05 257.12 4,376.47 4,320.27 -365.44 -3,151.94 6,030,698.66 466,668.11 0.49 2,816.99 MWD+IFR2+MS+sag(5) 6,109.85 70.29 255.57 4,409.12 4,352.92 -387.41 -3,242.36 6,030,677.07 466,577.60 1.67 2,893.74 MWD+IFR2+MS+sag(5) 6,206.00 70.35 256.98 4,441.50 4,385.30 -408.89 -3,330.31 6,030,655.95 466,489.58 1.38 2,968.33 MWD+IFR2+MS+sag(5) 6,296.96 70.47 257.77 4,472.00 4,415.80 -427.62 -3,413.93 6,030,637.56 466,405.89 0.83 3,039.86 MWD+IFR2+MS+sag(5) 6,392.50 70.96 258.81 4,503.55 4,447.35 -445.92 -3,502.23 6,030,619.62 466,317.52 1.15 3,115.92 MWD+IFR2+MS+sag(5) 6,487.74 71.03 259.25 4,534.57 4,478.37 -463.05 -3,590.63 6,030,602.84 466,229.06 0.44 3,192.48 MWD+IFR2+MS+sag(5) 6,582.74 70.87 258.69 4,565.57 4,509.37 -480.23 -3,678.77 6,030,586.02 466,140.86 0.58 3,268.78 MWD+IFR2+MS+sag(5) 6,677.75 70.73 259.06 4,596.82 4,540.62 -497.54 -3,766.81 6,030,569.07 466,052.76 0.40 3,344.94 MWD+IFR2+MS+sag(5) 6,773.48 71.16 258.45 4,628.07 4,571.87 -515.19 -3,855.56 6,030,551.79 465,963.95 0.75 3,421.65 MWD+IFR2+MS+sag(5) 6,868.81 71.27 257.68 4,658.77 4,602.57 -533.85 -3,943.86 6,030,533.48 465,875.59 0.77 3,497.57 MWD+IFR2+MS+sag(5) 1/31/2011 9:37:37AM Page 4 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 Database: .Pioneer 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 6,964.81 70.80 259.14 4,689.97 4,633.77 -552.10 -4,032.79 6,030,515.61 465,786.59 1.52 3,574.24 MWD+IFR2+MS+sag(5) 7,058.66 71.73 258.75 4,720.12 4,663.92 -569.14 -4,120.02 6,030,498.92 465,699.30 1.07 3,649.74 MWD+IFR2+MS+sag(5) 7,155.94 70.48 258.65 4,751.62 4,695.42 -587.17 -4,210.27 6,030,481.25 465,608.99 1.29 3,727.72 MWD+IFR2+MS+sag(5) 7,249.11 70.27 258.33 4,782.91 4,726.71 -604.68 -4,296.26 6,030,464.09 465,522.93 0.39 3,801.89 MWD+IFR2+MS+sag(5) 7,345.08 71.16 258.01 4,814.61 4,758.41 -623.25 -4,384.92 6,030,445.88 465,434.21 0.98 3,878.19 MWD+IFR2+MS+sag(5) 7,441.17 70.89 257.84 4,845.85 4,789.65 -642.26 -4,473.78 6,030,427.24 465,345.28 0.33 3,954.51 MWD+IFR2+MS+sag(5) 7,536.09 69.56 258.34 4,877.96 4,821.76 -660.70 -4,561.18 6,030,409.16 465,257.82 1.49 4,029.68 MWD+IFR2+MS+sag(5) 7,626.41 69.56 260.20 4,909.51 4,853.31 -676.45 -4,644.33 6,030,393.74 465,174.61 1.93 4,101.82 MWD+IFR2+MS+sag(5) 7,726.42 69.36 260.00 4,944.60 4,888.40 -692.56 -4,736.58 6,030,378.02 465,082.30 0.27 4,182.35 MWD+IFR2+MS+sag(5) 7,820.69 69.02 260.88 4,978.09 4,921.89 -707.19 -4,823.48 6,030,363.74 464,995.36 0.94 4,258.40 MWD+IFR2+MS+sag(5) 7,915.20 69.21 260.17 5,011.78 4,955.58 -721.73 -4,910.57 6,030,349.56 464,908.21 0.73 4,334.66 MWD+IFR2+MS+sag(5) 8,011.00 69.69 260.57 5,045.41 4,989.21 -736.73 -4,999.01 6,030,334.91 464,819.72 0.64 4,412.02 MWD+IFR2+MS+sag(5) 8,106.40 69.26 260.81 5,078.86 5,022.66 -751.19 -5,087.18 6,030,320.82 464,731.51 0.51 4,489.31 MWD+IFR2+MS+sag(5) 8,201.28 69.17 260.04 5,112.53 5,056.33 -765.94 -5,174.65 6,030,306.42 464,643.99 0.76 4,565.85 MWD+IFR2+MS+sag(5) 8,296.82 69.86 258.87 5,145.97 5,089.77 -782.32 -5,262.63 6,030,290.40 464,555.95 1.36 4,642.29 MWD+IFR2+MS+sag(5) 8,392.12 69.57 258.47 5,179.00 5,122.80 -799.88 -5,350.28 6,030,273.19 464,468.24 0.50 4,718.00 MWD+IFR2+MS+sag(5) 8,438.00 69.60 258.48 5,195.01 5,138.81 -808.47 -5,392.41 6,030,264.77 464,426.07 0.07 4,754.33 MWD+IFR2+MS+sag(6) 8,529.05 72.36 255.25 5,224.69 5,168.49 -828.05 -5,476.21 6,030,245.54 464,342.20 4.52 4,825.73 MWD+IFR2+MS+sag(6) 8,575.56 73.36 254.40 5,238.39 5,182.19 -839.68 -5,519.11 6,030,234.08 464,299.27 2.77 4,861.70 MWD+IFR2+MS+sag(6) 8,670.27 74.48 252.70 5,264.63 5,208.43 -865.46 -5,606.38 6,030,208.67 464,211.90 2.09 4,934.14 MWD+IFR2+MS+sag(6) 8,718.63 74.39 251.47 5,277.60 5,221.40 -879.79 -5,650.71 6,030,194.52 464,167.52 2.46 4,970.50 MWD+IFR2+MS+sag(6) 8,785.71 74.04 252.09 5,295.85 5,239.65 -899.97 -5,712.02 6,030,174.59 464,106.13 1.03 5,020.66 MWD+IFR2+MS+sag(6) 8,881.94 73.38 251.52 5,322.84 5,266.64 -928.81 -5,799.77 6,030,146.10 464,018.28 0.89 5,092.45 MWD+IFR2+MS+sag(6) 8,977.86 73.11 252.53 5,350.50 5,294.30 -957.15 -5,887.13 6,030,118.12 463,930.81 1.05 5,164.07 MWD+IFR2+MS+sag(6) 9,072.22 72.75 254.47 5,378.20 5,322.00 -982.77 -5,973.61 6,030,092.85 463,844.23 2.00 5,235.83 MWD+IFR2+MS+sag(6) 9,168.00 72.53 256.55 5,406.78 5,350.58 -1,005.65 -6,062.12 6,030,070.34 463,755.64 2.09 5,310.45 MWD+IFR2+MS+sag(6) 9,262.77 72.47 260.99 5,435.29 5,379.09 -1,023.24 -6,150.74 6,030,053.11 463,666.95 4.47 5,387.06 MWD+IFR2+MS+sag(6) 9,357.47 72.46 264.53 5,463.83 5,407.63 -1,034.62 -6,240.31 6,030,042.09 463,577.35 3.56 5,466.75 MWD+IFR2+MS+sag(6) 9,452.53 71.85 267.34 5,492.97 5,436.77 -1,041.04 -6,330.55 6,030,036.04 463,487.09 2.89 5,548.84 MWD+IFR2+MS+sag(6) 9,547.64 72.27 271.43 5,522.27 5,466.07 -1,042.01 -6,421.01 6,030,035.44 463,396.64 4.11 5,633.07 MWD+IFR2+MS+sag(6) 9,642.41 72.06 275.01 5,551.31 5,495.11 -1,036.94 -6,511.07 6,030,040.87 463,306.61 3.60 5,719.06 MWD+IFR2+MS+sag(6) 9,737.67 71.99 278.14 5,580.71 5,524.51 -1,026.57 -6,601.07 6,030,051.61 463,216.66 3.13 5,806.88 MWD+IFR2+MS+sag(6) 9,833.18 71.37 281.53 5,610.74 5,554.54 -1,011.09 -6,690.39 6,030,067.45 463,127.42 3.43 5,895.88 MWD+IFR2+MS+sag(6) 9,929.57 71.41 286.08 5,641.51 5,585.31 -989.30 -6,779.07 6,030,089.60 463,038.83 4.47 5,986.53 MWD+IFR2+MS+sag(6) 10,024.64 71.38 289.64 5,671.85 5,615.65 -961.67 -6,864.82 6,030,117.57 462,953.21 3.55 6,076.49 MWD+IFR2+MS+sag(6) 10,118.68 72.08 292.42 5,701.34 5,645.14 -929.62 -6,948.16 6,030,149.95 462,870.01 2.90 6,165.78 MWD+IFR2+MS+sag(6) 10,214.27 72.08 296.36 5,730.76 5,674.56 -892.07 -7,030.97 6,030,187.83 462,787.35 3.92 6,256.53 MWD+IFR2+MS+sag(6) 10,309.31 71.94 299.25 5,760.12 5,703.92 -849.92 -7,110.92 6,030,230.31 462,707.59 2.90 6,346.24 MWD+IFR2+MS+sag(6) 10,404.13 72.22 300.94 5,789.30 5,733.10 -804.68 -7,188.97 6,030,275.86 462,629.73 1.72 6,435.27 MWD+IFR2+MS+sag(6) 10,498.75 73.56 303.93 5,817.14 5,760.94 -756.17 -7,265.28 6,030,324.67 462,553.62 3.34 6,523.82 MWD+IFR2+MS+sag(6) 1/31/2011 9:37:37AM Page 5 COMPASS 2003.16 Build 42F 6 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7+13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 10,593.70 74.26 308.42 5,843.47 5,787.27 -702.34 -7,338.90 6,030,378.80 462,480.23 4.60 6,611.75 MWD+IFR2+MS+sag(6) 10,689.51 74.46 309.71 5,869.30 5,813.10 -644.19 -7,410.53 6,030,437.23 462,408.84 1.31 6,699.36 MWD+IFR2+MS+sag(6) 10,784.19 74.92 311.89 5,894.30 5,838.10 -584.53 -7,479.65 6,030,497.17 462,339.97 2.27 6,785.16 MWD+IFR2+MS+sag(6) 10,879.86 74.40 314.18 5,919.61 5,863.41 -521.57 -7,547.09 6,030,560.39 462,272.80 2.37 6,870.55 MWD+IFR2+MS+sag(6) 10,975.10 74.72 315.49 5,944.97 5,888.77 -456.84 -7,612.19 6,030,625.38 462,207.97 1.37 6,954.38 MWD+IFR2+MS+sag(6) 11,070.33 75.73 317.97 5,969.26 5,913.06 -389.80 -7,675.29 6,030,692.67 462,145.14 2.73 7,037.18 MWD+IFR2+MS+sag(6) 11,166.35 75.55 321.26 5,993.08 5,936.88 -318.96 -7,735.55 6,030,763.75 462,085.18 3.32 7,118.66 MWD+IFR2+MS+sag(6) 11,261.96 75.75 324.90 6,016.78 5,960.58 -244.92 -7,791.18 6,030,838.01 462,029.85 3.69 7,196.95 MWD+IFR2+MS+sag(6) 11,357.50 76.88 328.38 6,039.39 5,983.19 -167.40 -7,842.21 6,030,915.73 461,979.14 3.73 7,272.17 MWD+IFR2+MS+sag(6) 11,451.93 77.90 332.01 6,060.02 6,003.82 -87.45 -7,888.00 6,030,995.85 461,933.68 3.90 7,343.36 MWD+IFR2+MS+sag(6) 11,547.13 79.28 336.17 6,078.86 6,022.66 -3.53 -7,928.76 6,031,079.93 461,893.27 4.52 7,411.25 MWD+IFR2+MS+sag(6) 11,642.52 79.79 339.06 6,096.19 6,039.99 83.20 -7,964.48 6,031,166.79 461,857.91 3.03 7,475.42 MWD+IFR2+MS+sag(6) 11,736.96 79.85 338.89 6,112.88 6,056.68 169.96 -7,997.83 6,031,253.68 461,824.91 0.19 7,537.40 MWD+IFR2+MS+sag(6) 11,831.99 79.89 339.14 6,129.59 6,073.39 257.31 -8,031.33 6,031,341.15 461,791.77 0.26 7,599.72 MWD+IFR2+MS+sag(6) 11,927.00 79.58 341.03 6,146.52 6,090.32 345.20 -8,063.17 6,031,429.17 461,760.29 1.98 7,660.69 MWD+IFR2+MS+sag(6) 12,022.53 80.09 342.27 6,163.38 6,107.18 434.45 -8,092.78 6,031,518.52 461,731.05 1.38 7,720.04 MWD+IFR2+MS+sag(6) 12,067.94 80.08 343.26 6,171.20 6,115.00 477.17 -8,106.03 6,031,561.30 461,717.97 2.15 7,747.59 MWD+IFR2+MS+sag(6) 12,090.00 80.21 343.64 6,174.98 6,118.78 498.01 -8,112.22 6,031,582.15 461,711.87 1.81 7,760.78 MWD+IFR2+MS+sag(6) 12,122.46 80.82 341.19 6,180.33 6,124.13 528.52 -8,121.89 6,031,612.71 461,702.32 7.68 7,780.65 MWD+IFR2+MS+sag(7) 12,148.55 81.79 338.20 6,184.27 6,128.07 552.71 -8,130.84 6,031,636.92 461,693.47 11.92 7,797.60 MWD+IFR2+MS+sag(7) 12,196.49 83.40 336.52 6,190.45 6,134.25 596.58 -8,149.14 6,031,680.87 461,675.35 4.83 7,830.28 MWD+IFR2+MS+sag(7) 12,245.45 84.40 336.18 6,195.65 6,139.45 641.17 -8,168.67 6,031,725.53 461,656.00 2.16 7,864.37 MWD+IFR2+MS+sag(7) 12,289.71 84.07 336.40 6,200.10 6,143.90 681.49 -8,186.38 6,031,765.92 461,638.46 0.89 7,895.23 MWD+IFR2+MS+sag(7) 12,386.42 84.01 338.03 6,210.14 6,153.94 770.17 -8,223.63 6,031,854.74 461,601.58 1.68 7,961.53 MWD+IFR2+MS+sag(7) 12,483.58 83.89 342.52 6,220.39 6,164.19 861.10 -8,256.23 6,031,945.79 461,569.35 4.60 8,024.29 MWD+IFR2+MS+sag(7) 12,532.01 87.52 342.90 6,224.01 6,167.81 907.20 -8,270.58 6,031,991.95 461,555.19 7.54 8,054.07 MWD+IFR2+MS+sag(7) 12,579.25 88.92 342.40 6,225.48 6,169.28 952.27 -8,284.66 6,032,037.07 461,541.29 3.15 8,083.23 MWD+IFR2+MS+sag(7) 12,676.17 91.88 340.53 6,224.80 6,168.60 1,044.15 -8,315.46 6,032,129.06 461,510.86 3.61 8,144.63 MWD+IFR2+MS+sag(7) 12,771.79 93.54 338.11 6,220.28 6,164.08 1,133.49 -8,349.19 6,032,218.53 461,477.50 3.07 8,207.88 MWD+IFR2+MS+sag(7) 12,850.00 93.34 336.38 6,215.59 6,159.39 1,205.48 -8,379.38 6,032,290.64 461,447.60 2.22 8,261.66 MWD+IFR2+MS+sag(8) 12,867.91 92.47 337.25 6,214.68 6,158.48 1,221.93 -8,386.43 6,032,307.11 461,440.63 6.87 8,274.08 MWD+IFR2+MS+sag(8) 12,965.10 91.18 329.71 6,211.58 6,155.38 1,308.78 -8,429.77 6,032,394.13 461,397.64 7.87 8,345.43 MWD+IFR2+MS+sag(8) 13,061.01 90.94 326.12 6,209.81 6,153.61 1,390.01 -8,480.70 6,032,475.56 461,347.05 3.75 8,421.87 MWD+IFR2+MS+sag(8) 13,156.84 91.87 325.44 6,207.46 6,151.26 1,469.23 -8,534.57 6,032,554.98 461,293.50 1.20 8,500.36 MWD+IFR2+MS+sag(8) 13,250.00 89.65 323.82 6,206.22 6,150.02 1,545.18 -8,588.49 6,032,631.15 461,239.90 2.95 8,577.72 MWD+IFR2+MS+sag(9) 13,256.15 89.44 322.68 6,206.27 6,150.07 1,550.11 -8,592.17 6,032,636.09 461,236.24 18.85 8,582.91 MWD+IFR2+MS+sag(9) 13,350.96 87.11 323.73 6,209.12 6,152.92 1,625.99 -8,648.93 6,032,712.19 461,179.80 2.70 8,662.91 MWD+IFR2+MS+sag(9) 13,448.22 88.80 323.22 6,212.60 6,156.40 1,704.09 -8,706.77 6,032,790.52 461,122.28 1.81 8,744.71 MWD+IFR2+MS+sag(9) 13,544.65 85.56 323.73 6,217.34 6,161.14 1,781.48 -8,764.09 6,032,868.13 461,065.28 3.40 8,825.76 MWD+IFR2+MS+sag(9) 13,640.89 86.33 323.44 6,224.14 6,167.94 1,858.73 -8,821.08 6,032,945.61 461,008.61 0.85 8,906.46 MWD+IFR2+MS+sag(9) 1/31/2011 9:37:37AM Page 6 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-18-Slot ODS-18 Project: Oooguruk Development TVD Reference: 42.7'+13.5(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-18 North Reference: True Wellbore: ODSN-18 Survey Calculation Method: Minimum Curvature Design: ODSN-18 PN11 Database: .Pioneer 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) (°/100') (ft) Survey Tool Name 13,737.31 86.69 321.32 6,230.01 6,173.81 1,934.96 -8,879.82 6,033,022.07 460,950.18 2.23 8,988.43 MWD+IFR2+MS+sag(9) 13,833.69 90.05 320.88 6,232.76 6,176.56 2,009.93 -8,940.31 6,033,097.27 460,890.00 3.52 9,071.59 MWD+IFR2+MS+sag(9) 13,930.46 89.29 322.09 6,233.31 6,177.11 2,085.64 -9,000.57 6,033,173.22 460,830.06 1.48 9,154.80 MWD+IFR2+MS+sag(9) 14,026.99 90.03 322.46 6,233.89 6,177.69 2,161.99 -9,059.63 6,033,249.80 460,771.31 0.86 9,237.12 MWD+IFR2+MS+sag(9) 14,122.85 88.73 323.92 6,234.92 6,178.72 2,238.73 -9,117.06 6,033,326.76 460,714.20 2.04 9,318.05 MWD+IFR2+MS+sag(9) 14,218.75 89.04 322.55 6,236.79 6,180.59 2,315.54 -9,174.45 6,033,403.80 460,657.13 1.46 9,398.96 MWD+IFR2+MS+sag(9) 14,315.40 87.99 319.97 6,239.29 6,183.09 2,390.89 -9,234.90 6,033,479.39 460,596.99 2.88 9,482.23 MWD+IFR2+MS+sag(9) 14,411.26 90.35 321.18 6,240.68 6,184.48 2,464.92 -9,295.77 6,033,553.66 460,536.43 2.77 9,565.41 MWD+IFR2+MS+sag(9) 14,508.52 90.77 319.56 6,239.73 6,183.53 2,539.83 -9,357.80 6,033,628.81 460,474.71 1.72 9,649.98 MWD+IFR2+MS+sag(9) 14,605.16 90.15 315.20 6,238.96 6,182.76 2,610.92 -9,423.22 6,033,700.16 460,409.59 4.56 9,736.38 MWD+IFR2+MS+sag(9) 14,701.30 92.33 310.59 6,236.87 6,180.67 2,676.32 -9,493.61 6,033,765.84 460,339.47 5.30 9,825.40 MWD+IFR2+MS+sag(9) 14,796.99 88.40 308.16 6,236.26 6,180.06 2,737.01 -9,567.56 6,033,826.82 460,265.78 4.83 9,916.08 MWD+IFR2+MS+sag(9) 14,894.10 86.81 306.14 6,240.32 6,184.12 2,795.60 -9,644.89 6,033,885.72 460,188.70 2.65 10,009.16 MWD+IFR2+MS+sag(9) 14,990.37 88.93 305.66 6,243.90 6,187.70 2,852.01 -9,722.81 6,033,942.43 460,111.01 2.26 10,102.04 MWD+IFR2+MS+sag(9) 15,086.83 91.28 305.32 6,243.72 6,187.52 2,908.00 -9,801.34 6,033,998.74 460,032.71 2.46 10,195.33 MWD+IFR2+MS+sag(9) 15,184.57 91.27 302.39 6,241.55 6,185.35 2,962.43 -9,882.48 6,034,053.50 459,951.80 3.00 10,290.51 MWD+IFR2+MS+sag(9) 15,281.09 87.66 298.31 6,242.45 6,186.25 3,011.18 -9,965.74 6,034,102.58 459,868.75 5.64 10,385.65 MWD+IFR2+MS+sag(9) 15,377.11 88.49 301.47 6,245.68 6,189.48 3,059.00 -10,048.93 6,034,150.73 459,785.77 3.40 10,480.39 MWD+IFR2+MS+sag(9) 15,473.69 86.31 301.13 6,250.06 6,193.86 3,109.12 -10,131.36 6,034,201.18 459,703.54 2.28 10,575.25 MWD+IFR2+MS+sag(9) 15,570.81 89.74 305.23 6,253.41 6,197.21 3,162.22 -10,212.57 6,034,254.61 459,622.56 5.50 10,670.01 MWD+IFR2+MS+sag(9) 15,666.83 94.08 309.64 6,250.20 6,194.00 3,220.53 -10,288.74 6,034,313.21 459,546.64 6.44 10,761.92 MWD+IFR2+MS+sag(9) 15,763.17 91.99 307.54 6,245.10 6,188.90 3,280.53 -10,363.93 6,034,373.51 459,471.70 3.07 10,853.51 MWD+IFR2+MS+sag(9) 15,859.61 94.19 307.64 6,239.91 6,183.71 3,339.27 -10,440.23 6,034,432.55 459,395.65 2.28 10,945.69 MWD+IFR2+MS+sag(9) 15,955.19 92.62 307.55 6,234.23 6,178.03 3,397.47 -10,515.82 6,034,491.06 459,320.30 1.65 11,037.02 MWD+IFR2+MS+sag(9) 16,051.26 91.38 306.13 6,230.88 6,174.68 3,455.04 -10,592.66 6,034,548.93 459,243.70 1.96 11,129.29 MWD+IFR2+MS+sag(9) 16,148.23 90.46 306.50 6,229.32 6,173.12 3,512.46 -10,670.79 6,034,606.66 459,165.82 1.02 11,222.71 MWD+IFR2+MS+sag(9) 16,244.54 88.91 306.71 6,229.85 6,173.65 3,569.88 -10,748.10 6,034,664.39 459,088.75 1.62 11,315.37 MWD+IFR2+MS+sag(9) 16,340.48 88.98 307.43 6,231.61 6,175.41 3,627.70 -10,824.63 6,034,722.52 459,012.46 0.75 11,407.44 MWD+IFR2+MS+sag(9) 16,437.36 89.48 307.73 6,232.92 6,176.72 3,686.78 -10,901.40 6,034,781.90 458,935.93 0.60 11,500.19 MWD+IFR2+MS+sag(9) 16,534.58 90.16 307.48 6,233.22 6,177.02 3,746.11 -10,978.42 6,034,841.53 458,859.16 0.75 11,593.25 MWD+IFR2+MS+sag(9) 16,630.89 92.33 310.64 6,231.13 6,174.93 3,806.77 -11,053.18 6,034,902.49 458,784.66 3.98 11,684.67 MWD+IFR2+MS+sag(9) 16,689.00 92.33 310.64 6,228.77 6,172.57 3,844.58 -11,097.23 6,034,940.48 458,740.76 0.00 11,739.28 PROJECTED to TD 1p 1/312011 9:37:37AM Page 7 COMPASS 2003.16 Build 42F HALLI B U RTON merry Drilling Oooguruk ODSN-18 PB1 8000 l I I 1 1 I Loggers on location Nov 5th,2010. TD 1st Intermediate Section Nov 3rd,2010 at 9139'MD, 5441'TVD.Set 9 5/8"Liner at 8822'MD,5328'TVD PIONEER 9000 - Ai,' -' ''. ' _ Begin drilling#2 Intermediate Section on Nov. ATURAL RESOURCES 14th,2010 w/9 1/2"Rhino Reamer. FIT to 14 ' ppg EMW at 9159'MD,5448.1'TVD. POOH ::: for MWD. Drill ahead on Nov 15th 10000 - , , inimuil Attempt to cut and fish out 7' Casing at 11000 - 8948'MD-No -- --- MIME Success Decision made to abandon ■■IIIIII■i Stuck section and set whipstock 1111111111111111 W —I to sidetrack 12000 11111111111EIMMIE 1 Attempt to fish out 7"' t ����►r�%�'r� p +-1Casing at 475'MD- TD#2 Intermediate , =Success - 0 Section,Nov 17th,2010 Attempt to cut and , Set 7"casing at fish out 7"'Casing at 13000 - 11200'MD,6185' 9074'II D-No 1.1 s- RIH With Casing N • ( I Scraper and Boot -- a Basket,Circulate 3 a) BU,Pooh 14000 , 15000 - _ — • 16000 • - 0- f 17000 - _- , I m._.. 10 i 20 . —___L.- 30 --40 9Q_.-. 6+0 18000 , . Rig Days HALLIBURTON Sperry Orating Oooguruk ODSN-18 8000 1 I I t 1I i) _ I I I I I I 4 Whipstock set at 8460'MD. Mill window from 8438'MD- casio MD out of thefo 9 atio I O NEE R casing. Drill new formation to 8473'MD. 9000 t _ ATURAL RESOURCES Drill Ahead with 8.5"BHA with Mud Motor. Drilled to 8757'MD 10000 i Begin drilling Intermediate Section#2 I .. on Dec 5th,2010 with 8.5"bit plus a 9.5"Rhino Reamer. Run 7"tie-back liner. 11000 j Could not sting into tie-back.POOH with 7"liner and became stuck. RIH Run 7"Liner to sting 7"liner with success and Cement — p.20.00.- . i i i i . i , Begin drilling initial 6.125" 12000 - Production Section 12/18/2010. Ct. I BHA stuck,Pump Acid and CD Fish out with wireline Q TD 8.5"Intermediate Section Drill out of Zone,POOH #2 at 12100'MD,6176'TVD, AiMD End ODSN-18 op 13000 Dec 08 th2010 4 a– N C C4 �i G Packed off,short tripped to 12935' 14000 - MD and back to bottom while fighting ' pack off,stopped at 13435'MD. RIH to cement —Decision made to plug and abandon. ODSN-18 PB2 15000 L I - / Drilled out of Zone at 13920', Pull up for Open hole Sidetrack,End ODSN-18 PB3 I / r 1 16000 Drill out of Zone,Pull Back for --1 Run 4.5"Liner _ III. -open hole sidetrack.End ODSN- I 18PB5 'C/ I 17000 I ( TD 6.125"Production _ : Section at 16689'MD,6228' Run 4.5"Tubing TVD,Jan 12th,2011 C ' _ 10 - 20 30 40 - 90 OD 18000 ' Rig Days OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format.
