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212-106
New Plugback Esets 8/13/2024 Well Name API Number PTD Number ESet Number Date 1E-28A 50-029-20832-01-00 213-095 T39403 5-15-2014 1E-112 50-029-23211-70-00 204-091 T39404 10-19-2004 3N-14APB1 50-029-21589-70-00 207-119 T39405 2-3-2009 Nikaitchuq 3 PB1 50-629-23242-70-00 205-001 T39406 5-23-2005 Nikaitchuq 3 PB2 50-629-23242-71-00 205-001 T39407 5-23-2005 Nikaitchuq 3 PB3 50-629-23242-72-00 205-001 T39408 5-23-2005 ODSK-41 PB1 50-703-20585-70-00 208-147 T39409 2-27-2009 ODSN-26 PB1 50-703-20642-70-00 211-121 T39410 2-1-2012 ODSN-26 PB2 50-703-20642-71-00 211-121 T39411 2-1-2012 ODSN-29 PB1 50-703-20661-70-00 212-106 T39412 6-12-2013 ODSN-29 PB2 50-703-20661-71-00 212-106 T39413 6-12-2013 Z-05APB1 50-029-22056-70-00 190-078 T39414 10-13-2013 ODSN-29 PB2 50-703-20661-71-00 212-106 T39413 6-12-2013 ODSN-29 PB1 50-703-20661-70-00 212-106 T39412 6-12-2013 Eni US Operating Co, Inc WELL LOG/DATA TRANSMITTAL To: ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ 333 W. 7th Ave, Anchorage, AK 99501 Well:ODSN-29 PB2 LWD/MWD Logs PDF LAS DLIS Text Drilling Mechanics Depth Drilling_Mechanics Time ScopeService RM 2" & 5" ScopeServices RM MD 2" & 5" ScopeServices RM TVD ASP Final Survey X X Density Image X Composite log X X Mudlogs (Halliburton) 2" & 5" MD Formation Evaluation Log X 2" MD Drilling Evaluation Log X 2" MD Gas Ratio Log X E-line logs 9-5/8" Multi-Finger Imaging Tool Casing 9-5/8" Multi-Finger Imaging Tool Liner 9-5/8" Radial Cement Bond Log 9-5/8" Bottom Hole Pressure Survey 9-5/8" Micro DLS Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Edgar Pinzon Mail: edgar.pinzon@eni.com Received By: ___________________________________Date:____________ Eni US Operating Co, Inc. August 13, 2024 212-106 T39402 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.13 10:32:42 -08'00' Eni US Operating Co, Inc WELL LOG/DATA TRANSMITTAL To: ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ 333 W. 7th Ave, Anchorage, AK 99501 Well:ODSN-29 PB1 LWD/MWD Logs PDF LAS DLIS Text Drilling Mechanics Depth Drilling_Mechanics Time ScopeService RM 2" & 5" ScopeServices RM MD 2" & 5" ScopeServices RM TVD ASP Final Survey X X Composite log X X Mudlogs (Halliburton) 2" & 5" MD Formation Evaluation Log X 2" MD Drilling Evaluation Log X 2" MD Gas Ratio Log X E-line logs 9-5/8" Multi-Finger Imaging Tool Casing 9-5/8" Multi-Finger Imaging Tool Liner 9-5/8" Radial Cement Bond Log 9-5/8" Bottom Hole Pressure Survey 9-5/8" Micro DLS Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Edgar Pinzon Mail: edgar.pinzon@eni.com Received By: ___________________________________Date:____________ Eni US Operating Co, Inc. August 13, 2024 212-106 T39401 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.13 10:32:02 -08'00' Eni US Operating Co, Inc WELL LOG/DATA TRANSMITTAL To: ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽ 333 W. 7th Ave, Anchorage, AK 99501 Well:ODSN-29 LWD/MWD Logs PDF LAS DLIS Excel Drilling Mechanics Depth Drilling_Mechanics Time ScopeService RM 2" & 5" ScopeServices RM MD X X 2" & 5" ScopeServices RM TVD X X ASP Final Survey X X Composite Log X X Drilling data 158-15716 TD X Density X Mudlogs (Halliburton) 2" & 5" MD Formation Evaluation Log X X 2" MD Drilling Evaluation Log X X 2" MD Gas Ratio Log X X E-line logs 9-5/8" Multi-Finger Imaging Tool Casing 9-5/8" Multi-Finger Imaging Tool Liner 9-5/8" Radial Cement Bond Log 9-5/8" Bottom Hole Pressure Survey 9-5/8" Micro DLS Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Edgar Pinzon Mail: edgar.pinzon@eni.com Received By: ___________________________________Date:____________ Eni US Operating Co, Inc. August 13, 2024 212-106 T39400 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.13 10:31:08 -08'00' Eni US Operating Co, Inc WELL LOG/DATA TRANSMITTAL To: Alaska Oil and Gas ConservaƟon Commissio 333 W. 7th Ave, Anchorage, AK 99501 January 11, 2023 Well:ODSNͲ29 Oooguruk Field LWD/MWD Logs PDF LAS DLIS Excel Mudlogs EͲline logs 7" Multiginger Caliper Log x x PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Edgar Pinzon Mail: edgar.pinzon@eni.com Received By: ___________________________________Date:____________ Eni US Operating Co, Inc. By Meredith Guhl at 8:36 am, Jan 11, 2023 212-106 T37433 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.11 08:38:06 -09'00' 1 Regg, James B (OGC) From:Mbx ODSDrilling <ODSDrilling@eni.com> Sent:Monday, November 21, 2022 7:41 PM To:DOA AOGCC Prudhoe Bay Cc:Pierfelici Stefano; Carballo Nelson Subject:Bops used to prevent the flow of well bore fluids Report Contents 11 21 2022 00:30 HRS. ODSN 29 / ODS 212 106 / Sundry 322 448 Nabors 19AC ODS Drilling supervisor 907 670 6606 Trip in hole with Upper Completion, 8363md Annular Preventer, Choke manifold, Kill Line, FOSV Reason for closing in well do to Crude oil Migration by way of Annulus A. Install FOSV, and Close. Closed Annular Preventer to Perform Bull head operation. completed / Hanger Landed and tested / Packer set and tested / Well bore secured. Bops test tested on 11 14 2022 Craig Smith ODS Drilling Supervisor Office 907 670 6606 Cell 208 816 6803 ---------------------------------------------------------------------------------------------------------------------------------------------------- -------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: isolate Kuparuk and open Nuiqsut__ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 15,716 feet 8,595 feet true vertical 6,430 feet N/A feet Effective Depth measured 15,706 feet See attachment, pg. 3 feet true vertical 6,430 feet See attachment, pg. 3 feet 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"6.4 ppf L-80 8473' 6246' Packers and SSSV (type, measured and true vertical depth)See attachment, pg. 3 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Nuiqsut Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Stefano Pierfelici 12/15/2022 Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Well Operations Project Manager Contact Phone: measured TVD Production Liner 3,314' 9,721' Collapse N/A 3,180 psi 3,090 psi 5,410 psi N/A 5,830 psi 5,750 psi 7,240 psi Plugs Junk measured N/A Length 115' 4,101' 158'Conductor Surface Intermediate 16" 11-3/4" Size 158' 9-5/8" 8,430 psi 7" 6,182' Casing MF Caliper 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 355036 / ADL 389958 Oooguruk - Nuiqsut Oil Pool / Kuparuk Oil Pool STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 212-106 50-703-20661-00-00 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 3. Address: ODSN-29 Eni US Operating Co. Inc MD 1246 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 1186 3821236 Structural 5,506' 6,430' 4-1/2" 7,238' 9,759' 15706 6430 4,140'3,544' Burst 322-448 Sr Pet Eng: 7,500 psi Sr Pet Geo:Sr Res Eng: WINJ WAG 419 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf 102 1164190 300 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 1026 Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3379 p k ft t Fra O s 212 6. A G L PG , _ Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Stefano Pierfelici By Anne Prysunka at 9:45 am, Dec 19, 2022 Top (MD)Top (TVD) 10,179 6,445 10,336 6,444 10,750 6,433 10,909 6,430 11,379 6,415 11,537 6,410 12,231 6,407 12,389 6,409 12,903 6,415 13,059 6,409 13,726 6,417 13,883 6,423 14,263 6,425 14,421 6,428 14,786 6,429 14,944 6,431 10,410 6,442 11,067 6,427 11,612 6,408 12,506 6,409 13,217 6,402 13,957 6,423 14,495 6,428 15,102 6,432 15,644 6,429 15,698 6,430 Baker Multi-Point Frac Sleeve w/segmented ball seat Baker Multi-Point Frac Sleeve w/solid ball seat Baker Multi-Point Frac Sleeve w/solid ball seat Baker Multi-Point Frac Sleeve w/solid ball seat Baker Multi-Point Frac Sleeve w/segmented ball seat Baker Multi-Point Frac Sleeve w/solid ball seat Baker Multi-Point Frac Sleeve w/solid ball seat Baker Multi-Point Frac Sleeve w/solid ball seat Baker Multi-Point Frac Sleeve w/solid ball seat Baker Multi-Point Frac Sleeve w/solid ball seat Baker Multi-Point Frac Sleeve w/segmented ball seat Baker Multi-Point Frac Sleeve w/segmented ball seat Baker Multi-Point Frac Sleeve w/segmented ball seat Baker Multi-Point Frac Sleeve w/segmented ball seat Baker Multi-Point Frac Sleeve w/segmented ball seat Pressure Activated Sleeve B Pressure Activated Sleeve A Attachment 2 Sundry Application Box 11 - Perforation Locations Well: ODSN-29 Baker Multi-Point Frac Sleeve w/segmented ball seat Baker Multi-Point Frac Sleeve w/segmented ball seat Baker Multi-Point Frac Sleeve w/segmented ball seat AOGCC Form 10-403 Baker Multi-Point Frac Sleeve w/segmented ball seat Baker Multi-Point Frac Sleeve w/segmented ball seat Baker Multi-Point Frac Sleeve w/segmented ball seat Baker Multi-Point Frac Sleeve w/segmented ball seat Baker Multi-Point Frac Sleeve w/segmented ball seat Baker Multi-Point Frac Sleeve w/segmented ball seat SSSV MD TVD 2-7/8" Schlumberger TRMAXX-5E 2,083 2,021 PACKERS 3-1/2" x 7" SLB Bluepack Packer 8,028 5,999 9,524 6,413 9,949 6,364 10,647 6,365 11,178 6,367 12,017 6,366 12,701 6,355 13,370 6,355 13,508 6,354 14,110 6,343 14,648 6,344 15,249 6,345 Baker ECP Packer Baker ECP Packer Baker ECP Packer Baker ECP Packer Baker ECP Packer Baker ECP Packer Baker ECP Packer Attachment 3 Baker ECP Packer 5" x 7" Baker ZXP Liner Top Packer Baker ECP Packer Baker ECP Packer AOGCC Form 10-403 Application for Sundry Box 11 - Packers & SSSV Well: ODSN-29 158' 16" Conductor ODSN-29 Nuiqsut Producer As Run 2022-11-22 Kuparuk C Perforation 8263-8332' 6-1/8" TD 15716' (6430' TVD) 13470' FaultFailed ECP 9759' (6430' TVD) 7" 26# L80 BTC-M/TH521 7238' (5506' TVD) 9-5/8" 40# L80 TH521 4140' (3544' TVD) 11-3/4" 60# L80 BTC 9524' (6413' TVD) BHI LTP/HGR 15' TBR 11980' Fault Lower Completion MD TVD BHI ECP 9949 6436 BHI Multi-Point Frac Sleeve (3.000 ball/2.948 seat) 10179 6445 Resman Tracer Carrier 10253 6445 BHI Multi-Point Frac Sleeve (3.000 ball/2.948 seat) 10336 6444 BHI Multi-Point Frac Sleeve (3.000 ball/2.948 seat) 10411 6442 BHI ECP 10647 6434 BHI Multi-Point Frac Sleeve (2.938 ball/2.885 seat) 10750 6433 Resman Tracer Carrier 10836 6431 BHI Multi-Point Frac Sleeve (2.938 ball/2.885 seat) 10909 6340 Resman Tracer Carrier 10985 6429 BHI Multi-Point Frac Sleeve (2.938 ball/2.885 seat) 11067 6427 BHI ECP (Failed) 11178 6423 BHI Multi-Point Frac Sleeve (2.875 ball/2.823 seat) 11379 6415 Resman Tracer Carrier 11454 6413 BHI Multi-Point Frac Sleeve (2.875 ball/2.823 seat) 11537 6410 BHI Multi-Point Frac Sleeve (2.875 ball/2.823 seat) 11612 6408 4-1/2" 13.5# Liner w/2 HLB slide on centralizers 11756 6407 BHI ECP 12017 6407 BHI Multi-Point Frac Sleeve (2.813 ball/2.760 seat) 12231 6407 Resman Tracer Carrier 12306 6408 BHI Multi-Point Frac Sleeve (2.813 ball/2.760 seat) 12389 6409 BHI Multi-Point Frac Sleeve (2.813 ball/2.760 seat) 12506 6409 BHI ECP 12701 6416 BHI Multi-Point Frac Sleeve (2.750 ball/2.698 seat) 12903 6415 Resman Tracer Carrier 12977 6412 BHI Multi-Point Frac Sleeve (2.750 ball/2.698 seat) 13059 6409 Resman Tracer Carrier 13134 6405 BHI Multi-Point Frac Sleeve (2.750 ball/2.698 seat) 13217 6402 BHI ECP 13370 6402 BHI ECP 13508 6408 BHI Multi-Point Frac Sleeve (2.688 ball/2.635 seat) 13726 6417 Resman Tracer Carrier 13801 6420 BHI Multi-Point Frac Sleeve (2.688 ball/2.635 seat) 13883 6423 BHI Multi-Point Frac Sleeve (2.688 ball/2.635 seat) 13957 6423 BHI ECP 14110 6424 BHI Multi-Point Frac Sleeve (2.625 ball/2.573 seat) 14263 6425 Resman Tracer Carrier 14339 6426 BHI Multi-Point Frac Sleeve (2.625 ball/2.573 seat) 14421 6428 BHI Multi-Point Frac Sleeve (2.625 ball/2.573 seat) 14495 6428 BHI ECP 14648 6427 BHI Multi-Point Frac Sleeve (2.563 ball/2.510 seat) 14786 6429 Resman Tracer Carrier 14862 6430 BHI Multi-Point Frac Sleeve (2.563 ball/2.510 seat) 14944 6431 Resman Tracer Carrier 15020 6431 BHI Multi-Point Frac Sleeve (2.563 ball/2.510 seat) 15102 6432 BHI ECP 15249 6432 Resman Tracer Carrier 15469 6431 Pressure Activated Sleeve "B" 5800 psi 15644 6430 Pressure Activated Sleeve "B" 5800 psi 15698 6430 Wellbore Isolation Valve "WIV" 15700 6430 9538' 3-½” 9.2# L80 TCII Middle Completion (2017) 8595' XN Nipple, 2.812, 2.75 No-Go 8515' SS (Down to Open), 2.812 X Closed 4-½” 13.5 L80 TH521 15706' (6430' TVD) Completion: 2-7/8" 6.4# L80 TH Blue ID 2.441" Wellhead: Vault MB233 2012-12-09 D&C 2017-09-07 Recomplete w/Kuparuk 2022-11-22 Plug Kuparuk & Recomplete 3924' TOL 8465' (6243' TVD) LTP/HGR 10' TBR Fish: BHI Premier Packer Slip (1) (2022-10) 8340' Bottom of Straddle Packer 8253' Top of Straddle Packer, ID 4.00" (2022-11) SSSV GL GL 8473' Bottom of Upper Completion 8038' XN Nipple, 2.205 No-Go 8028' Packer, SLB Bluepack Max RH 7939' Solid Gauge Mandrel 8036' XO, 3-½” 9.2# L80 TH511 B x 2-7/8" 6.4# L80 TH Blue P 7898' XO, 2-7/8" 6.4# L80 TH Blue B x 3-½” 9.2# L80 TH511 P x ID 2.992 7855' GLM #1 5/16 Orifice Valve 2181' X Nipple 2131' GLM #2, SLB KBMM-R DV 2083' TRSV, TRMAXX, 2.312 X Profile 103' XO 3-½ 9.4# L80 TH Blue B x 2-7/8 6.4 L80 TH Blue P 7249' Est. TOC CBL 2017-9 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/1/2022 Report #: 1 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 27.5 Wind N at 14 MPH Days LTI (days) Days RI (days) POB 53.0 Daily Summary Operations 24h Forecast Cont. Rigging up, Install BPV and blanking plug. Nipple down tree, Nipple up BOPs and Test 250/ 3,500, Rig up Halliburton slick line, 24h Summary Move rig over ODSN-29. Berm rig. Cont.rigging up. Operation at 07.00 Nippling down tree. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 15:00 18:00 3.00 3.00 MOB A 1 P Rig off Hi-Line power at 15:00 and on rig power, secure upper skate, place rig matt's, Raise landings and stairs, disconnect lines in Putz, clean well bay, warm up hydraulic moving system and function test. Rig accepted 15:01 hrs. 10-1-2022. 18:00 20:00 2.00 5.00 MOB A 2 P Move rig F/ ODSN-31 to ODSN-29. 20:00 00:00 4.00 9.00 MOB A 2 P Rig up level sub and pits, put interconnect and landings down, Berm rig, lower skate down and bolt, lower steps down and bolt. Move Koomey and Geolog shack. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push Ryan Beard Nabors Tool Pusher Ryan.Beard@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/2/2022 Report #: 2 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 28.4 Wind ENE @ 13 MPH Days LTI (days) Days RI (days) POB 50.0 Daily Summary Operations 24h Forecast Continue nipple up of BOPE and test 250 psi low & 3,500 psi high. Nipple up wire line flange, rig up Halliburton slick line, perform slick line operations. 24h Summary Continue rigging up, bull head down tubing, install BPV and blanking plug, Nipple down tree, Nipple up BOPE. Operation at 07.00 Testing BOPs. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 MOB A 5 P R/U service lines in Putz and suitcase. Set pedestal and pin beaver slide. Plug in BOPE accumulator and Geolog unit. Rig back on highline power at 00:40. 02:00 03:00 1.00 3.00 W.O. M 7 P Rig up and bleed off 250 psi of tubing pressure through choke manifold and full poor boy degasser to 0 psi. Annulus A pressure 1,500 psi. Annulus B pressure 600 psi. 03:00 04:00 1.00 4.00 W.O. M 9 P Line up rig pumps and bullhead tubing @ 4 bpm, 850 psi, with 110 bbl. of 8.6 ppg 3% KCL brine. 04:00 12:00 8.00 12.00 W.O. M 20 P Monitor tubing pressure while bleeding off annulus A to bleed trailer. Initial annulus A pressure 1,500 psi. final 1,000 psi. perform DROPS inspection of derrick, top drive, rig floor, and cellar. Paint in cellar. Weld stabilizer bushing on agitator in mud pits. 12:00 18:00 6.00 18.00 W.O. M 1 P R/U Annulus -A to production test header and continue bleeding pressure from 1,000 psi to 0 psi, shut in and monitor pressures for 15 min. Tubing 0 psi, Annulus A 0 psi. Annulus B 600 psi. Cont. painting in cellar. Cont. welding toe boards on pump room landing. 18:00 00:00 6.00 24.00 W.O. C 5 P Install BPV, install blanking plug. Nipple down tree, nipple up BOPs. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push Ryan Beard Nabors Tool Pusher Ryan.Beard@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/3/2022 Report #: 3 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 26.8 Wind E @ 15 MPH Days LTI (days) Days RI (days) POB 55.0 Daily Summary Operations 24h Forecast Perform Halliburton slick line operations. 24h Summary Continue nippling up BOPs and test 250/3,500 psi, (all test good). Rig up Halliburton slick line pressure control tools and equipment. Operation at 07.00 Halliburton slick line operations. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. C 5 P Nipple up BOPs. Rig up Koomey lines to BOP stack, charge Koomey unit, secure BOP with turnbuckles. 01:30 02:30 1.00 2.50 W.O. C 20 P Fill BOP stack with fluid. Work air out of system and perform shell test to 2,500 psi. (good test). 02:30 08:30 6.00 8.50 W.O. C 12 P Test BOPs with 3.5" & 4” test jt to 250 PSI low, 3,500 PSI high. Test annular to 250 psi low, 3,500 PSI high. as per AOGCC requirements. Test upper and lower IBOP, 4" FOSV and 4" dart, 2 7/8" x 5" UPR, blind shear rams, 2 7/8" x 5" LPR, choke valves 1-15, super choke and manually operated choke, choke and kill HCR's and manuals, demco on kill line. All test were good. Test PVT and gas alarms (good). Perform accumulator draw down test, accumulator pressure 3,000 psi. After function 1,700 psi, 200 psi recovery 12 sec. Full recovery 60 sec. 6 bottle avg. 2,133psi. (AOGCC Witness Waived Guy Cook 10-2- 2022 @ 9:10 pm) 08:30 09:30 1.00 9.50 W.O. C 5 P Rig down/blow down test equip. Pull blanking plug 09:30 11:00 1.50 11.00 W.O. M 9 P Bull head down tubing with 110 bbls 8.6 ppg 3% KCL brine @ 2.5 bpm, 130 psi thru BPV with blind rams shut. 11:00 12:00 1.00 12.00 W.O. C 5 P 'Well on vac, remove BPV as per Vault rep. Monitor well (on vac). 12:00 20:00 8.00 20.00 W.O. M 1 P Bring up Halliburton slick line pressure control tools and equipment to the rig floor. Install shooting flange. 20:00 00:00 4.00 24.00 W.O. M 5 P Plan changed, nipple down shooting flange and install flow riser, install newly bored out 2.876" ID 3-1/2" landing joint and XO. Make up landing joint to tubing hanger. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push Ryan Beard Nabors Tool Pusher Ryan.Beard@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/4/2022 Report #: 4 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) 23.9 Wind E @ 5 MPH Days LTI (days) Days RI (days) POB 65.0 Daily Summary Operations 24h Forecast RIH with Halliburton Slickline to set Dummy valve in GLM #1 and change over to E-line operations. 24h Summary Run in hole with Slickline to TRSCSSSV to confirm it is open and POOH. RIH with gauge ring 2.85" to 8,397' wlm and POOH. RIH with PX Plug and set at 8,230' wlm. Pull OV from GLM #1 at 8,397' wlm. Operation at 07.00 Rig down Halliburton Slickline and Rig up E-line. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:00 3.00 3.00 W.O. R 5 P Rig up Halliburton full pressure control tools and equipment, Slick line jumped the upper sheave before picking lubricator off pipe ramp. Cut line and rehead rope socket. Pick up lubricator Pressure test lubricator to 2,500 psi (Good Test). 03:00 05:00 2.00 5.00 W.O. R 15 P Trip in the hole with BHA #1 to 2,106' wlm and confirm position of TRSCSSSV. Trip out of the hole and inspect flapper checker. (TRSCSSSV in fully open position) Pump 5 bbl. Every hour down the tubing. 05:00 07:30 2.50 7.50 W.O. R 15 P Run in the hole with BHA #2 2.85" Gauge ring and brush to 8,397' wlm, POOH same. Pump 5 bbl. Every hour down the tubing. 07:30 11:30 4.00 11.50 W.O. R 15 P Make up BHA #3 PX plug body and trip in hole. Take weight at 2,106 wlm (TRSCSSSV) attempt to work free. Pop off PX plug and POOH. Make up PXP body retrieval tool, trip in hole and latch up to PX plug body. Work free and POOH to surface. Inspect PX plug and observed no damage. Pump 5 bbl. Every hour down the tubing. 11:30 18:00 6.50 18.00 W.O. R 15 P Change BHA to trip in hole with PX plug. Trip in hole to 8,230' wlm and set PX plug in X-nipple. Shear off and POOH. Change BHA and trip in hole with prong to 8,230' wlm and set prong in plug body. Pump 5 bbl. Every hour down the tubing. 18:00 21:00 3.00 21.00 W.O. R 15 P Fill tubing with Clean 8.6 ppg 3% KCL, Pressure test tubing from 8,230' wlm to 2,500 psi for 15 charted min. (good test) 21:00 00:00 3.00 24.00 W.O. R 1 P Change out BHA tools to retrieve OV in GLM #1. Pressure up on Tubing 450 psi. While Slickline removed OV from GLM #1 at 7,950' wlm, Witness Tubing pressure drop to psi=0, Continue Pumping 1 bpm While SlickLine pulls out of the hole. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push Robert Madson Nabors Tool Pusher Robert.madson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/5/2022 Report #: 5 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 33.8 Wind S @ 9 MPH Days LTI (days) Days RI (days) POB 62.0 Daily Summary Operations 24h Forecast Trip in hole and cut Baker premier packer. Trip out of the hole, rig down wireline equipment and rig up to pull upper completion. Pull upper completion. 24h Summary Halliburton Slickline POOH with OV from GLM #1. Fluid pack and combo test tubing and A annulus, good test. Run in hole with Dummy valve and set in GLM #1, POOH. TIH with Sliding sleeve tool and open sleeve at 8,133' slm. Bullhead thru sliding sleeve. Switch to E-line equipment and make up CCL. TIH to locate cut zone, POOH. Make up mechanical cutter and stab on well. Operation at 07.00 Rig down E-line and prep to pull completion. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. R 15 P Continue to trip out of the hole with OV from GLM #1. Break and lay down lubricator on pipe skate change out pack off. 01:00 03:00 2.00 3.00 W.O. R 12 P Fluid pack 3-1/2" X 7" tubing and A Annulus, pumping down tubing taking returns thru choke manifold and full poor boy. Pump 177 bbl at 5 bpm, 900psi. Shut in choke manifold and combo test 3-1/2" X 7" to 2,500 psi for 15 charted minutes (good test). Blow down lines. 03:00 06:00 3.00 6.00 W.O. R 5 P Picked up Halliburton lubricator and tested to 2,500 psi, good test. Once stabbed on with Slickline BOPE, operator was unable to lower tools down. Removed lubricator from BOPs and lower to rig floor. Slickline jumped the upper sheave before picking lubricator off pipe ramp. Cut line and rehead rope socket. Pick up lubricator and pressure test to 2,500 psi (Good Test). 06:00 11:00 5.00 11.00 W.O. R 15 P Trip in the hole with DV and set in GLM #1 at 7,850' wlm.Trip out of the hole to surface. Fill tubing with 5 bbls/30 min. 11:00 15:00 4.00 15.00 W.O. R 15 P Remove lubricator and change out BHA to sliding sleeve function tool. RIH to 8,133' wlm and pressure up tubing to 500 psi. Shift sleeve open and observe pressure drop. Release from sliding sleeve and pull up the hole to 250' above all completion components. Bullhead tubing thru sliding sleeve to Kuparuk formation with 5 BPM, 0 psi. while Trip out of the hole with Slickline to surface. Bullhead 110 total bbls 8.6# 3% KCL. 15:00 18:00 3.00 18.00 W.O. R 5 P Remove lubricator, rig down wireline, and switch to E-line. Clear and organize rig floor. Continue painting projects in centrifugal room, and cellar. Continue welding doors and hole covers. Fill tubing with 10 bbls/hr. 18:00 22:30 4.50 22.50 W.O. R 15 P Make up CCL, 24 MFC, GR log tool, Stab Lubricator Pressure test to 1,500 psi (good test), Trip in the hole to locate packer cut zone. POOH. Packer Cut zone as agreed upon at 8,085.1' elm. 22:30 00:00 1.50 24.00 W.O. R 5 P Make up CCL, Welltec Mechanical Cutter, Stab Lubricator and pressure test 1,500 psi, good test. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push Robert Madson Nabors Tool Pusher Robert.madson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/6/2022 Report #: 6 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) 32.0 Wind SE @ 18 MPH Days LTI (days) Days RI (days) POB 65.0 Daily Summary Operations 24h Forecast Continue to rig down Halliburton E-Line tools and equipment. Pull hanger. Circulate and bull head. Lay down completion. 24h Summary Trip in the hole with Welltec mechanical Cutter and GR log to correlate packer cut zone with depths. POOH, rig down E-line equipment and rig up to pull upper completion. Trip in the hole correlate packer cutting depth with previous run at 8,086 elm (Cut packer slips 8,065.1 - 8,086). Trip out of the hole. Operation at 07.00 Working tubing string to free packer slips and element and begin pulling completion string. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 05:00 5.00 5.00 W.O. R 15 P Make up E-line CCL and Welltec Mechanical Cutter. Trip in the hole correlate packer cutting depth with previous run at 8,085.1 elm (Cut packer slips at 01:40 hrs.). Trip out of the hole. Break and lay down Tools. Pump 5 bbl. 8.6 ppg 3% KCL down tubing every hour. 05:00 06:00 1.00 6.00 W.O. R 5 P PJSM- Rig down Halliburton E-Line Pressure control tools and equipment. Pump 5 bbl. 8.6 ppg 3% KCL down tubing every hour. 06:00 07:00 1.00 7.00 W.O. C 5 P Change out landing jt and make up to hanger. Back out lock down screws. 07:00 10:00 3.00 10.00 W.O. L 4 P Pick up and unseat hanger with 200k. Work pipe to free packer. Pump 5 bbl. 8.6 ppg 3% KCL down tubing every hour. 10:00 11:00 1.00 11.00 W.O. L 4 P Continue working pipe to release packer, P/U 225K S/O 120K. (No release) Pump 5 bbl. 8.6 ppg 3% KCL down tubing every hour. 11:00 12:30 1.50 12.50 W.O. C 5 P Decision made to land hanger, run in lock down screws, and repeat cut with Welltec cutter. Change out landing jt and make up to hanger. Back out lock down screws. 12:30 14:30 2.00 14.50 W.O. R 5 P Rig up Halliburton wireline valves. String wireline over sheaves. Pump 5 bbl. 8.6 ppg 3% KCL down tubing every hour. 14:30 17:30 3.00 17.50 W.O. R 15 P Run in the hole with WellTec logging tools & log from 8,190' ELM to 7,700' ELM. Continue pulling out of hole. Pump 5 bbl. 8.6 ppg 3% KCL down tubing every hour. 17:30 19:00 1.50 19.00 W.O. R 5 P Test caliper in 3-1/2" pup jt on rig floor. Lay down logging tools. Make up WellTec cutter and logging tools. Pump 5 bbl. 8.6 ppg 3% KCL down tubing every hour. 19:00 00:00 5.00 24.00 W.O. R 1 P Make up E-line CCL and Welltec Mechanical Cutter. Trip in the hole correlate packer cutting depth with previous run at8,086' ELM (Cut packer slips @ 21:30 hrs.) Release Mechanical Cutters Blades and E-Line Correlate over cut zone. Trip out of the hole. Pump 5 bbl. 8.6 ppg 3% KCL down tubing every hour. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push Robert Madson Nabors Tool Pusher Robert.madson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/7/2022 Report #: 7 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) 34.8 Wind ES @ 9 MPH Days LTI (days) Days RI (days) POB 61.0 Daily Summary Operations 24h Forecast Halliburton change over to E-Line from Slickline. TIH and Close Sliding Sleeve. Halliburton Change to E-Line operations and RIH to cut pup joint above packer. Switch over from E-Line to Slickline TIH and open Sliding Sleeve. Rig down Halliburton Tools and Equipment. 24h Summary Continue to rig down Halliburton E-Line tools and Equipment. Pull hanger. Work tubing string and unable to work packer free. Land hanger and rig up Halliburton E-line. Operation at 07.00 Prep to run in hole with tubing plug on Slickline. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. R 5 P PJSM- Rig down Halliburton E-Line tools and equipment. 02:30 06:00 3.50 6.00 W.O. L 4 P Made up Landing joint and pulled hanger free of wellhead with a max pull of 200k. Worked pipe with a PUW=220k SOW=100K. Worked pipe up and down several times with a max pull of 90% from PUW=225k to SOW=70k. Pumped 10 bbls down the tubing every hour. 06:00 06:30 0.50 6.50 W.O. L 9 P Close annular and attempt to bullhead down A annulus. Pump .5 bpm pressure up to 1,980 psi. (Unable to bullhead). 06:30 07:30 1.00 7.50 W.O. R 5 P Change out landing jt and blow down top drive. 07:30 12:00 4.50 12.00 W.O. R 15 P Rig up and RIH with caliper and CCL logging tools on Halliburton E-line to 8,136' ELM. Fill tubing with10 bbls every hour. 12:00 15:00 3.00 15.00 W.O. R 15 P Trip out of the hole with caliper and CCL logging tools. See over pull 800lbs at TRSCSSSV. Pressure up A annulus to 2,500 psi. TRSCSSSV open. Continue to trip out of the hole to surface. Fill tubing with10 bbls every hour. 15:00 18:00 3.00 18.00 W.O. R 15 P Lay down CCL logging tools and caliper. Make up flapper checker and round trip to TRSCSSSV. (TRSCSSSV closed) Re- dress flapper checker and round trip to TRSCSSSV while holding 2,500 psi on A annulus. (TRSCSSSV open). Bleed off A annulus. 18:00 00:00 6.00 24.00 W.O. R 5 P Halliburton Change over from E-Line to Slickline Operations. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push Robert Madson Nabors Tool Pusher Robert.madson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/8/2022 Report #: 8 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 32.4 Wind S @ 7 MPH Days LTI (days) Days RI (days) POB 60.0 Daily Summary Operations 24h Forecast Continue rigging down Halliburton E-line tools and equipment. Pull hanger to the rig floor. Lay down 3-1/2" tubing to the pipe shed. 24h Summary Trip in the hole on Halliburton Slickline and close sliding sleeve. Halliburton Change over to E-Line operations. Trip in the hole and cut pup joint above packer. POOH and rig down Halliburton tools and equipment. Operation at 07.00 Diagnose top drive functions. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. R 5 P PJSM- Halliburton Change over from E-Line to Slickline operations. Pressure test lubricator 1,500 psi (Good test). 01:30 06:00 4.50 6.00 W.O. R 15 P Trip in the hole and close the sliding sleeve at 8,180 SLM. Trip out of the hole and pin was not sheared in Slickline tool. Attempt to fill tubing with 10 bbls. Unable to fill or build pressure. Trip in hole and close sliding sleeve on second run and POOH. Observe pin was sheared on closing tool. 06:00 12:00 6.00 12.00 W.O. R 5 P Rig down Slickline and rig up E-line. Fill tubing with 5 bbls 8.6 PPG 3%KCL every 30 minutes. 12:00 13:00 1.00 13.00 W.O. R 5 P PJSM-Make up Welltec mechanical cutter and stab tools and make up pack off. 13:00 16:30 3.50 16.50 W.O. R 15 P Trip in the hole to 8,075' ELM with cutter and cut 3-1/2" tubing 5' above packer. 16:30 19:30 3.00 19.50 W.O. R 15 P Trip out of the hole with Welltec mechanical cutter to TRSCSSSV. Unable to pass through TRSCSSSV with several attempts. 19:30 22:00 2.50 22.00 W.O. R 15 P Trip in the hole with E-Line to 8,075 ELM. Unable to get past the cut. Pull up the hole to TRSCSSSV and pump down both tubing and A annulus at 2,500 psi to open the TRSCSSSV. Pulled Welltec cutter up past the TRSCSSSV and trip out of the hole to surface. 22:00 23:00 1.00 23.00 W.O. R 1 P PJSM- Rig down Halliburton pressure control tools and equipment off to the side of the rig floor. Change out landing joints. 23:00 00:00 1.00 24.00 W.O. L 4 P Pull 130k to unseat hanger and pull to floor with 110k straight pull. Pulled hanger to rig floor to confirm pipe is free then landed hanger back in well head. Continue rigging down Halliburton tools and equipment from rig floor. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push Robert Madson Nabors Tool Pusher Robert.madson@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/9/2022 Report #: 9 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 30.2 Wind NE @ 12 MPH Days LTI (days) Days RI (days) POB 57.0 Daily Summary Operations 24h Forecast Repair top drive breaking system. Continue to pull out of the hole with 3-1/2" completion string. 24h Summary Rig down Halliburton E-line tools and equipment. Pull hanger to the rig floor. Lay down 3-1/2" tubing from 8,087' to 7,930' MD. Shut down to diagnose top drive breaking system. Operation at 07.00 Diagnose top drive breaking system. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. R 5 P PJSM-Continue rigging down Halliburton tools and pressure control equipment off rig floor. 01:30 02:30 1.00 2.50 W.O. L 5 P PJSM- Rig up GBR / Schlumberger tools and equipment. Prep rig floor and pipe shed to lay down 3-1/2" tubing in the shed. Pump double pipe displacement + 10 bbls every hour. 02:30 04:00 1.50 4.00 W.O. L 4 P Lay down tubing hanger. Connect Tec wire and 1/4" Capillary line to spoolers. Trip out of the hole laying down 3-1/2" tubing to pipe shed from 8,087' md to 7,930' md. Pump double pipe displacement + 10 bbls every hour. 04:00 00:00 20.00 24.00 W.O. L 25 TR04 Shut down to diagnose top drive mechanical braking system isssues. Pump10 bbls every hour. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push Robert Madson Nabors Tool Pusher Robert.madson@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/10/2022 Report #: 10 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 29.7 Wind SW @ 13 MPH Days LTI (days) Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Rig up test equipment and test BOPE. Trip in the hole with 4' Drill pipe to retrieve upper completion packer assembly. 24h Summary Diagnose and repair top drive mechanical breaking system. Review risk assessment and perform pre-operational checks of top drive. Trip out of the hole from 7,930' MD to surface. Clear and clean rig floor. Operation at 07.00 Testing BOPE. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 08:00 8.00 8.00 W.O. L 25 TR04 Diagnose top drive mechanical braking system failure. Fill hole with 10bbls of 8.6 ppg 3% KCL brine every hour. 08:00 09:30 1.50 9.50 W.O. L 25 TR04 Review risk assessment and perform pre-operational checks of top drive, drive system and braking systems. All lube and air pressures correct. Shift draworks from high to low (good test). Fill hole with 10bbls of 8.6 ppg 3% KCL brine every hour. 09:30 10:00 0.50 10.00 W.O. L 5 TR04 Lay down 1 jt of 3-1/2" tubing. 10:00 11:00 1.00 11.00 W.O. L 25 TR04 Install crossover in stump, make top drive connection and hang off blocks. Spool line off of drum, inspect and spool back on drum. Fill hole with 10bbls of 8.6 ppg 3% KCL brine every hour. 11:00 18:00 7.00 18.00 W.O. L 4 P Trip out of the hole laying down tubing to pipe shed from 7,895' md to 3,723' md PUW = 70K, SOW = 68K. 18:00 22:30 4.50 22.50 W.O. L 4 P Continue to trip out of the hole from 3,723' md to surface. Recovered a total of 243 full joints and 1cut joint (9.02'), full clamps = 240, half clamps = 7, stand off clamps = 2. Fill hole with 10bbls of 8.6 ppg 3% KCL brine every hour. 22:30 00:00 1.50 24.00 W.O. L 5 P Clear and clean rig floor of tools and equipment. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push Robert Madson Nabors Tool Pusher Robert.madson@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/11/2022 Report #: 11 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) 25.2 Wind SW @ 23 MPH Days LTI (days) Days RI (days) POB 45.0 Daily Summary Operations 24h Forecast Pull packer free and perform bull head operations. Trip out of the hole and lay down Baker premier packer. Run in hole with clean out BHA. Prep to run Halliburton RTTS. 24h Summary Rig up test equipment. Test BOPE. Run in hole with fishing tools and pull upper completion packer assembly. Operation at 07.00 Pull out of the hole with upper completion packer assembly. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. K 5 P Clear and clean rig floor of tools and equipment. Remove GBR tubing tongs. Pull gauge wire and control line over sheave and remove all clamps from rig floor. 02:00 03:30 1.50 3.50 W.O. C 12 P Rig up test equipment. Fill lines and BOPE stack. Perform shell test to 2,500 psi (Good Test). 03:30 14:30 11.00 14.50 W.O. C 12 P Test BOPE with 2-7/8", 3-1/2" & 4” test jts, 250 PSI low, 3500 PSI high. Annular 250 PSI low, 3500 PSI high. Good tests. Test 2-7/8" x 5" Upper, B/S rams, 2-7/8" x 5" Lower, good tests. Choke valves 1-15 and hydraulic and manual choke. Kill line valve, choke and kill manual and HCR valves. Upper and lower IBOP on top drive. XT-39 FOSV and dart valve. Test PVT and gas alarms. Perform accumulator draw down test, accumulator pressure 3,025 psi,after function1,550 psi, 200 psi recovery 13 sec, full recovery 69 sec, number of N2 bottles 6 total Average pressure 2,208 psi. All good tests. (AOGCC Lou Laubenstein Witness waived 10-10-22 @ 20:44hrs.) 14:30 15:30 1.00 15.50 W.O. C 5 P Rig down test equipment. Install wear bushing and run in lock down screws (ID 6-7/16"). 15:30 18:00 2.50 18.00 W.O. L 5 P Perform PJSM and make up Baker overshot BHA. Fill hole with 8.6 ppg brine 10 bbls every hour. 18:00 20:00 2.00 20.00 W.O. K 4 P Single in the hole with overshot BHA on 4" drill pipe to1,677' md. Fill hole with 8.6 ppg brine 10 bbls every hour. 20:00 23:30 3.50 23.50 W.O. K 4 P Trip in the hole stands from derrick from 1,677' md to 8,080' md. Fill hole with 8.6 ppg brine 10 bbls every hour. Top drive and Derrick inspection prior to jarring operations. 23:30 00:00 0.50 24.00 W.O. K 13 P Check drill string parameters, POW=175k SOW=135k Rpm=20 Free RW=150k. Tag top of fish at 8,080' md, swallowed 2 ft. to 8,082' md. Set 10k down to 125k, pulled to 10k over to 185k slacked off to 125k. Pulled up to 225k wait for jars, straight pull of 300k 1 time. Started Jarring at 80% pulled up to 250k wait for jars, straight pull of 340k working jars at 80% Total jar Hits =20. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/12/2022 Report #: 12 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 27.7 Wind S @ 28 MPH Days LTI (days) Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Phase III weather due to high winds. RIH with BHA #2. RIH with Halliburton E-line to cut packer bottom section of packer slips. Rig down E-Line. Spear upper completion of the fish assembly and POOH. 24h Summary Pull packer assembly free. Bull head A Annulus and Tubing. Trip out of the hole and lay down Baker premier packer. Phase 3 Weather due to high winds. Operation at 07.00 Rigging up Halliburton E-Line. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:00 3.00 3.00 W.O. L 13 P Check drill string parameters, POW=175k SOW=135k Rpm=20 Free RW=150k. Tag top of fish at 8,080' md, swallowed 2 ft. to 8,082' md. Set 10k down to 125k, pulled to 10k over to 185k slacked off to 125k. Pulled up to 225k wait for jars, straight pull of 300k one time. Started Jarring at 80% pulled up to 250k wait for jars, straight pull of 340k working jars at 80%. Total jar Hits =98 Jarred Free with 6k over pull at 181k, Stand back one stand in derrick to 7,990' md. 03:00 05:30 2.50 5.50 W.O. L 9 P PJSM. Bull head A Annuals with 274 bbls 8.6 PPG 3% KCL at 5 bpm and 625 psi. Bull head tubing with 110 bbls 8.6 PPG 3% KCL at 5 bpm and 530 psi. 05:30 06:30 1.00 6.50 W.O. L 25 P PJSM. Conduct derrick and Top drive inspection after jarring operations. Fill pits with 8.6 PPG 3% KCL Brine from RSC. 06:30 13:30 7.00 13.50 W.O. L 4 P PJSM. Complete trip plan checklist and trip out of the hole with BHA Assembly #1 from 7,990' md to BHA. Fill hole double displacement with 8.6 PPG 3% KCL brine and 10 bbls every hour. 13:30 14:30 1.00 14.50 W.O. L 5 P Pull fishing tools and fish to rig floor. Retrieved 5' cut jt and 4.8' of Baker premier packer. Lay down BHA and clean and clear floor. Fill hole with 8.6 PPG 3% KCL brine and 10 bbls every hour. 14:30 00:00 9.50 24.00 W.O. L 22 TW01 Standby due to Phase III conditions (high winds). Expedite spear, WellTec cutter, and wireline crews to NOC. Continue filling hole with 8.6 PPG 3% KCL brine and 10 bbls every hour. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/13/2022 Report #: 13 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 25.9 Wind SW 16 MPH Days LTI (days) Days RI (days) POB 56.0 Daily Summary Operations 24h Forecast Continue to retrieve packer assembly. 24h Summary Phase III weather due to high winds, Make up BHA #2 Trip in hole. Trip in the hole with E-line and cut packer bottom section of packer slips. RIH and spear upper section of the fish assembly. RIH with Welltec cutter to 8,082' MD. Attempt to enter Baker premier packer make 20 attempts. POOH. Make up slimhole wireline 2.37" gauge BHA. Operation at 07.00 RIH with E-Line gauge ring 2.37". Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 W.O. L 22 TW01 Phase III weather due to high winds. Expedite spear, WellTech cutter, and wireline crews to NOC. Filling hole with 8.6 ppg 3% KCL brine 10 bbls every hour. Phase III weather conditions standby has been lifted. 04:00 07:00 3.00 7.00 W.O. L 1 P Expedite Baker Hughes BHA #2 to ODS from Air force pad and load in the pipe shed. ID/OD and strap all tools. Filling hole with 8.6 ppg 3% KCL brine 10 bbls every hour. 07:00 07:30 0.50 7.50 W.O. L 5 P Rig up and Make up BHA #2 (wireline entry guide). Filling hole with 8.6 ppg 3% KCL brine 10 bbls every hour. 07:30 13:00 5.50 13.00 W.O. L 4 P RIH with BHA #2 from surface to 8,072' MD. P/U WT = 186K, S/O WT = 126K. Filling hole with 8.6 ppg 3% KCL brine 10 bbls every hour. 13:00 18:00 5.00 18.00 W.O. L 15 P Rig up E-line and PCE. Make up Welltec cutter and RIH to 8,082' MD. Attempt to enter Baker premier packer ( unsuccessful) make 20 attempts (no go). Filling hole with 8.6 ppg 3% KCL brine 10 bbls every hour. 18:00 19:00 1.00 19.00 W.O. L 15 P Decision made to POOH to surface with E-line and lower drill string 5' closer to top of PKR.Filling hole with 8.6 ppg 3% KCL brine 10 bbls every hour. 19:00 00:00 5.00 24.00 W.O. L 15 P POOH with E-line. Rig down E-line equipment. Pick up to 4" drill pipe in hole and slack off 5' and set slips. Rig up E-line and PCE. Make up slimhole wireline 2.37" gauge BHA. RIH to 8,079' MD. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/14/2022 Report #: 14 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) 26.2 Wind WS 20 MPH Days LTI (days) Days RI (days) POB 55.0 Daily Summary Operations 24h Forecast Rig up shooting flange. Rig up Slickline and RIH with magnet. RIH with debris catcher. 24h Summary Continue to RIH on E-line with 2.37" gauge ring to 8,084' MD. POOH after multiple attempts to enter packer. Bullhead 84 bbls 8.6# 3% KCL fluid. RIH to 8084' with 3.20" LIB. Rig down E-Line and PCE. POOH with drill pipe from 8,079' to surface. Nipple down flow riser and nipple up shooting flange. Operation at 07.00 Prep to RIH on Slickline with magnet to remove junk on top of packer. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:30 4.50 4.50 W.O. L 15 P Continue to RIH with E-line with 2.37" gauge ring to 8,084". After multiple attempts to enter packer failed, pulled out of hole with E-Line. Check drill pipe pressure before breaking down lubricator. 04:30 05:30 1.00 5.50 W.O. L 9 P Bullhead 84 bbls 8.6# 3% KCL fluid at 44 SPM and 440 psi. 05:30 09:00 3.50 9.00 W.O. L 15 P Disconnect lubricator and change configuration of current gauge tool making it completely ridged. RIH to 8,084' and make several attempts to enter packer. Not successful. POOH with E-Line. 09:00 12:00 3.00 12.00 W.O. L 15 P Disconnect Lubricator and change over to 3.20" LIB. RIH to 8,084' and POOH with E-Line. 12:00 15:00 3.00 15.00 W.O. L 5 P Completely rig down E-Line and PCE. Clear from floor and prep for POOH with drill pipe. 15:00 15:30 0.50 15.50 W.O. L 25 P Service rig and install Kelly Hose Armor. 15:30 21:00 5.50 21.00 W.O. L 4 P POOH from 8,079' to surface racking back into derrick and lay down centralizing string mills. Fill 10 bbls per hour plus 2 times displacement with 8.6# 3% KCL. 21:00 22:00 1.00 22.00 W.O. L 5 P Clear rig floor. PJSM for nipple down flow riser and nipple up shooting flange. Add 10 bbls 8.6# 3% KCL fluid per hour. 22:00 00:00 2.00 24.00 W.O. C 5 P Nipple down flow riser and nipple up shooting flange. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/15/2022 Report #: 15 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) 23.4 Wind S 9 MPH Days LTI (days) Days RI (days) POB 52.0 Daily Summary Operations 24h Forecast Phase III conditions due to wind speed exceeding Hovercraft operating limit. Continue Slickline operations to retrieve packer when Hovercraft operations can resume. 24h Summary Rig up Halliburton Slickline and RIH with 3-1/2" magnet assembly to 8,090' WLM. POOH, retrieved 2 lower packer slips. RIH with 3-1/2" magnet assembly #2 to 8,105'' WLM. POOH, retrieve only shavings. Make up 2-1/2" magnet/Gauge and RIH to 8,092'.Unable to pass 8,092'. POOH and recovered only shavings. Operation at 07.00 Phase III conditions. Standby until Hovercraft operations can resume. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 07:00 7.00 7.00 W.O. R 5 P Rig up Halliburton Slickline. Pick up two 8' spacers and install beneath lubricator. Make up full PCE and tool string magnet assembly. Pressure test lubricator, good test. Add 10 bbls 8.6# 3% KCL fluid per hour. 07:00 10:00 3.00 10.00 W.O. R 15 P RIH with 3-1/2" magnet assembly to 8090' WLM. POOH. Retrieved 1 lower packer slip 4-1/16" x 2-1/8" x 3/4". Add 10 bbls 8.6# 3% KCL fluid per hour. 10:00 14:00 4.00 14.00 W.O. R 15 P Run back in hole again with 3-1/2" magnet assembly to 8090' WLM. POOH. Retrieved 1 lower packer slip 4-1/16" x 2-1/8" x 3/4". Add 10 bbls 8.6# 3% KCL fluid per hour. 14:00 18:30 4.50 18.50 W.O. R 15 P RIH again with 3-1/2" magnet assembly to 8090' WLM. POOH. Only metal shavings retrieved. No packer components. Add 10 bbls 8.6# 3% KCL fluid per hour. 18:30 20:30 2.00 20.50 W.O. R 15 P Add 5' lubricator and 5' stem to increase distance between magnet and no-go/centralizer. RIH with 3-1/2" magnet assembly to 8105'' WLM. POOH. Add 10 bbls 8.6# 3% KCL fluid per hour. 20:30 00:00 3.50 24.00 W.O. R 15 P Remove 3-1/2" magnet and Centralizer / no-go. Make up 2-1/2" magnet and RIH to 8092' and tag 13' higher. Can not pass. POOH to check magnet. No packer components, retrieved some shavings. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/16/2022 Report #: 16 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 27.9 Wind NE 37 MPH Days LTI (days) Days RI (days) POB 50.0 Daily Summary Operations 24h Forecast Continue with Slickline operations to remove debris from on top of packer. 24h Summary Secure well and rig floor. Standby due to hovercraft transportation being suspended from high winds. Pump 10 bbls 8.6# 3% KCL fluid every hour. Operation at 07.00 RIH with Halliburton Slickline tapered magnet assembly. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 12:00 12.00 12.00 W.O. L 22 TW01 Secure well and rig floor. Standby due to hovercraft transportation being suspended from high winds. Pump 10 bbls 8.6# 3% KCL fluid every hour. 12:00 00:00 12.00 24.00 W.O. L 22 TW01 Secure well and rig floor. Standby due to hovercraft transportation being suspended from high winds. Pump 10 bbls 8.6# 3% KCL fluid every hour. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/17/2022 Report #: 17 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 29.7 Wind NW 20 MPH Days LTI (days) Days RI (days) POB 50.0 Daily Summary Operations 24h Forecast Continue to RIH with the mill/centralizer BHA. Rig up E-line and RIH with Welltec cutter and make cut. POOH with E-line and rig down. POOH with drill pipe and prepare for BOPE test. 24h Summary RIH with Slickline retrieving tool and tag. POOH, nothing recovered. RIH with sword magnet and POOH. Add stem and magnet and RIH and enter packer inner mandrel. POOH. Rig down Slickline. Nipple down shooting flange. Make up dual mill/centralizer BHA and RIH. Cut and slip drill line. Bullhead down drill pipe and bullhead down A annulus. Operation at 07.00 Prep to RIH with Welltec mechanical cutter. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:00 3.00 3.00 W.O. R 15 P RIH with Slickline Retrieving tool to 8,097' and tag up. Sticky with some over pull. POOH. Recovered nothing. 03:00 06:30 3.50 6.50 W.O. R 15 P Make up Sword Magnet and RIH to 8,097'. POOH. Recovered Shavings. 06:30 10:30 4.00 10.50 W.O. R 15 P Add additional 5' of stem and make up 2-1/2" OD magnet to Slickline. RIH to 8,110' WLM, appears to have entered packer inner mandrel. Fill hole with 10 bbls 8.6 ppg brine every hour. POOH. 10:30 12:00 1.50 12.00 W.O. R 5 P Rig down Slickline. Fill hole with 10 bbls 8.6 ppg brine every hour. 12:00 15:00 3.00 15.00 W.O. L 5 P Nipple down shooting flange from top of annular. Install 11" flange with air boot for flow nipple. Install flow nipple. Fill hole with 10 bbls 8.6 ppg brine every hour. 15:00 15:30 0.50 15.50 W.O. L 5 P Make up dual mill/centralizer BHA and RIH to 40' MD. Fill hole with 10 bbls 8.6 ppg brine every hour. 15:30 17:30 2.00 17.50 W.O. L 4 P RIH with dual mill/centralizer BHA from 40' MD to 2,925' MD. Fill hole with 10 bbls 8.6 ppg brine every hour. 17:30 21:30 4.00 21.50 W.O. L 25 P Cut and slip drill line. Fill hole with 10 bbls 8.6 ppg brine every hour. Service rig. Grease traveling block, crown cluster. 21:30 22:00 0.50 22.00 W.O. L 1 P Crude flowing out of drill pipe. Secure well and rig up to bullhead. 22:00 00:00 2.00 24.00 W.O. L 9 P Bullhead 50 bbls 8.6# 3% KCL down drill pipe at 4 BPM and 200 psi. Shut in drill pipe and bullhead 274 bbls of 8.6# 3% KCL down A annulus at 4 BPM and 820 psi. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/18/2022 Report #: 18 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 27.9 Wind NW 10 MPH Days LTI (days) Days RI (days) POB 48.0 Daily Summary Operations 24h Forecast Continue testing BOPE as per Sundry. RIH with Bull nose and drill pipe to 8,083'. Rig up E-line and make dummy gauge run to enter packer inner mandrel. 24h Summary Continue bull heading A Annulus. RIH with mill/centralizer BHA from 2,925' to 8,083'. Rig up E-Line and RIH with 2-7/8" Welltec cutter to 8,086'. Unable to enter stump and POOH. Rig down PCE, lay down E-Line tools. POOH with drill pipe and lay down Baker string mills BHA. Pull wear bushing and rig up BOPE testing equipment. Test BOPE. Operation at 07.00 Continue testing BOPE. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 00:30 0.50 0.50 W.O. L 9 P Continue bull heading A Annulus at 4 BPM with 825 psi. Total pumped 274 bbls 8.6# 3% KCL. 00:30 01:00 0.50 1.00 W.O. L 5 P Blow down Kill line and set Floor/Crown saver. 01:00 05:00 4.00 5.00 W.O. L 4 P Continue to RIH from 2,925' to 8,083' MD. UPW=184K; DNW=124K. Fill the hole with 10 bbls 8.6# 3% KCL per hour. 05:00 08:00 3.00 8.00 W.O. R 5 P Rig up E-Line. Fill the hole with 10 bbls 8.6# 3% KCL per hour. 08:00 12:00 4.00 12.00 W.O. R 15 P RIH with 2-7/8" Welltec cutter to 8,086'. Unable to enter stump, POOH. Fill the hole with 10 bbls 8.6# 3% KCL per hour. 12:00 14:00 2.00 14.00 W.O. R 5 P Rig down PCE, lay down E-Line tools. Prepare to POOH with drill pipe. Fill the hole with 10 bbls 8.6# 3% KCL per hour. 14:00 19:30 5.50 19.50 W.O. L 4 P Blow down top drive and cement line. POOH with drill pipe. Fill the hole with 10 bbls 8.6# 3% KCL per hour plus 1.5 times pipe displacement. 19:30 20:00 0.50 20.00 W.O. L 5 P Lay down Baker string mills BHA. 20:00 22:00 2.00 22.00 W.O. C 5 P Pull wear bushing and rig up BOPE testing equipment. Fill the hole with 10 bbls 8.6# 3% KCL per hour. 22:00 00:00 2.00 24.00 W.O. C 12 P Test BOPE as per Sundry 250 low / 3500 Psi High. Test with 2 7/8" and 4" test joints. Good tests. Test witnessed by Guy Cook with AOGCC. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/19/2022 Report #: 19 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 26.2 Wind E 8 MPH Days LTI (days) Days RI (days) POB 51.0 Daily Summary Operations 24h Forecast Continue testing BOPE. RIH with reversing circulating junk basket assembly. 24h Summary Testing BOPE equipment as per Sundry. Open lower rams and trapped pressure ejected test joint. Secure well, closing blind/shear rams. Bullhead 1.5 times hole capacity. Safety Stand Down. Continue bull heading. Perform full top drive Drops inspection. Install test plug and open lower ram door for inspection - no observed damage found. Operation at 07.00 Continue testing BOPE. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 08:00 8.00 8.00 W.O. C 12 P Testing BOPE equipment 250 psi low / 3500 psi high as per Sundry. Testing with 2-7/8" and 4" test joints. Testing witness is Guy Cook AOGCC representative. 08:00 08:30 0.50 8.50 W.O. C 12 TR05 Open lower rams and trapped pressure ejected test joint. 08:30 09:30 1.00 9.50 W.O. C 12 TR05 Secure well by closing blind/shear rams. Secure rig floor and make notifications of incident. 09:30 11:00 1.50 11.00 W.O. C 9 P Bullhead 1.5 times hole capacity at 4 BPM with 640 psi. 11:00 12:00 1.00 12.00 W.O. C 20 P Safety Stand down for incident. Discuss heightened awareness on maintaining exclusion zones and housekeeping in work areas. Continue bull heading. Total of 470 bbls 8.6# 3% KCL pumped. 12:00 18:00 6.00 18.00 W.O. C 9 P Fill A annulus with 15 Bbls 8.6# 3% KCL fluid down kill line. Install rotary bushing and lay down test joint. Remove lower and upper IBOP valves from top drive and replace with spares. 18:00 22:00 4.00 22.00 W.O. C 5 P Perform full top drive Drops inspection. Rig up 2" hose from A annulus to Production test header and bleeder hose to bleed trailer. Secure low pressure digital gauge from Production and rig up to A annulus. 22:00 00:00 2.00 24.00 W.O. C 5 TR05 Install test plug and open lower ram door for inspection - no observed damage. Close back up. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/20/2022 Report #: 20 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 26.4 Wind NE 22 MPH Days LTI (days) Days RI (days) POB 50.0 Daily Summary Operations 24h Forecast Phase III weather conditions. Standby, waiting on winds to slow down and Phase III weather to lift. Proceed with BOPE test. Pick up reverse circulating junk basket assembly and RIH. 24h Summary Pick up BOPE testing assembly. Make up to top drive and perform a shell test to 3500 psi, good test. Formulate plan forward for testing BOPE. Continue monitoring casing valve for pressure increase and add 10 bbls 8.6# 3%KCL every hour. Phase III conditions due to high wind preventing Hovercraft's ability to reach ODS. Operation at 07.00 Phase III weather conditions. Standby, waiting on winds to slow down and Phase III weather to lift. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. C 25 P Open lower ram doors and inspect the ram elements, no damage observed. Close doors back up. 02:30 04:00 1.50 4.00 W.O. C 12 P Make up BOPE testing assembly. Make up top drive to test joint and perform Shell test to 3500 psi, good test. Observed gas pressure increasing at 7" casing valve. 04:00 06:00 2.00 6.00 W.O. C 9 P Decision made to bullhead 7" casing. Bullhead 370 bbls of 8.6# 3% KCL at 6 BPM with 812 psi. Shut down and casing valve on vacuum. 06:00 08:00 2.00 8.00 W.O. C 20 P Discussions with Anchorage office to formulate plan forward for testing BOPE. Continue monitoring casing valve for pressure increase. With blind rams closed continue adding 10 bbls 8.6# 3% KCL to 7" casing through secondary kill line every hour. 08:00 12:00 4.00 12.00 W.O. C 22 TW01 Phase III called due to high wind and ice build up preventing Hovercraft's ability to reach ODS. Continue monitoring casing valve for pressure increase. Continue adding 10 bbls 8.6# 3% KCL to 7" casing through secondary kill line every hour. 12:00 00:00 12.00 24.00 W.O. C 22 TW01 Phase III condition. Continue monitoring casing valve for pressure increase. Continue adding 10 bbls 8.6# 3% KCL to 7" casing through secondary kill line every hour. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/21/2022 Report #: 21 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 26.6 Wind EN 32 MPH Days LTI (days) Days RI (days) POB 50.0 Daily Summary Operations 24h Forecast Phase III conditions. Continue monitoring casing valve for pressure increase. Continue adding 10 bbls 8.6# 3% KCL fluid to 7" casing every hour through secondary kill line. When Phase III conditions are lifted will proceed with BOPE test. 24h Summary Phase III conditions. Monitoring casing valve for pressure increase. Continue adding 10 bbls 8.6# 3% KCL fluid to 7" casing every hour through secondary kill line. Operation at 07.00 Phase III weather conditions. Standby, waiting on winds to slow down and Phase III weather to lift. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 12:00 12.00 12.00 W.O. L 22 TW01 Phase III condition. Continue monitoring casing valve for pressure increase. Continue adding 10 bbls 8.6# 3% KCL fluid to 7" casing every hour through secondary kill line. 12:00 00:00 12.00 24.00 W.O. L 22 TW01 Phase III condition. Continue monitoring casing valve for pressure increase. Continue adding 10 bbls 8.6# 3% KCL fluid to 7" casing every hour through secondary kill line. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/22/2022 Report #: 22 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 26.8 Wind E 29 MPH Days LTI (days) Days RI (days) POB 49.0 Daily Summary Operations 24h Forecast Continue with weekly BOPE testing. Pick up reverse circulating junk basket assembly and RIH. Remove debris on top of packer and POOH. 24h Summary Phase III conditions until 10:00 hours. Bullhead 492 bbls down 7" casing. Install TBG hanger in wellhead and run in lock down screws. Perform BOPE body test (good test). Perform BOPE test as per Sundry. Operation at 07.00 Prep to pick up and RIH with reverse circulating basket. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 10:00 10.00 10.00 W.O. L 22 TW01 Phase III conditions. Continue monitoring casing valve for pressure increase. Continue adding 10 bbls 8.6# 3% KCL fluid to 7" casing every hour through secondary kill line. 10:00 12:00 2.00 12.00 W.O. L 1 P Bleed off casing pressure through Production header and monitor casing pressure at digital gauge. Prepare to Bullhead 1.5 times casing volume to top of perforations. 12:00 13:30 1.50 13.50 W.O. L 9 P Bullhead 492 Bbls 8.6# 3% KCL down 7" casing @ 4 BPM with 700 Psi. Stage TBG hanger, BPV, test dart overshot to rig floor while Bull heading. Shut down Bull heading and -11 Psi observed on 7" casing valve. 13:30 14:30 1.00 14.50 W.O. C 12 P Install TBG hanger in wellhead and run in lock down screws. Test hanger seals to 3500 psi witnessed by ENI Company man, good test.. Continue adding 20 bbls 8.6# 3% KCL fluid to 7" casing every hour through secondary kill line. 14:30 18:00 3.50 18.00 W.O. C 5 P Rig High-line power went down. Fired up rig generator #1. Monitor casing pressure while rigging up to test BOPE. During testing rig up an accumulator hose developed a leak. Isolated, replaced and reported. Continue adding 20 bbls 8.6# 3% KCL fluid to 7" casing every hour through secondary kill line. 18:00 20:00 2.00 20.00 W.O. C 5 P Pick up and make up testing assembly. Flood choke and stack with fresh water. Perform body test and observed leak on TIW floor valve. Change out floor valve. Continue adding 20 Bbls 8.6# 3% KCL fluid to 7" casing every hour through secondary kill line. 20:00 21:00 1.00 21.00 W.O. C 12 P Perform BOPE body test to 250 low and 3500 psi, good test. Continue adding 20 bbls 8.6# 3% KCL fluid to 7" casing every hour through secondary kill line. 21:00 00:00 3.00 24.00 W.O. C 12 P Perform weekly BOPE test as per Sundry ; 250/3500 psi. with 2-7/8" and 4" test joints. Test witnessed by Guy Cook with AOGCC. Continue adding 20 bbls 8.6# 3% KCL fluid to 7" casing every hour through secondary kill line while testing BOPE. Continue monitoring pressure at 7" casing valve. At 21:00 Hrs pressure was -3.1 psi. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/23/2022 Report #: 23 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 24.6 Wind E 12 MPH Days LTI (days) 1,150.00 Days RI (days) POB 45.0 Daily Summary Operations 24h Forecast Phase III weather conditions. Continue to POOH with reverse circulating basket BHA. RIH with 2-3/8" mule shoe BHA. 24h Summary Continue testing BOPE. Pull test dart and BPV. Pick up landing joint and pull hanger. Phase III weather conditions protocol implemented. Phase III lifted after 1 hour. Pick up reverse circulating BHA and RIH. Operation at 07.00 Phase III weather conditions. Standby, waiting on winds to slow down and Phase III weather to lift. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. C 12 P Continue testing BOPE with 4" test joint 250 low and 3500 psi high, good tests. K3 valve a Fail / pass, grease and retest, good test. Pull test joint and test blind/shear rams, super choke and manual choke, good tests. Add 20 bbls 8.6# 3% KCL fluid to 7" casing every hour. 01:30 02:30 1.00 2.50 W.O. C 12 P Rig up for testing 2-7/8" test joint. Annular was a fail/pass. Increased closing pressure and passed, good test. Add 20 bbls 8.6# 3% KCL fluid to 7" casing every hour. 02:30 06:00 3.50 6.00 W.O. C 12 P Continue with testing 2-7/8" test joint, good test. Add 20 bbls 8.6# 3% KCL fluid to 7" casing every hour. 06:00 08:30 2.50 8.50 W.O. C 12 P Pull test dart and BPV. Monitor casing pressure. Pick up landing joint and pull hanger-75K to unseat hanger. Add 20 bbls 8.6# 3% KCL fluid to 7" casing every hour. 08:30 11:30 3.00 11.50 W.O. L 5 P PJSM and clear rig floor. Bring reverse circulating junk basket BHA to rig floor. Add 20 bbls 8.6# 3% KCL fluid to 7" casing every hour. 11:30 12:00 0.50 12.00 W.O. L 25 P Service rig. 12:00 13:00 1.00 13.00 W.O. L 20 P Pick up reverse circulating junk basket BHA. Add 20 bbls 8.6# 3% KCL fluid to 7" casing every hour. 13:00 14:00 1.00 14.00 W.O. L 22 TW01 Phase III weather conditions protocol implemented. Nabors rig crew perform WOCRM and IWCFL1 training. Phase III lifted after 1 hour. Add 20 bbls 8.6# 3% KCL fluid to 7" casing every hour. 14:00 18:00 4.00 18.00 W.O. L 25 TS03 Rig down time due to iron roughneck issue. Add 20 bbls 8.6# 3% KCL fluid to 7" casing every hour. 18:00 00:00 6.00 24.00 W.O. L 4 P Pick up reverse circulating junk basket BHA and RIH to 8,084'. Add 20 bbls 8.6# 3% KCL fluid to 7" casing every hour. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/24/2022 Report #: 24 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 24.0 Wind E 18 MPH Days LTI (days) 1,151.00 Days RI (days) POB 49.0 Daily Summary Operations 24h Forecast Run in hole with reverse circulating basket. POOH. Make up 2-3/8" mule shoe assembly and RIH. 24h Summary RIH with junk basket. Bring on mud pumps and tag top of packer 4 times. Crude mixed with Brine to surface, bull head 125% annular volume. POOH with the reverse circulating assembly. 2 hour Phase III weather conditions. Continue POOH and lay down basket. Retrieved 2 packer element rubbers. Re-run the reverse circulating basket. Tag 3 times at 8,086.5 and pump. Bull head DP and A annulus. POOH. Operation at 07.00 Running in the hole with reversing circulating basket at 120' MD. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. L 7 P RIH from 8,084' to 8,086.5' and tag top of packer fish. Bring on mud pumps at 10 BPM with 2550 psi and slack off and gently tag top of packer 4 times. 01:00 03:00 2.00 3.00 W.O. L 9 P Crude mixed with brine to surface. Shut down pumps and line up to bull head A annulus. Bull head 125% annular volume at 4 BPM with 650 psi. 03:00 06:00 3.00 6.00 W.O. L 4 P POOH with the reverse circulating assembly from 8,086' to 4,150'. Fill hole with 20 bbls every hour + pipe displacement. 8.6# 3% KCL. 06:00 08:00 2.00 8.00 W.O. L 22 TW01 Phase III weather conditions protocol implemented. Nabors rig crew perform WOCRM and IWCFL1 training. Fill hole with 20 bbls every hour + pipe displacement. 8.6# 3% KCL. 08:00 10:00 2.00 10.00 W.O. L 4 P Continue to pull out of the hole with the reverse circulating assembly from 4150' to surface. Fill hole with 20 bbls every hour + pipe displacement. 8.6# 3% KCL. 10:00 11:30 1.50 11.50 W.O. L 5 P Break and lay down basket. Clean basket. Retrieved 2 packer element rubbers. 11:30 12:00 0.50 12.00 W.O. L 22 TW01 Phase III weather conditions protocol implemented. Nabors rig crew perform WOCRM and IWCFL1 training. Weather lifted after 30 minutes. 12:00 13:00 1.00 13.00 W.O. L 5 P Re-run the reverse circulating basket. Make up the catcher bushing and burn shoe. 13:00 18:30 5.50 18.50 W.O. L 4 P Run in the hole to 8,084". Fill hole with 20 bbls every hour + pipe displacement. 8.6# 3% KCL. 18:30 19:30 1.00 19.50 W.O. L 7 P Obtain parameters UP wt-195K, Dn wt-125K. Bring pumps up to 10 BPM with 1650 psi. Slack off and tag top of packer fish at 8086.5' three times. 19:30 21:00 1.50 21.00 W.O. L 9 P Crude mixed with Brine to surface. Shut down pumps and line up to bull head DP and A annulus. Bull head one DP volume and 125% annular volume at 5 BPM with 830 psi. Shut down pumps and check pressures. Open annular preventer. 21:00 00:00 3.00 24.00 W.O. L 4 P Blow down top drive and Kill line. POOH. Fill hole with 20 bbls every hour + pipe displacement. 8.6# 3% KCL. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/25/2022 Report #: 25 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 24.0 Wind E 30 MPH Days LTI (days) 1,152.00 Days RI (days) POB 53.0 Daily Summary Operations 24h Forecast Waiting on weather Phase III. POOH with reversing assembly. 24h Summary Pull out of the hole with the reverse circulating assembly #2 from 4057' to 216' MD. Retrieved 2 each metal rings and 1 piece of 2" rubber. Make up catcher and burn shoe and run in the hole with the jet sub. Run in the hole from 155' to 8084'. Make up top drive and tag PKR fish @ 8086.5' Pick up and bring on pumps @ 10 BPM and tag fish. Crude returning to mud pits. Shut down and bull head A annulus. Pump down TD @ 10 BPM and tag top of PKR fish 3 times. Phase III Protocol implemented. Pump 10 bbls every hour down drill pipe to prevent top drive freezing. Nabors rig crew perform WOCRM and IWCFL1 training. Operation at 07.00 Pulling out of the hole with the reverse circulating assembly #3. (Note: back on phase lll conditions at 07:10 AM). Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. L 4 P Pull out of the hole with the reverse circulating assembly #2 from 4057' to 216'. Fill hole with pipe displacement 1.5 times and 20 BPH into the annulus A. B annulus 600 psi, A annulus -1 psi. 02:30 03:30 1.00 3.50 W.O. L 4 P Continue pulling out of the hole to the BHA. Break off burn shoe and catcher bushing. Retrieved 2 each metal rings and 1 piece of 2" rubber. 03:30 04:00 0.50 4.00 W.O. L 25 P Service Iron roughneck and crown. 04:00 05:00 1.00 5.00 W.O. L 4 P Make up BHA #3 catcher and burn shoe and run in the hole with the jet sub, top sub, and oil jars. 05:00 07:00 2.00 7.00 W.O. L 5 P Layed down drill collars due to over torque. 07:00 12:00 5.00 12.00 W.O. L 4 P Run in the hole with BHA #3 from 155' to 8084'. Add 15 bbls of 8.6 ppg brine with 3% KCL every hour. 12:00 16:00 4.00 16.00 W.O. L 19 P Make up TD and tag PKR fish @ 8086.5' Pick up and bring on pumps @ 10 BPM and tag fish. Crude returning to mud pits. Shut down pumps. Bullhead 38 Bbls crude from pits followed by 276 Bbls clean 8.6# 3% KCL down annulus A. Shut down pump and monitor well for 15 minutes. Verified -15 Psi on annulus A gauge. Open annular preventer utilized to bull head. Pump down top drive @ 10 BPM and tag top of PKR fish 3 times. Pull up hole 1 stand DP and rack into derrick. 16:00 00:00 8.00 24.00 W.O. L 22 TW01 Phase III Protocol. Make up top drive to drill string. Add 15 Bbls 8.6# 3% KCL to A annulus every hour. Pump 10 Bbls down DP to prevent top drive from freezing. Limited pit volume available due to Phase III. 420 Bbls total pit volume. 8.6# 3% KCL freezing point is 29 degrees Fahrenheit. Nabors rig crew perform WOCRM and IWCFL1 training. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Jon Castle Nabors HSE John.Castle@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/26/2022 Report #: 26 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 23.0 Wind ENE @ 25 MPH Days LTI (days) 1,153.00 Days RI (days) POB 43.0 Daily Summary Operations 24h Forecast Continue RIH with Spear BHA. Bull head well prior to latching onto packer. Cut/Slip Drilling line. Latch onto packer and unseat, POOH with packer. 24h Summary Phase III Protocol until 04:00 Hrs. Phase III lifted. Pull out of the hole with the BHA from 8086' to 7076'. Phase III waiting on weather for Hovercraft operations to resume. Continue POOH with the BHA from 4061' to BHA. Lay down Baker Reversing BHA (no recovery) and send off rig floor. Bring Spear BHA to rig floor. Pick up/make up Spear fishing BHA and begin running in the hole. Operation at 07.00 Bull heading 8.6# 3% KCL down annulus A. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:30 3.50 3.50 W.O. L 4 P Phase III lifted. Pull out of the hole with the BHA from 8086' to 4061' MD. Add 15 Bbls 8.6# 3% KCL fluid to A annulus every hour plus pipe displacement. 03:30 07:30 4.00 7.50 W.O. L 22 TW01 Phase III Protocol. Top Drive made up to drill string. Add 15 Bbls 8.6# 3% KCL to A annulus every hour, pump 10 bbls down drill pipe every hour to prevent TD freezing. Limited Pit volume available due to Phase III. 420 Bbls total pit volume. Nabors rig crew performing WOCRM and IWCFL1 training. 07:30 13:00 5.50 13.00 W.O. L 22 TW01 Phase III waiting on weather for Hovercraft operations to resume. Add 15 Bbls 8.6# 3% KCL fluid to A annulus every hour. Nabors rig crew continue performing WOCRM and IWCFL1 training. 13:00 16:30 3.50 16.50 W.O. L 4 P Pull out of the hole with the BHA from 4061' to BHA . Add 15 Bbls 8.6# 3% KCL fluid to A annulus every hour plus pipe displacement. 16:30 19:30 3.00 19.50 W.O. L 5 P Brake down the reverse circulating assembly (no recovery). Lay down BHA and clear rig floor. Bring Spear BHA to rig floor. Verify straps and OD/IDs of tools. Add 15 Bbls 8.6# 3% KCL fluid to annulus A. 19:30 00:00 4.50 24.00 W.O. L 20 P Discuss with Anchorage office the options and availability of fishing tools to better retrieve PKR fish. Pick up/make up Spear fishing BHA and begin to run in the hole. Add 15 Bbls 8.6# 3% KCL fluid to A annulus every hour. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/27/2022 Report #: 27 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Partly Cloudy Temperature (°F) 22.1 Wind E @ 17 MPH Days LTI (days) 1,154.00 Days RI (days) POB 41.0 Daily Summary Operations 24h Forecast Continue RIH with 2-3/8" Mule shoe BHA to enter PKR inner mandrel. POOH with Mule shoe assembly. 24h Summary Continue RIH with Spear assembly from 1122' to 8031'. Prepare and Bull head DP and A annulus. Cut and slip 68' of drilling line. Tagged fish @ 8086', ran down 2.5' and set down 10K picked up to 135K and jarred one time. Went back down to 8091' and set down with 20K picked up and had over pull of 5 to 10K, POOH with the spear assembly #1 to surface. No fish recovered. Bull head annulus A with 386 Bbls 8.6# 3% KCL fluid. Break down/lay down Spear BHA. Clear rig floor. Make up 2-3/8" Mule shoe BHA. Operation at 07.00 Working on top drive. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:30 4.50 4.50 W.O. L 4 P Continue RIH with Spear assembly from 1122' to 8031'. Add 15 Bbls 8.6# 3% KCL fluid to A annulus every hour. 04:30 08:00 3.50 8.00 W.O. L 9 P Prepare and bull head DP and A annulus. 103 bbls down drill pipe and 230 bbls down annulus A. Annulus A -1.0 psi, Annulus B 600 psi. 08:00 10:30 2.50 10.50 W.O. L 25 P Cut and slip 68' of drilling line. Continue with filling the annulus with 15 bbls of 8.3 ppg brine with 3% KCL. 10:30 11:30 1.00 11.50 W.O. L 19 P Took parameters of fishing string. UW 200k, DW 120k, ROT UW 170k, ROT DW 130k, RPM 5 with 5.8k torque. Tagged fish @ 8086', ran down 2.5' and set down 10K. Picked up to 135K and jarred one time. Went back down to 8091' and set down with 20K. Picked up and had drag of 5 to10K over pull. 11:30 12:00 0.50 12.00 W.O. L 20 P Observed well and performed a derrick drops inspection. 12:00 19:00 7.00 19.00 W.O. L 4 P Pull out of the hole with the spear assembly #1 from 8050' to surface. No fish recovered 19:00 21:00 2.00 21.00 W.O. L 9 P Bull head annulus A with 386 Bbls 8.6# 3% KCL fluid. 21:00 22:00 1.00 22.00 W.O. L 5 P Break down/lay down Spear BHA. Clear rig floor. Continue with filling annulus A with 15 Bbls of 8.3 ppg brine with 3% KCL. 22:00 23:00 1.00 23.00 W.O. L 20 P Fill mud pits and paint mule shoe for identifying marks after POH. 23:00 23:30 0.50 23.50 W.O. L 25 P Service Top Drive 23:30 00:00 0.50 24.00 W.O. L 5 P Make up 2-3/8" Mule shoe BHA. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/28/2022 Report #: 28 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 19.6 Wind NE @ 23 MPH Days LTI (days) 1,155.00 Days RI (days) POB 42.0 Daily Summary Operations 24h Forecast Continue POOH and lay down 2-3/8" mule shoe assembly and prep for E-line operations. 24h Summary RIH with 2-3/8" mule shoe to 1347'. Repair top drive after making contact with a stand of drill pipe. Inspect TDS, perform derrick inspection. Inspect draw works. Phase 3 weather conditions, RIH with 2-3/8" mule shoe assembly from 1347' to 8002'. Continue RIH from 8002' to 8086' and enter into Inner PKR mandrel to 8118' and set down 10K. Pull out of PKR and repeat with same depth 8118' and set down weight, no issue entering. POOH from 8118' to 6464'. Operation at 07.00 Pulled out of hole to 1074' MD. Currently Phase 3 conditions, waiting on weather. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. L 4 P RIH with 2-3/8" mule shoe to 1347' MD. Add 15 Bbls 8.6# 3% KCL per hour to A annulus. 01:30 12:30 11.00 12.50 W.O. L 25 TR04 Inspect and repair top drive after making contact with a stand of drill pipe @ 1347' MD. Inspect TDS, perform derrick inspection. Inspect draw works. Ran TDS and blocks up and down several times in the derrick. Functioned all components of the TDS (all good). Removed the stand of drill pipe and inspected the pin and box. Add 15 Bbls 8.6# 3% KCL per hour to A annulus. 12:30 15:30 3.00 15.50 W.O. L 22 TW01 Phase 3 weather conditions. All work stopped except non-critical activities. Crews performs preventive maintenance pms and worked on WOCRM and IWCFL1 training. Add 15 Bbls 8.6# 3% KCL per hour to A annulus. 15:30 18:00 2.50 18.00 W.O. L 25 TR04 Waiting on conformation from Nabors that top drive equipment is satisfactorily safe to continue normal operations. Add 15 Bbls 8.6# 3% KCL per hour to A annulus. 18:00 21:30 3.50 21.50 W.O. L 4 P Nabors confirm top drive good for operations, continue operations. RIH with 2-3/8" mule shoe assembly from 1347' to 8002' MD. Add 15 Bbls 8.6# 3% KCL per hour to A annulus. 21:30 23:00 1.50 23.00 W.O. L 20 P Record PU wt = 198K, down wt = 120K. Continue RIH to 8086' and enter into inner PKR mandrel to 8118' and set down 10K. Pull out of PKR and repeat with same depth 8118' and set down 10K weight, no issue entering both times. 23:00 00:00 1.00 24.00 W.O. L 4 P POOH from 8118' to 6464' MD. Add 15 Bbls 8.6# 3% KCL per hour to A annulus plus pipe displacement. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/29/2022 Report #: 29 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 23.4 Wind E @ 25 MPH Days LTI (days) 1,156.00 Days RI (days) POB 42.0 Daily Summary Operations 24h Forecast Perform weekly BOPE test. Rig up E-line with full PCE and RIH to make TBG cut below PKR. POOH and rig down E-line. 24h Summary Continue POOH with 2-3/8" mule shoe assembly from 6468' to 4258'. 'Bull head DP and A annulus with 8.6# 3% KCL fluid. Continue POOH with 2-3/8" Mule Shoe assembly from 4258' to 1074'. Phase 3 weather conditions. Crews working on WCORM & IWCFL1 training. Preventive maintenance PMs & housekeeping. Phase 3 weather conditions suspended. Pull out of the hole with the 2-3/8" mule shoe assembly from 1074' to surface. Lay down BHA. Nipple down flow riser and nipple up shooting flange for E-line operations. Mobilization of Halliburton E-line crew from SID to ODS delayed due to high wind gust to 35 mph at SID. Operation at 07.00 Rigging up to test BOPs. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. L 4 P Continue POOH with 2-3/8" mule shoe assembly from 6468' to 4258' MD. Add 15 Bbls 8.6 ppg with 3% KCL plus pipe displacement. 02:00 03:30 1.50 3.50 W.O. L 9 P Bull head DP and A annulus with 147 Bbls of 8.6# 3% KCL fluid. Monitor well. 03:30 06:00 2.50 6.00 W.O. L 4 P Continue POOH with 2-3/8" mule shoe assembly from 4258' to 1074' MD. Fill hole with 15bbls of 8.6 ppg brine with 3% KCL. 06:00 15:00 9.00 15.00 W.O. L 22 TW01 Phase 3 weather conditions. Rig crew performing WOCRM and IWCFL1 training. Preventive maintenance PMs & housekeeping. 15:00 16:30 1.50 16.50 W.O. L 4 P Phase 3 weather conditions suspended. Pull out of the hole with the 2-3/8" mule shoe assembly from 1074' to surface. Lay down BHA. 16:30 18:00 1.50 18.00 W.O. L 5 P Nipple down flow riser and nipple up shooting flange for E-line operations 18:00 00:00 6.00 24.00 W.O. L 22 TW01 Mobilization of Halliburton E-line crew from SID to ODS delayed due to high wind gust to 35 mph at SID. Rig crew performing WOCRM and IWCFL1 training. Preventive maintenance PMs & housekeeping. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/30/2022 Report #: 30 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 19.0 Wind E @ 19 MPH Days LTI (days) 1,157.00 Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Continue to test E-line PCE. RIH with E-line cutter assembly. Enter PKR and correlate depth. Make cut and POOH. Rig down E-line and make up Baker spear assembly and RIH. 24h Summary Mobilization of Halliburton E-line crew from SID to ODS delayed due to hovercraft not running. N/D shooting flange and N/U riser and flowline. Install tubing hanger, BPV, and test dart. Test hanger seals to 4500 psi with Vault -OK. Make up test assembly. Test BOPE to 250 psi low and 3500 psi high with 2 7/8" and 4" test joints, all test good. Bull head the casing with 395 Bbls 8.6# brine 3% KCL. Rig up E-line PCE equipment and test, pack off failed test. Replace pack off sealing rubbers. Operation at 07.00 Performing WOCRM and IWCFL1 training, rig maintenance, wireline crew rest due to timed out (only one crew). Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 05:00 5.00 5.00 W.O. L 22 TW01 Mobilization of Halliburton E-line crew from SID to ODS delayed due to hovercraft not running. Crews working on WOCRM & IWCFL1 training. Preventive maintenance PMs & housekeeping. 05:00 08:30 3.50 8.50 W.O. L 5 P Nipple down shooting flange and nipple up riser and flowline. Stage hanger to the rig floor. 08:30 11:30 3.00 11.50 W.O. C 12 P Mobilize test assembly to the rig floor. Install tubing hanger, BPV, and test dart. Test hanger seals to 4500 psi with Vault (good test). Make up test assembly. Fill BOP and lines with water. Shell test BOP to 3500 psi, good test. 11:30 16:30 5.00 16.50 W.O. C 12 P PJSM, Test BOPE to 250 psi low and 3500 psi high with 2-7/8" and 4" test joints to AOGCC requirements, all test good. Test witness waived by AOGCC rep Lou Laubenstein on 10-29-22 @ 14:03 hrs. 16:30 19:00 2.50 19.00 W.O. L 9 P Lay down test assembly and bull head 7" casing with 8.6 ppg brine 3% KCL, 395 Bbls @ 4.6 BPM with 950 Psi. casing on vac -1.5 psi. Pull BPV. 19:00 20:00 1.00 20.00 W.O. L 20 P Hold PJSM for rig up and running TBG cutter. Mobilize E-line tools to rig floor. 20:00 22:30 2.50 22.50 W.O. R 20 P Rig up Halliburton E-line PCE equipment, landing joint, FOSV, pump in sub, wireline valves, QTS and pack off. Pressure test PCE - wireline pack off failed at 750 Psi. 22:30 00:00 1.50 24.00 W.O. L 25 TS03 Trouble shoot pack off. Replace pack off sealing rubbers. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 10/31/2022 Report #: 31 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Partly Cloudy Temperature (°F) 9.1 Wind E @ 15 MPH Days LTI (days) 1,158.00 Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Continue pulling hanger and install wear ring. Pick up spear BHA and RIH on drill pipe Latch up fish and POOH. 24h Summary Test E-line pack-off, failed. Rig down pack off and take to Halliburton tool trailer for repair. Welltec and Halliburton crews timed out @ 04:00 hrs. Mobilize pack off to rig floor. M/U and test, good test. RIH with cutter, enter into PKR and RIH to 8140' - bottom of cutter. Stacking weight. Correlate logs. Logged from top of PKR to 8140' and back to above PKR 3 times. Position cutter at 8114' in the up stroke. Make cut at 8114' and POOH with E-line and rig down E-line. Clear rig floor of E-line PCE. Remove landing jnt and hanger. Operation at 07.00 Running in hole with Baker spear BHA on drill pipe. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. R 25 TS03 Continue replacing pack off rubbers. Attempt to test E-line pack-off, failed at 700 Psi. Continue adding 15 Bbls of 8.6# 3% KCL to casing valve every hour 01:30 03:30 2.00 3.50 W.O. R 20 TS03 Re-test E-line pack off, pack off failed at 700 Psi. Rig down pack off and take to Halliburton tool trailer. Service man rider crown sheave. Ice build up, removed and greased sheave. Working smoothly after servicing. Continue adding 15 Bbls of 8.6# 3% KCL to casing valve every hour. 7" casing pressure at 04:00 hrs is -3.2 Psi. 03:30 13:30 10.00 13.50 W.O. L 20 P Welltec and Halliburton crews timed out @ 04:00 hrs. FOSV closed with Night cap on E-line PCE, Continue adding 15 Bbls of 8.6# 3% KCL to 7" casing valve every hour. Crews continue working on WOCRM & IWCFL1 training. Rig maintenance. 13:30 17:00 3.50 17.00 W.O. R 25 TS03 Re-head E-line pack off at Halliburton unit. 17:00 18:00 1.00 18.00 W.O. R 20 P Mobilize pack off to rig floor. M/U and test, good test. 18:00 19:00 1.00 19.00 W.O. R 19 P RIH with Welltec cutter on Halliburton E-line to 8086'. 19:00 20:30 1.50 20.50 W.O. R 19 P Enter into PKR and RIH to 8140' - bottom of cutter. Stacking weight. Correlate logs. Logged from top of PKR to 8140' and back to above PKR 3 times. Position cutter at 8114' in the up stroke (middle 2nd pup joint). Cutter anchor positioned 3' inside bottom of 1st pup joint under PKR. 20:30 23:30 3.00 23.50 W.O. R 20 P Make cut at 8114' and POOH with E-line. At surface inspection of Cutter indicated it opened to 4.2". Rig down and clear floor of PCE. 23:30 00:00 0.50 24.00 W.O. L 5 P Remove landing joint and hanger. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/1/2022 Report #: 32 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) -3.3 Wind Calm Days LTI (days) 1,159.00 Days RI (days) POB 44.0 Daily Summary Operations 24h Forecast Replace blown air boot on flow riser. Continue RIH in hole and latch up onto fish at 8114'. Free fish and POH with fish. 24h Summary Pick up Baker spear assembly and RIH to top of fish @ 8086'. Run in through the fish to 8088' work down to 8090.5'. Pull out of the hole with the spear assembly to surface. Retrieved Fish, Packer + 22' of cut joints. Lay down Spear assembly. Make up 5.75" overshot BHA and RIH to 8094'. Crude overflow DP as slacking off with Drill Pipe. Line up and Bull head DP with 82 Bbls 8.6# 3% KCL and A annulus with187 Bbls. 5.5 BPM with 950 Psi. Operation at 07.00 Jarring on fish. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. L 20 P Make up top drive to landing joint. Verify casing pressure. Back out LDS and pull hanger free at 70K. Lay down hanger and landing joint. Fill casing with 15 Bbls 8.6# 3% KCL fluid every hour. 01:30 03:30 2.00 3.50 W.O. L 20 P Pick up Baker spear assembly as per Baker rep. Fill casing with 15 Bbls 8.6# 3% KCL fluid every hour. 03:30 09:00 5.50 9.00 W.O. L 4 P RIH with Baker spear assembly to top of fish @ 8086'. UW 198K, dW 122K. Annulus A -.9 psi, annulus B - 600 psi. Continue to add 15 BPH 8.6# 3% KCL fluid down the well each hour. 09:00 10:30 1.50 10.50 W.O. L 19 P Run in through the fish to 8088'. Started taking weight. Set 15K down. Picked up 5' and set down again. At 8088' lost 5K weight and ran in to 8090.5'. Set down with 15K. Picked up and worked torque down hole and sat on the fish 2 more times with same results. Continue to add 15 BPH 8.6# 3% KCL fluid down the well each hour. 10:30 17:00 6.50 17.00 W.O. L 4 P Pull out of the hole with the spear assembly to surface. Retrieved Fish, Packer + 22' of cut joints. Continue to add 15 BPH 8.6# 3% KCL to the annulus each hour + pipe displacement. 17:00 18:30 1.50 18.50 W.O. L 5 P Break down fish from the spear assembly. Lay down Spear assembly. Continue to add 15 BPH 8.6# 3% KCL fluid down the well each hour. 18:30 22:30 4.00 22.50 W.O. L 4 P PJSM and make up 5.75" overshot BHA and RIH to top of fish at 8094'. Continue to add 15 BPH 8.6# 3% KCL fluid to A annulus.. 22:30 00:00 1.50 24.00 W.O. L 9 P Running in hole crude overflow drill pipe, line up and bull head drill pipe with 82 Bbls 8.6# 3% KCL and A annulus with 187 Bbls. at 5.5 BPM with 950 Psi. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/2/2022 Report #: 33 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 6.7 Wind S @ 9 MPH Days LTI (days) 1,160.00 Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Continue to monitor drill pipe through gas buster. Add 15 Bbls 8.6# 3% KCL to A annulus every hour. Continue with WOCRM & IWCFL1 training. 24h Summary Finish bull head A annulus. Replace blown lower air boot on upper section flow riser. Tag fish at 8114' and latch up and jarred fish free, pulled out of the hole to 7638'. Observed crude and gas at surface inside the drill pipe. Attempt to bullhead the drill pipe up to 2500 psi. Would not bullhead. Attempt to bullhead the drill pipe up to 4500 psi. Would not bullhead. Bull head A annulus. POOH from 7638' 7652’ MD. Observed crude and gas at surface inside the drill pipe. Rigged up through gas buster and let the gas and crude bleed from the drill pipe. Monitor well. Continue with L1 and WOCRM training. Operation at 07.00 Monitoring well through gas buster. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 00:30 0.50 0.50 W.O. L 20 P Finish bull head A annulus. Blow down kill line. 00:30 03:00 2.50 3.00 W.O. L 25 TS03 Replace blown lower air boot on upper section flow riser. Add 15 Bbls 8.6# 3% KCL to A annulus every hour. 03:00 07:00 4.00 7.00 W.O. L 19 P UP weight 200K; Down weight -122K. Tag fish at 8114' and latch up with 12K down weight. Jar on fish with 290K and straight pull to 335k. Fish came free, pulled out of the hole to 8044'. Add 15 Bbls 8.6# 3% KCL to A annulus every hour. 07:00 08:00 1.00 8.00 W.O. L 20 P Perform post jar inspection on the derrick and Top Drive. Add 15 Bbls 8.6# 3% KCL to A annulus every hour. 08:00 08:30 0.50 8.50 W.O. L 4 P Pull out of the hole with the fish to 7638'. Observed crude and gas at surface inside the drill pipe. 08:30 14:30 6.00 14.50 W.O. L 20 P Attempt several times to bullhead the drill pipe up to 2500 psi. Would not bullhead. Attempted to bullhead through the drill pipe to 4500 psi. Would not circulate. Bullheaded the annulus @ 5 BPM with 900 psi. Broke off TDS and blow down. Monitor well. 14:30 17:00 2.50 17.00 W.O. L 20 P Rigged up through gas buster and let the gas and crude bleed from the drill pipe. No pressure, no gas, no crude. Add 15 Bbls 8.6# 3% KCL to A annulus every hour. 17:00 17:30 0.50 17.50 W.O. L 4 P Pull out of the hole with the fish from 7638' to 7352'. Observed crude and gas at surface inside the drill pipe. 17:30 18:30 1.00 18.50 W.O. L 20 P Rigged up through gas buster and let the gas and crude bleed from the drill pipe. Monitor drill pipe through gas buster. Add 15 Bbls 8.6# 3% KCL to A annulus every hour. 18:30 00:00 5.50 24.00 W.O. L 20 P Continue to monitor drill pipe through gas buster. Add 15 Bbls 8.6# 3% KCL to A annulus every hour. Continue with L1 and WOCRM training. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Mark Ashley ASRC Energy Services Drilling Supv. siddrilling@eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/3/2022 Report #: 34 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 10.7 Wind W @ 7 MPH Days LTI (days) 1,161.00 Days RI (days) POB 49.0 Daily Summary Operations 24h Forecast Pressure test lubricator 3,500 psi, run in hole correlate tool, perforate tubing. Pull out of the hole rig down Halliburton. Bull head tubing Vol + 50%, monitor well bore, Trip out of the hole with drill pipe. Double pipe displacement + 15 bbl. every hour, Break and lay down fishing BHA. 24h Summary Continue to monitor drill pipe through gas buster. Add 15 Bbl. 8.6# 3% KCL to annulus -A every hour. Rig up Halliburton E-line tools and equipment, Rehead E-line socket. Crews continue working on WOCRM & IWCFL1 training. Operation at 07.00 Bull heading well. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 05:00 5.00 5.00 W.O. L 1 P Monitor well, fill hole15 bbl. every hour. Continue house keeping and maintenance projects. Annulus-A 8 psi Annulus-B 600 psi 05:00 08:00 3.00 8.00 W.O. L 9 P Monitor well, return flow meter increased to 17% decision was made to bull head down Annulus-A @ 6 bpm with 975 psi, total stks=3002, monitor well and pits (no flow). 08:00 11:30 3.50 11.50 W.O. L 1 P Monitor well and pits. Fill hole15 bbl. every hour, 11:30 13:30 2.00 13.50 W.O. L 4 P Trip in the hole F/7356' MD to top PBR @ 8,465' MD. Monitor well and pits. Fill hole15 bbl. every hour. 13:30 14:00 0.50 14.00 W.O. L 19 P Rotate drill pipe and attempt to back off and release fish at the PBR @ 8465' MD unable to release fish from over shot. 14:00 20:00 6.00 20.00 W.O. L 1 P Monitor well and pits. Fill hole15 bbl. every hour. Rig maintenance, Clean and organize rig. Crews continue working on WOCRM & IWCFL1 training. 20:00 00:00 4.00 24.00 W.O. R 5 P PJSM - Halliburton rehead E-line socket, Bring up Halliburton tools and equipment to rig floor. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Stefano Pierfelici Eni Drilling Manager Stefano.Pierfelici@enipetroleum.com 907-685-3320 Eni representative Nelson Carballo Eni Drilling Superintendent nelson.carballo@eni.com Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE jack.potter@external.eni.com 907-670-6622 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/4/2022 Report #: 35 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 12.2 Wind E @ 6 MPH Days LTI (days) 1,162.00 Days RI (days) POB 53.0 Daily Summary Operations 24h Forecast Halliburton Slick-Line Operations, Rig down Halliburton same, Cont. laying down upper completion, Make up clean out BHA assembly, Trip in the hole to top PBR at 8,465 MD. 24h Summary Pressure test lubricator 3,500 psi, (good test) Run in hole correlate tool, perforate tubing from 8,104 to 8,109'. Pull out of the hole rig down Halliburton, Bull head Annulus =A 250 bbl. and tubing Vol + 50% 110 bbl. Monitor well bore, Pull out of the hole with E-Line rig down same, Trip out of the hole with drill pipe F/ 8,190 MD to 336 MD. Break lay down fishing BHA assembly, overshot and shot jnt and sliding sleeve. Rig up Halliburton slick line with full pressure control equipment. Operation at 07.00 Rigging down wireline. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:30 3.50 3.50 W.O. R 5 P Cont. rigging up Halliburton E-line BOP's, lubricator and full pressure control equipment. PJSM, pressure test lubricator 3,500 psi (good test). Bleed pressure off and break quick connect make up tubing punch, install back into lubricator and test to 1,500 psi (good test). 03:30 05:30 2.00 5.50 W.O. R 19 P Run in hole correlate tubing punch on 15 ft. pup joint above sliding sleeve from 8,104' to 8,108', fire guns (guns 4 shots per foot). Pull out of the hole with E-Line above BHA, Bull head Tubing with a max rate 6 bpm at 640 psi total 20 bbl. Pumped away. 05:30 07:00 1.50 7.00 W.O. L 9 P Bull head 250 bbl. down Annulus-A. 07:00 10:00 3.00 10.00 W.O. R 20 P Pull out of the hole with Halliburton wireline and rig down. Move wire line equipment off the rig floor. 10:00 11:00 1.00 11.00 W.O. L 9 P Bull head drill pipe with 110 bbl. of 8.6 ppg brine. 11:00 16:00 5.00 16.00 W.O. L 4 P Pull out of the hole F/ 8,190' to 336' MD with fishing assembly. Add 15 bbl./hr. down the annulus + pipe displacement. 16:00 17:30 1.50 17.50 W.O. L 5 P Break and lay down fishing BHA assembly, overshot and shot jnt and sliding sleeve. 17:30 22:30 5.00 22.50 W.O. R 5 P PJSM Halliburton changing over from E-Line to Slick line operations, Hoist and install BOP's and lubricator, full pressure control equipment. Pressure test lubricator 1,500 psi (Good test). Add 15 bbl./hr. down the annulus. 22:30 00:00 1.50 24.00 W.O. R 1 P PJSM, Halliburton slick-Line operations, unable to get magnet ID of a 2.72 through 4' XT-39 x 4.5 IF x-over with a ID of 2.563. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE jack.potter@external.eni.com 907-670-6622 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/5/2022 Report #: 36 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 10.2 Wind SW @ 14 MPH Days LTI (days) 1,163.00 Days RI (days) POB 51.0 Daily Summary Operations 24h Forecast Continue with slickline operations, rig down Halliburton. Continue laying down upper completion, Test BOP's, Make up clean out BHA assembly, Trip in the hole top PBR at 8,465' MD. 24h Summary Halliburton Slick-Line Operations, Operation at 07.00 Laying down fish. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 W.O. R 15 P PJSM, Halliburton Slick-Line operations, Run #1 Magnet OD 2.5" to fish lower packer dies. Working slick-Line with several attempts unable to pass through at 45' WLM with magnet , POOH install gauge ring OD 2.30" Trip in hole stacked out at 45ft. WLM, Decision was made to rig down Halliburton Slick-Line Tools and Equipment. 06:00 14:00 8.00 14.00 W.O. L 1 P Halliburton slick-line crew has timed out, Perform housekeeping and maintenance projects around on rig, Pump down Annulus -A 15 bbl./hr. 8.6 ppg 3% KCL. 14:00 16:30 2.50 16.50 W.O. L 9 P Bull head down Annulus -A 395 bbl. at 45 spm with psi=550 8.6 ppg 3% KCL brine. 16:30 18:00 1.50 18.00 W.O. R 5 P PJSM, Rig up Halliburton slick-Line BOP's, lubricator, pressure control equipment, Test lubricator to 1,500 psi (Good test). 18:00 22:00 4.00 22.00 W.O. R 1 P #1 Run in hole with 2.5" magnet to 42' SLM, pull out of hole with no recovery on magnet, #2 run in hole to 2.5" magnet to 42' WLM, pull out of hole recovered 1 packer slip die. #3 Run in hole the hole with 2.5" magnet to 42' WLM, pull out of hole and recovered 1/4 cup of debris, #4 Run in hole with 2.5" magnet to 42' WLM, pull out of hole and recovered prong F/plug body from XN nipple. #5 run in hole, unable to pull plug body F/Plug from XN-Nipple, Pressure up on tubing 500/1,000 psi unable to break circulation, Pull out of the hole from 45' WLM and inspect GR tool. 22:00 00:00 2.00 24.00 W.O. R 1 P #6 run make up bailer run in hole bail sand and debris from XN-Nipple, pull out of the hole empty bailer recovered 1 full cup of fine sand, Break down clean bailer out, #7 run in hole with bailer to top of plug body in XN-Nipple, pull out of the hole empty bailer, Recovered 2-Cups of sand and debris at 45 WLM. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE jack.potter@external.eni.com 907-670-6622 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/6/2022 Report #: 37 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) 1.9 Wind E @ 10 MPH Days LTI (days) 1,164.00 Days RI (days) POB 55.0 Daily Summary Operations 24h Forecast Rig down test equipment, blow down line lines, Remove landing joint, install wear bushing, Make up clean out BHA assembly, Trip in the hole top PBR at 8,465 MD. 24h Summary Halliburton Slick-Line Operations. Rig down Halliburton slickline, Cont. laying down upper completion, Test BOP's, Operation at 07.00 Picking up clean out BHA. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:00 3.00 3.00 W.O. R 15 P Halliburton Slick-Line Operations, Run #8 Run in hole Latch onto the Plug body at 45ft. WLM several attempt to jar Plug body free from XN-Nipple, Pull out of the hole re-pin Latch Tool, Run # 9 Run in hole 45ft. WLM Latch onto Plug body several attempts, jar free, Pull out of the hole lay down plug body. 03:00 04:00 1.00 4.00 W.O. L 9 P Bull head tubing with 4 bpm 880 psi.Total 75 bbl. pumped away. 04:00 06:00 2.00 6.00 W.O. R 15 P Halliburton Slick-Line Operations, Run #10 Run in hole latch onto the Prong in the lower XN-Nipple at 242' WLM, jarred Prong free. Pull out of the hole, lay down Prong. Run #11 run in the hole and jarred on Plug body at 242' WLM. Did not release. 06:00 08:00 2.00 8.00 W.O. R 5 P Rig down Halliburton wire line equipment and clear the rig floor. Monitor well. 08:00 10:00 2.00 10.00 W.O. L 4 P PJSM. Rig up GBR tongs and equipment. Pull out of the hole with the fish to the blast joints. 10:00 13:00 3.00 13.00 W.O. L 9 P Bull head Annulus-A with 3,000 stks at 560 psi before pulling the blast joints. Monitor well. 13:00 15:30 2.50 15.50 W.O. L 4 P Pull out of the hole laying down fish. Simops test gas alarms with AOGCC Rep Brian Bixby witnessing. 15:30 17:00 1.50 17.00 W.O. L 5 P Rig down GBR and clear the rig floor of non-essential tools and equipment. 17:00 19:30 2.50 19.50 W.O. C 5 P Remove wear bushing. Install hanger, BPV, and dart sub. Test hanger seals (good test). Make up test assembly. 19:30 00:00 4.50 24.00 W.O. M 12 P Test BOPs with 2-7/8 and 4” test jnt. 250 PSI low, 3500 PSI high, annular 250 psi low, 3500 PSI high. per AOGCC requirements. Test 2 7/8 x 5 UPR, B/S rams, 2 7/8 x 5 LPR. Choke valves 1-15, hydraulic and manual choke. Kill line valve, choke and kill manual and HCR valves. Upper and lower IBOP on top drive. XT-39 FOSV and dart valve. Test PVT and gas alarms. Perform accumulator draw down test, accumulator pressure 2,900,after function1,600 ,200 psi recovery 11 sec, full recovery 60 sec, number of N2 bottles 6 total Average pressure 2,192 psi. All tests good. (AOGCC rep Brian Bixby Witness BOP Test) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE jack.potter@external.eni.com 907-670-6622 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/7/2022 Report #: 38 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) 23.0 Wind E @ 7 MPH Days LTI (days) 1,165.00 Days RI (days) POB 54.0 Daily Summary Operations 24h Forecast Cont trip out of the hole F/ 1,792' to surface, Break down lay down BHA assembly. Make up RTTS packer assembly, Trip in hole test casing as per plan, trip out of the hole lay down RTTS packer assembly. 24h Summary Rig down test equipment blow down lines, Remove landing joint, install wear bushing, make up clean out BHA assembly. Trip in the hole to the PBR at 8,465 and polish. Trip out of the hole F/ 8,464' to 1,792' MD. Operation at 07.00 Running in the hole with Halliburton 7" RTTS packer. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. M 12 P Rig down test equipment blow down all lines and test pump. Add 15 bbl. / hour down Annulus-A 02:00 05:30 3.50 5.50 W.O. C 5 P PJSM- Vault Rep, remove BPV. Make up landing to hanger, work hanger free10k to 15k over pull to free, lay down hanger. Install wear bushing. 05:30 07:30 2.00 7.50 W.O. M 4 P PJSM-Pick up over shot break jar and bumper sub off as per Baker Rep, Make up clean out BHA assembly. 07:30 09:00 1.50 9.00 W.O. M 4 P Run in the hole with the clean out assembly F/ 151' to 1688' UW 68K, DW 66K. Observed gas at surface. 09:00 11:30 2.50 11.50 W.O. M 9 P Bullhead Annulus -A 4 bpm at 580 psi, pump total of 20 BBL. down drill pipe. Monitor well ( well went on a vacuum) Blow down lines. 11:30 15:30 4.00 15.50 W.O. M 4 P Run in the hole with the clean out assembly from 1688' to 8,407' MD. 15:30 17:00 1.50 17.00 W.O. M 4 P PJSM Make up top drive s/o/w=128k p/u/w=195k R/t/w=151k Tq=6.2, tag @ 8,470' MD scrape 7" casing F/8,469' to 8,419' MD x 5 times slack off into liner top with a rotary of 20 rpm pumping 2.3 bpm Polished PBR 8,478' MD with 10k down for 1 min, Trip out of the hole to 8,207' MD working 7" casing scraper x3 from 8,200' to 8,365' MD above top perf. 17:00 18:30 1.50 18.50 W.O. M 9 P Bull head drill pipe with 108 bbl at 950 psi, Bull head Annulus -A 234 BBL. at 900 psi, Shut down monitor well. 18:30 00:00 5.50 24.00 W.O. M 4 P PJSM. Trip out of the hole F/ 8,207' to 1,792' MD. Strap drill pipe in derrick, Fill hole15 bbl every hour plus drill pipe displacement. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Jody Cornell ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE jack.potter@external.eni.com 907-670-6622 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/8/2022 Report #: 39 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) 29.5 Wind SE @ 14 MPH Days LTI (days) 1,166.00 Days RI (days) POB 53.0 Daily Summary Operations 24h Forecast Remove flow riser, nipple up shooting flange. Rig up Halliburton E-line tools and equipment and full pressure control equipment. Conduct E-line operations as per plan. 24h Summary Cont. trip out of the hole F/ 1,792' to surface, Break down lay down BHA assembly, Make up packer assembly, Trip in hole test casing as per plan. Trip out of the hole lay down packer assembly. Operation at 07.00 Halliburton E-line operations. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. M 4 P PJSM, trip out of the hole F/ 1.792' to surface strapping drill pipe in derrick. Fill hole15 bbl. every hr. plus drill pipe displacement. 02:00 04:30 2.50 4.50 W.O. M 5 P Break down lay down BHA Jars / Bumper subs, razerback casing scraper, clean magnets. Recovered #5 pounds of metal from magnets. Break and lay down BHA as per Baker Hughes rep. 04:30 07:30 3.00 7.50 W.O. M 4 P PJSM, Pick up / make up Halliburton RTTS 7" 23# test packer, Trip in the hole to 2,515' MD. p/u/w=86k s/o/w=82k 07:30 10:00 2.50 10.00 W.O. M 9 P Bull head down Annulus-A, 4.5 bpm at 580 psi 341 bbls pumped away, bull head drill pipe 4.5 bpm at 460 psi total 38 bbls. Monitor well, went on a Vacuum. 10:00 13:30 3.50 13.50 W.O. M 4 P Cont.trip in the hole F/ 2,515' to 8,260' MD. 13:30 15:00 1.50 15.00 W.O. M 9 P Bull head down Annulus-A with 5.8 bpm, 875 psi, total 190 bbls pumped. 15:00 16:30 1.50 16.50 W.O. M 12 P PJSM, pressure test 7' casing F/ 8,260' MD to surface at 2,500 psi for 30 min charted (Good Test). 16:30 17:00 0.50 17.00 W.O. M 9 P Bull head down drill pipe at 5 bpm, 650 psi. Blow down top drive, monitor well. 17:00 22:30 5.50 22.50 W.O. M 4 P Trip out of the hole F/ 8,260' to surface, Break and lay down RTTS packer. 22:30 23:00 0.50 23.00 W.O. M 4 P Run1 stand of 4-3/4" drill collar in mouse hole break and lay down to pipe shed. 23:00 00:00 1.00 24.00 W.O. C 5 P Remove wear bushing from well head profile as per vault Rep, Add 15 bbl. per hour to well Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Chad Gueco ASRC Energy Services Drilling Supervisor Chad.Gueco@external.eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE jack.potter@external.eni.com 907-670-6622 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/9/2022 Report #: 40 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 23.7 Wind E @ 16 MPH Days LTI (days) 1,167.00 Days RI (days) POB 55.0 Daily Summary Operations 24h Forecast Halliburton E-Line operations. 24h Summary Remove flow riser, nipple up shooting flange, Rig up Halliburton E-Line tools and equipment, perform Halliburton E-Line operations as per plan. Operation at 07.00 Halliburton E-Line operations. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. M 4 P Remove flow riser, install and nipple up shooting flange. Add 15 bbl. per hour to well. 01:00 04:00 3.00 4.00 W.O. R 1 P PJSM, rig up Halliburton E-Line BOPs, function test prior to install, good. Install full pressure control equipment. (Casing showing 58 psi ) Blind rams Closed 04:00 05:00 1.00 5.00 W.O. M 9 P Bull head casing pumping at 5.9 bpm 730 psi, total bbl. 309 pumped away, Monitor well 15 min, Well is on a Vacuum. 05:00 07:30 2.50 7.50 W.O. R 9 P PJSM, Halliburton E-Line fill lubricator pressure test equipment 2,000 psi 10 min. (good test). Bullhead 400 bbl. of 8.6 ppg brine @ 6 bpm, 700 psi. Install swab valve below pump in sub and test same. Fill hole with 15 bbl./hr. over the top. 07:30 12:00 4.50 12.00 W.O. R 15 P M/U & round trip wireline CCL, GR, and 40 finger caliper logging BHA to 8,490' WLM. Fill hole with 15 bbl./hr. over the top 12:00 20:00 8.00 20.00 W.O. R 1 P E-line engineer timed out @ 12:00 hrs. Fill hole with 15 bbl./hr. over the top. Work on housekeeping and general maintenance on rig. Perform rig survey with Nabors engineer and superintendent. 20:00 21:00 1.00 21.00 W.O. M 9 P Bull head casing pumping at 5.9 bpm 900 psi total bbl. =384 pumped away, Monitor well 15 min, Well is on a Vacuum. 21:00 22:00 1.00 22.00 W.O. R 20 P Halliburton E-Line break off lube and lower weight bar to rig floor and remove. Hook up HES CCL and swivel along with interwell tools, stab on and PT 300/ 1,500 (Pass). Test Interwell tool on surface (good). 22:00 23:00 1.00 23.00 W.O. R 15 P Run in hole with 1.375' fishing neck ch / Swivel / CCL / interwell setting tool / Hex plug, OAL: 25' Max OD 3.63', Log correlation pass from 8,450 to 8,050 WLM tie into HES 40 arm caliper log. 23:00 00:00 1.00 24.00 W.O. R 15 P Log setting pass stopping at CCL depth 8,394.9' WLM ccl to mid element 15.1'. Mid element set at 8,410' WLM Changed over to interwell to set HEX plug. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Chad Gueco ASRC Energy Services Drilling Supervisor Chad.Gueco@external.eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Wes Steenhoven ASRC Energy Services HSE Wes.Steenhoven@external.eni.com 907-685-6622 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/10/2022 Report #: 41 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 19.2 Wind SW @ 15 MPH Days LTI (days) 1,168.00 Days RI (days) POB 55.0 Daily Summary Operations 24h Forecast Halliburton E-Line operations as per plan. 24h Summary Halliburton E-Line operations as per plan. Participate in audit with emphasis on safety, culture and permitting. Audit conducted by Eni group from Anchorage, Houston and Milano. Escorted by ODS team. Mix and Spot 125 bbl. Safe-vis lube in well bore. Operation at 07.00 Halliburton E-Line operations as per plan. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. R 15 P Continue with setting HEX plug on Halliburton E-line and Interwell, good indication of set lost 150# after setting. Pull out of the hole to surface and close blind rams. 01:00 02:30 1.50 2.50 W.O. R 5 P PJSM with rig crew , break off secondary swab valve lay down break down HEX plug tool string, make up APS lower packer module and stab on and test Interwell tools, good. Cont. adding 15 bbl./hr. to well. 02:30 06:00 3.50 6.00 W.O. R 15 P Run in hole with 1.375 fishing neck ch / swivel / ccl / Interwell setting tool / lower packer module OAL 22' Max OD 5.72' TW 500#. Log correlation pass from 8370' to 8050' tie into HES 40 arm caliper log, Log setting pass stopping at ccl. Depth 8,322.7, ccl, to mid element 14.3' mid element set at 8337' , swap over to Interwell to set APS lower packer module. Cont. adding 15 bbl./hr to well. 06:00 12:00 6.00 12.00 W.O. R 15 P Pull out of the hole to surface and make up 2nd straddle packer section. RIH t/ 8,150' wlm and slack off to weight of wire. Attempt to work past 8,150' wlm 5 times without success. Decision made to POOH to surface. Cont. adding 15 bbl./hr. to well. 12:00 14:00 2.00 14.00 W.O. R 15 P POOH to surface, lay down 2nd straddle packer section, and inspect. No abnormal wear observed. Close blind rams and cont. adding 15 bbl./hr. to well. 14:00 22:00 8.00 22.00 W.O. M 1 P Expedite Welltech tractor and Safe Vis-E for fluid lube. Cont. adding 15 bbl./hr. to well. Participate in audit with emphasis on safety culture and permitting. Audit conducted by Eni group from Anchorage, Houston and Milano. Escorted by ODS team. 22:00 00:00 2.00 24.00 W.O. M 9 P Mix Safe -Vis E in rig pits 125 bbl. Lube Pill, Bullhead 125 bbl. lube and chase with 275 bbl. of 8.6 ppg brine. Max Pump Rate of 60spm @ 5 bpm with 820 psi Total bbl. 400 pumped away, Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Stefano Pierfelici Eni Drilling Manager Stefano.Pierfelici@enipetroleum.com 907-685-3320 Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Chad Gueco ASRC Energy Services Drilling Supervisor Chad.Gueco@external.eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Wes Steenhoven ASRC Energy Services HSE Wes.Steenhoven@external.eni.com 907-685-6622 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/11/2022 Report #: 42 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) 3.7 Wind ESE @ 10 MPH Days LTI (days) 1,169.00 Days RI (days) POB 58.0 Daily Summary Operations 24h Forecast Halliburton E-Line Operations as per plan. 24h Summary Halliburton E-Line Operations as per plan, Participate in field visit with emphasis on safety, culture and permitting. Field Visit conducted by Eni group from Anchorage, Houston and Milano. Escorted by ODS team. Operation at 07.00 Halliburton E-Line Operations as per plan. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. R 5 P PJSM, Halliburton E-Line operations, Bring wire line with CCL/ Swivel to rig floor with new rope socket, start to assemble Interwell spacer pipe tool string make up on rope socket and test Interwell tools, good. 01:00 02:00 1.00 2.00 W.O. R 15 P PJSM Run in the hole with 1.375 fishing neck ch / swivel / ccl / Interwell setting tool, APS spacer pipe, OAL 55.4' max OD 5.72 Total wt.1,200# 02:00 04:00 2.00 4.00 W.O. R 15 P Attempt to pass through restriction going 150 fpm, made it to 8124' WLM. Attempt at 200 fpm made it to 8100' WLM, ccl / depth. Attempt at 100 fpm, made it to 8100' WLM, Attempt at 150 fpm made it to 8115' WLM, over pulls every time picking up out of restriction. Decision was made to pull out of the hole. 04:00 06:00 2.00 6.00 W.O. R 5 P On surface, break down lay down spacer pipe, Add 15 bbl. per hour to well. 06:00 14:00 8.00 14.00 W.O. R 1 P PJSM, Halliburton L/D E-line to unit and tie new rope socket. Prep to run spacer pipe, inspect Interwell and Welltech tools. Cont. adding 15 bbl./hr. to well. 14:00 22:00 8.00 22.00 W.O. R 20 P Expedite Welltech tractor to pipe shed and function test. R/U to run Interwell spacer jt on E-line. Cont. adding 15 bbl./hr. to well. Participate in field visit team with emphasis on safety, culture and permitting. Field visit team conducted by Eni group from Anchorage, Houston and Milano. Escorted by ODS team. 22:00 00:00 2.00 24.00 W.O. M 8 P Bring in 4 drums of Bara Lube W-520 into the rig pits, Drums are Frozen solid wrap drums with Herculite and thaw with steam hose. Mix 3 drums with 400 bbl. 8.6 brine 3% KCL. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Stefano Pierfelici Eni Drilling Manager Stefano.Pierfelici@enipetroleum.com 907-685-3320 Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Chad Gueco ASRC Energy Services Drilling Supervisor Chad.Gueco@external.eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Wes Steenhoven ASRC Energy Services HSE Wes.Steenhoven@external.eni.com 907-685-6622 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/12/2022 Report #: 43 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 14.7 Wind SW @ 10 MPH Days LTI (days) 1,170.00 Days RI (days) POB 57.0 Daily Summary Operations 24h Forecast Halliburton E-Line Operations as per plan. 24h Summary Halliburton E-Line Operations as per plan, Place Interwell spacer pipe in well, rig hydraulic system repair, set upper packer module, pull out of hole. Operation at 07.00 Halliburton E-Line Operations as per plan. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. M 9 P Continue bring in 4 drums of Bara Lube W-520 into the Rig pits, Drums are frozen solid wrap drums with herculite thaw with steam hose. Mix 3 ea. drums with 400 bbl. 8.6 brine 3% KCL. Bull head 40 bbl. down casing. 01:00 03:00 2.00 3.00 W.O. R 5 P PJSM Halliburton E-Line operations, make up Welltec tractor onto E-Line. Place Interwell spacer pipe in well make up tractor to Interwell spacer pipe, test Welltec and Interwell tools ( Good test). 03:00 06:00 3.00 6.00 W.O. R 15 P Halliburton E-Line run tools in hole W/ 1.375' fishing neck CH/ Swivel / CCL / Tractor / Interwell setting tool/ APS spacer pipe, OAL;81.1' Max OD; 5.72' TW 1,670#, Run in the hole while pumping 8.6 ppg brine mixed with 1% Bara-Lube W-520, pumping at 1.8 bpm while running tools in hole. Total 315 bbl. pumped away, Running speed 60 fpm. Tagged up at 8,115' WLM with a over pull of 4400# 06:00 12:00 6.00 12.00 W.O. R 15 P Begin tractoring in hole with spacer pup on Welltech tractor F/ 8,115' WLM to 8,331' wlm. Attempt to latch 8 times. (unsuccessful) POOH to 8,120' WLM and bring rig pumps @ 4 bpm 120 psi and s/o wireline @ 205'/ min and latch. (Successful latch) Cont. filling hole @ 15bbl/hr with 8.6 ppg brine with 1% lube. 12:00 16:00 4.00 16.00 W.O. R 15 P POOH with spacer pup running tool to surface. Prep for run #4. Tie new rope socket, test wire and tractor. Cont. filling hole @ 15bbl/hr with 8.6 ppg brine with 1% lube. 16:00 18:00 2.00 18.00 W.O. M 25 TR99 Repair hydraulic hose on sub hydraulic system. Function test (good) Cont. filling hole @ 15bbl/hr with 8.6 ppg brine with 1% lube 18:00 19:00 1.00 19.00 W.O. R 5 P PJSM Halliburton E-Line Operations, make up Welltec tractor onto E-Line, place Interwell spacer pipe in well make up tractor to Interwell spacer pipe, test Welltec and Interwell tools ( Good test). 19:00 21:00 2.00 21.00 W.O. R 15 P Halliburton E-Line run tools in hole W/ 1.375' fishing neck CH/ Swivel / CCL / Tractor / Interwell setting tool/ APS spacer pipe, OAL;81.1' Max OD; 5.72' TW 1,750#, Tagged up at CCL depth of 8135' WLM, Pull up and make another attempt to go past restriction. Tag up on CCL Depth of 8120' WLM, turn Tractor on and tractor to 8190' CCL depth. 21:00 22:00 1.00 22.00 W.O. R 15 P Get pick up weight and hanging weight at 8190' and run in hole at 180 fpm to attempt to latch and pick up and pull the packer out of the latch position at approximately 4900#, Run second attempt to latch into spacer pipe, pick up to 4,900# and hold for 2 minutes, ( Good latch). Return to neutral weight. 22:00 23:00 1.00 23.00 W.O. K 9 P Bull head 215 bbl. @ 4 bpm at 160 psi. 23:00 00:00 1.00 24.00 W.O. R 15 P Change to Interwell operations to set upper packer module, good indication of set, slack off to confirm set at CCL depth at 6215' putting the center of element at 8256' WLM, The bottom at approximately 8289' WLM, Pulled out of the hole to surface. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Chad Gueco ASRC Energy Services Drilling Supervisor Chad.Gueco@external.eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Wes Steenhoven ASRC Energy Services HSE Wes.Steenhoven@external.eni.com 907-685-6622 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/13/2022 Report #: 44 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 13.1 Wind NW @ 6 MPH Days LTI (days) 1,171.00 Days RI (days) POB 58.0 Daily Summary Operations 24h Forecast Test Bops, Halliburton E-Line operations as per plan, 24h Summary Halliburton E-Line operations as per plan, begin BOP testing. Operation at 07.00 Testing Bops. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 W.O. R 5 P PJSM, Halliburton E-Line make up Interwell tools in the pipe shed, bridge plug, in flow test devise and barrier verification system. Monitor well on trip tank. 04:00 09:00 5.00 9.00 W.O. R 15 P PJSM Halliburton E-Line, set inflow test devise timer for 180 min. & run in hole with bridge plug / inflow test device. Set top of bridge plug at 8,210'- 8,410' bottom, Monitor bottom hole pressures and Inflow test devise, time out at 7:47 am and did not function. Wait one extra hour still no function. Monitor well on trip tank. 09:00 10:30 1.50 10.50 W.O. R 12 P Decision made to pressure test casing and to top of plug @ 8,210 WLM to 500 psi for 60 charted minutes. Good test. Monitor well on trip tank. 10:30 16:00 5.50 16.00 W.O. R 15 P Release E-line and pull out of the hole to surface. Swap HES wireline unit from E-line to slickline. Monitor well on trip tank 16:00 18:00 2.00 18.00 W.O. R 15 P RIH with slick line and engage bridge plug and inflow test device @ 8,210' WLM. Monitor well on trip tank. 18:00 22:00 4.00 22.00 W.O. R 7 P Pull out of the hole with bridge plug and inflow test device to surface. Lay down Halliburton and Interwell tools and equipment. Fill hole with 215 bbl. with returns to surface. 22:00 23:30 1.50 23.50 W.O. K 7 P PJSM remove shooting flange. Install flow riser, closed blind rams for PT. Pump 223 BBLs before returns at surface. loss rate of 2 BPM to wellbore. 23:30 00:00 0.50 24.00 W.O. C 12 P Rig up and begin BOP equipment testing. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. Paul.Dillon@external.eni.com 907-685-0715 Eni representative Chad Gueco ASRC Energy Services Drilling Supervisor Chad.Gueco@external.eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Wes Steenhoven ASRC Energy Services HSE Wes.Steenhoven@external.eni.com 907-685-6622 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/14/2022 Report #: 45 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) 6.1 Wind SW @ 12 MPH Days LTI (days) 1,172.00 Days RI (days) POB 61.0 Daily Summary Operations 24h Forecast Halliburton E-Line Operations as per plan, Rig Maintenance / Clean / Paint. 24h Summary Testing BOPE, Halliburton E-Line operations as per plan, Operation at 07.00 Following the results of spinner tool run standby for plan forward, rig maintenance. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. C 5 P Remove Shooting flange, Install Flow Riser, Rig up Bleed trailer and install 2" high pressure hose to bleed trailer from Annulus A. 02:00 15:00 13.00 15.00 W.O. C 12 P Rig up test Equipment and test BOPs with 2 7/8" & 4” test jnt. 250 PSI low, 3500 PSI high, annular 250 psi low, 2500 PSI high. per AOGCC requirements. All test are Good test. Test 2 7/8 x 5 UPR, B/S rams, 2 7/8 x 5 LPR. Choke valves 1-15, hydraulic and manual choke. Kill line valve, choke and kill manual and HCR valves. Upper and lower IBOP on top drive. XT-39 FOSV and dart valve. Test PVT and gas alarms. Perform accumulator draw down test, accumulator pressure 3,000,after function 1600 ,200 psi recovery 10 sec, full recovery 61sec, number of N2 bottles 6 total average pressure 2133 psi. (AOGCC Guy Cook Witness waived 11-11-22 @ 12:57 hrs.) R/D test equip. 15:00 16:30 1.50 16.50 W.O. C 5 P N/D flow riser and air boot flange. Nipple up shooting flange and prep to run wireline. Fill the hole with 8.6 ppg @ 15 bbl/hr 16:30 21:00 4.50 21.00 W.O. R 5 P R/U wireline lubricator with full PCE as per Halliburton Rep. Fill the hole with 8.6ppg @ 15 bbl/hr 21:00 00:00 3.00 24.00 W.O. R 11 P Run in the hole Halliburton E-Line Spinner tool assembly, Log from 8000' to 8410' SLM while pumping 126 gpm 100 psi, Leak confirmed @ 8256 WLM. Pull out of the hole. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. Paul.Dillon@external.eni.com 907-685-0715 Eni representative Chad Gueco ASRC Energy Services Drilling Supervisor Chad.Gueco@external.eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Wes Steenhoven ASRC Energy Services HSE Wes.Steenhoven@external.eni.com 907-685-6622 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/15/2022 Report #: 46 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 14.5 Wind S @ 25 MPH Days LTI (days) 1,173.00 Days RI (days) POB 61.0 Daily Summary Operations 24h Forecast Halliburton E-Line Operations as per plan to retrieve Straddle packer assembly. 24h Summary Halliburton E-Line Operations as per plan. Rig Maintenance / Clean / Paint Rig. Make up and run in hole run # 7. BHA - GS pulling tool, Welltec stroker tool, CCL. Operation at 07.00 Prep E-line for run # 7. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. R 15 P Finish pull out of hole with E-line. Lay down spinner tools. Fill the hole with 8.6ppg @ 15 bbl./hr. 01:30 19:00 17.50 19.00 W.O. R 1 U Expedite Welltec stroker tool to location. Load back-up Interwell straddle packer assembly in the pipe shed and prep for install. Tie new rope socket on wireline. Change out depth panel in Halliburton wireline unit and test, (good). Rig Maintenance / Clean / Paint, Work on Cleaning and painting motor room module. Fill the hole with 8.6 ppg @ 15 bbl./hr. 19:00 22:00 3.00 22.00 W.O. R 5 P Welltec tool, equipment and personal arrived on location at 19:00 hr. Mobilize stroker tool to pipe shed and stage on pipe skate. Make up Run 7 BHA: 6" GS pulling tool, Welltec stroker tool, CCL. Length 41.05', Max OD 5.72", 956 LBS. Fill the hole with 8.6 ppg @ 15 bbl./hr. 22:00 00:00 2.00 24.00 W.O. R 15 P Run in hole with Run 7 on E-line to retrieve upper straddle packer to 7900'. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. Paul.Dillon@external.eni.com 907-685-0715 Eni representative Chad Gueco ASRC Energy Services Drilling Supervisor Chad.Gueco@external.eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Wes Steenhoven ASRC Energy Services HSE Wes.Steenhoven@external.eni.com 907-685-6622 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/16/2022 Report #: 47 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) 22.8 Wind S @ 12 MPH Days LTI (days) 1,174.00 Days RI (days) POB 61.0 Daily Summary Operations 24h Forecast Halliburton E-Line Operations as per plan to install upper straddle packer assembly, test straddle packers, and retrieve lower bridge plug. 24h Summary Halliburton E-Line Operations as per plan to retrieve upper straddle packer assembly. Redress Welltec stroker tool. Halliburton re-headed rope socket. Run in hole with E-line to confirm spacer joint fully latched into lower straddle packer. Make up upper straddle packer assembly on E-line. Operation at 07.00 Halliburton E-Line Operations. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:30 3.50 3.50 W.O. R 15 P Continue run in hole with BHA # 7 on E-line to retrieve upper straddle packer from 7900' to 8250'. Engage upper straddle packer with upper spacer pipe and unseat from lower spacer pipe. Pull out of hole with E-line. Fill wellbore with 8.6 PPG brine at 15 BPH. 03:30 04:30 1.00 4.50 W.O. R 5 P Lay down upper straddle packer with upper spacer pipe and BHA #7. Upper straddle packer seal latch indicates the tool was never fully engaged in lower spacer pipe. Fill wellbore with 8.6 PPG brine at 15 BPH. 04:30 06:00 1.50 6.00 W.O. R 1 P Prepare E-line tools to run in hole. Rebuild Welltec stroker tool. Halliburton re-headed rope socket. Fill wellbore with 8.6 PPG brine at 15 BPH. 06:00 18:00 12.00 18.00 W.O. R 15 P Continue rebuild Welltec E-line stroker tool and tie new rope socket. Prep and expedite Welltec tractor. Pick up stroker tool and run in hole for latch integrity test of the spacer joint to the lower tandem straddle packer. Fill wellbore with 8.6 PPG brine at 15 BPH. 18:00 21:30 3.50 21.50 W.O. R 15 P Latched the lower straddle packer spacer at 8256’ ( bottom of tool). Stroke up to a 2500# over pull. Held for 2 min, no movement. Release the stroker and close the stroker. Stroke down 10K hold for 2 min, no movement. Open the stroker tool to fully extended. Stroke up to shear the DU adapter tool at 4K. Good signature of DU shear at 3960#. Close the stroker to the compressed position, stroke down 10K to shear the GS. GS sheared at 8500# with a good signature. Pick up off tool with wire line with a pick up weight of 2100#. Pull out of the hole lay down tools. Fill wellbore with 8.6 PPG brine at 15 BPH. 21:30 00:00 2.50 24.00 W.O. R 5 P Make up BHA #9 MR APS Upper Module straddle packer seal Assembly with Stroker Tool. Fill wellbore with 8.6 PPG brine at 15 BPH. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. Paul.Dillon@external.eni.com 907-685-0715 Eni representative Chad Gueco ASRC Energy Services Drilling Supervisor Chad.Gueco@external.eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Wes Steenhoven ASRC Energy Services HSE Wes.Steenhoven@external.eni.com 907-685-6622 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Tool Push Matt Turcotte Nabors Tool Pusher Matthew.Turcotte@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/17/2022 Report #: 48 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) 28.4 Wind S @ 14 MPH Days LTI (days) 1,175.00 Days RI (days) POB 58.0 Daily Summary Operations 24h Forecast Run in hole on Halliburton E-Line to retrieve HEX plug with Mags Tool. Bullhead 8.6 ppg brine into wellbore. Pull out of hole, rig down E-line, and shooting flange. Trip in hole with 4" drill pipe from derrick and lay down same. 24h Summary Halliburton E-Line Operations as per plan to install upper straddle packer assembly. Test 7" casing. Attempt to enter top of upper straddle packer module (unsuccessful). Run in hole with 3.80" swedge with spang jars on E-line. Run in hole to retrieve HEX plug with Mags Tool. Safety Stand down. Make up tractor and Stroker tools on E-Line. Operation at 07.00 Halliburton E-Line Operations. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 00:30 0.50 0.50 W.O. R 5 P Make up BHA #9 MR APS Upper Module straddle packer seal assembly with Stroker Tool. 00:30 06:00 5.50 6.00 W.O. R 15 P Run in hole with Upper Module straddle packer seal assembly with Stroker Tool to 8,000'. Perform weight checks and function test tools 3,000# Up Weight, 1,100# Neutral weight , 2,500# static weight. Stacked out at 8,100' swap over to Welltec and began stroking down 2 times. Stacked out at 8,206' (CCL depth 8,277' bottom of tool). Switch over to Welltec again to stroke upper assembly into Latch. Upper patch Completion set into place. Lower straddle 8,337' C/O/E. POOH and lay down tools. 06:00 07:30 1.50 7.50 W.O. M 12 P Fill 7" casing with 40 bbl 8.6 ppg brine and closed the blind rams to test casing from 8,410' to surface. 500 psi charted for 1' hour ( Good test). 07:30 12:00 4.50 12.00 W.O. R 15 P Run in hole on Halliburton E-Line to retrieve HEX plug with Mags Tool. At 8,256' wlm slack off to wire weight and attempt to enter top of upper straddle packer module while staging up wire speed to a max of 200'/min.(unsuccessful). 12:00 17:30 5.50 17.50 W.O. R 15 P POOH and inspect tools. No signs of damage or informalities. Prep and expedite 3.80" swedge with spang jars to rig floor. 17:30 19:00 1.50 19.00 W.O. R 21 U Safety Stand Down to asses person medical issue on the rig floor. 19:00 00:00 5.00 24.00 W.O. R 15 P Run in hole with 3.80" swedge with spang jars on E-line to 8,378' wlm. POOH and lay down tools. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. Paul.Dillon@external.eni.com 907-685-0715 Eni representative Chad Gueco ASRC Energy Services Drilling Supervisor Chad.Gueco@external.eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Wes Steenhoven ASRC Energy Services HSE Wes.Steenhoven@external.eni.com 907-685-6622 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/18/2022 Report #: 49 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) 28.4 Wind W @ 20 MPH Days LTI (days) 1,176.00 Days RI (days) POB 58.0 Daily Summary Operations 24h Forecast Finish cut and slip drilling line. Pull out of hole from 2,053' laying down 4" drill pipe. Run in hole with upper completion as planned. 24h Summary Run in hole on Halliburton E-Line to retrieve HEX plug with Mags Tool. Bullhead 525 bbls of 8.6 ppg brine into wellbore. Pull out of hole and rig down E-line. Trip in hole with 4" drill pipe from derrick to 2,053'. Critical life work suspended due to hovercraft maintenance. Cut and slip drilling line. Operation at 07.00 POOH laying down 4" drill pipe. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:00 3.00 3.00 W.O. R 5 P Make up Tractor / Stroker Tools on E-Line. Pressure test lubricator 500 psi (Good test). 03:00 08:00 5.00 8.00 W.O. R 15 P Run in hole on E-Line to retrieve HEX plug at 8,410'. Pressure up on wellbore to 200 psi. Pulled and release HEX Plug and observe pressure drop to 0 psi. Pull out of the hole to surface. Fill well with 8.6 ppg brine at 15 bbl/hr. 08:00 17:00 9.00 17.00 W.O. R 9 P Verify 0 psi and pop off lubricator and pull tool string clear of BOPE. Close blind rams and bullhead 600 bbls at 2 bpm and 980 psi. Rig down wireline on rig floor. Rig down Interwell and WellTec tools from pipe shed. Fill well after bull heading with 8.6 ppg brine at 15 bbl/hr. 17:00 22:00 5.00 22.00 W.O. M 4 P Trip in the hole with 4" Drill pipe from derrick to 2,053' MD. 22:00 23:30 1.50 23.50 W.O. M 25 P Life critical operations suspended due to hovercraft maintenance. 23:30 00:00 0.50 24.00 W.O. M 25 P Slip & cut drill line. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. Paul.Dillon@external.eni.com 907-685-0715 Eni representative Chad Gueco ASRC Energy Services Drilling Supervisor Chad.Gueco@external.eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Wes Steenhoven ASRC Energy Services HSE Wes.Steenhoven@external.eni.com 907-685-6622 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/19/2022 Report #: 50 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 22.1 Wind SW @ 14 MPH Days LTI (days) 1,177.00 Days RI (days) POB 42.0 Daily Summary Operations 24h Forecast Run in hole with upper completion as planned. Slickline operations as planned to set 7" packer, combo test tubing and casing. Nipple down BOPE and install tree. 24h Summary Finish cut and slip drilling line. Pull out of hole from 2,053' laying down 4" drill pipe. Run in hole with upper completion as planned. Operation at 07.00 Run in hole with upper completion. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:00 3.00 3.00 W.O. M 25 P Slip & cut drill line, 4 wraps on the drum = 29.5'. 03:00 05:00 2.00 5.00 W.O. M 9 P Bull head to clear oil cap from top of well while pulling out of hole. Bull head tubing with 24 bbls 8.6 ppg brine at 825 psi. Bull Head A Annulus with 61 bbls 8.6 ppg brine at 850 psi. 05:00 09:00 4.00 9.00 W.O. M 4 P POOH sideways with 4' Drill pipe from 2060 'MD to surface. Fill the hole with 8.6 ppg brine @ 9 bbl./hr. 09:00 10:00 1.00 10.00 W.O. C 5 P Pull wear bushing as Vetco rep. and lay down. Fill the hole with 8.6 ppg brine @ 9 bbl./hr. 10:00 17:00 7.00 17.00 W.O. M 1 P Drain and clear crude from 4" drill pipe in shed. Rig up to run upper completions with SLB completions and GBR casing. Fill the hole with 8.6 ppg brine at 9 bbl/hr. 17:00 19:30 2.50 19.50 W.O. K 4 P RIH with 2-7/8" / 3-1/2" upper completion to 534' MD. Fill the hole with 8.6 ppg brine at 9 bbl/hr. 19:30 23:00 3.50 23.00 W.O. K 5 P Install pressure and temperature line to gauge mandrel with Schlumberger completion reps. Fill the hole with 8.6 ppg brine at 9 bbl/hr. 23:00 00:00 1.00 24.00 W.O. K 4 P RIH with 2-7/8" / 3-1/2" upper completion from 534' to 715' MD. Fill the hole with 8.6 ppg brine at 9 bbl/hr. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. Paul.Dillon@external.eni.com 907-685-0715 Eni representative Chad Gueco ASRC Energy Services Drilling Supervisor Chad.Gueco@external.eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Wes Steenhoven ASRC Energy Services HSE Wes.Steenhoven@external.eni.com 907-685-6622 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/20/2022 Report #: 51 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 22.6 Wind Calm Days LTI (days) 1,178.00 Days RI (days) POB 47.0 Daily Summary Operations 24h Forecast Continue running 2-7/8" x 3-1/2" upper completion. Land tubing hanger. Test hanger void and drop ball and rod. Set packer. Pump Corrosion Inhibitor and LVT. Test packer. 24h Summary Finish slip and cut drill line. POOH and lay down drill pipe. Rig up and run in hole with upper completion. Operation at 07.00 Landing hanger on upper completion. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 W.O. K 4 P RIH with 2-7/8" x 3-1/2" upper completion with SLB completions and GBR from 715' to 2,755' MD. Fill the hole with 8.6 ppg brine at 9 bbl./hr. 06:00 16:00 10.00 16.00 W.O. K 4 P RIH with 2-7/8" x 3-1/2" upper completion with SLB completions and GBR from 2,755' to 6,390' MD. Fill the hole with 8.6 ppg brine at 9 bbl./hr. 16:00 17:00 1.00 17.00 W.O. K 5 P Install TRSCSSSV control line with Schlumberger representatives. Pressure test control line to 6000 PSI, good test. Bleed line down to 4960 PSI to keep TRSCSSSV in open position while continuing to run in hole. 17:00 22:00 5.00 22.00 W.O. K 4 P RIH with 2-7/8" x 3-1/2" upper completion with SLB completions and GBR from 6,390' to 8,256' MD. Fill the hole with 8.6 ppg brine at 9 bbl./hr. 22:00 22:30 0.50 22.50 W.O. K 4 P Tag on Joint #268 at 8,256' SOW = 77k. Orientate mule shoe 1/2 turn and set 15k down. Enter top of Liner with mule shoe at 8,256 MD. 22:30 00:00 1.50 24.00 W.O. K 4 P Continue Running in the hole from 8,256 to 8,366 MD. Change out Elevators from 2-7/8" to 3-1/2". Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. Paul.Dillon@external.eni.com 907-685-0715 Eni representative Chad Gueco ASRC Energy Services Drilling Supervisor Chad.Gueco@external.eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/21/2022 Report #: 52 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 22.1 Wind NW @ 32 MPH Days LTI (days) 1,179.00 Days RI (days) POB 59.0 Daily Summary Operations 24h Forecast Slick line operations to retrieve ball and rod. Nipple down BOPE & Nipple up Tree. Pipe management, lay down drill pipe. Move Nabors 19E From ODSN-29 to ODSN-25. 24h Summary Continue running in the hole with upper completion. Bull head down A Annulus and tubing. Land tubing hanger. Drop ball and rod. Pump Corrosion Inhibitor and LVT. Test packer (good test). Operation at 07.00 Nipple down BOPE. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 00:30 0.50 0.50 W.O. K 5 P Change out dies on GBR casing tongs from 2-7/8" to 3-1/2". 00:30 10:30 10.00 10.50 W.O. K 9 P Make up 1st jt of 3-1/2" Tenaris Blue. Observe flow from tubing. Engage FOSV and close annular preventer. A annulus = 50 psi. Bleed to 0 psi through poor boy degasser. Line up and bullhead 310 bbls down A annulus at 2 bpm, 725 psi. Bullhead 50 bbls down tubing at 2 bpm 700 psi. Verify communication on tech line to gauge carrier (good test). Verify pressure on TRSCSSSV control line at 6,000 psi (good test). 10:30 11:30 1.00 11.50 W.O. K 1 P Bleed pressure to 0 psi. through choke manifold and production test header. Allow tubing and A annulus to equalize. 11:30 16:00 4.50 16.00 W.O. K 4 P Change out first joint of 3-1/2" Tenaris Blue tubing due to damage from power tongs back up dies. Continue to RIH. Pick up hanger, terminate and verify communication on tech line to gauge carrier (good test). Verify pressure on TRSCSSSV control line at 6,000 psi (good test). 16:00 17:00 1.00 17.00 W.O. C 5 P Land Hanger with PU - 90K, SO - 75K and run in lock down screws as per vault rep. Test upper and lower seals on hanger (good test). 260 of 2-7/8" Clamps used & 5 of 3-1/2" Clamps used. 17:00 18:00 1.00 18.00 W.O. K 5 P Change landing joints and drop 1.30" Ball and rod to set SLB packer. Hold PJSM for pumping packer fluid, and LVT freeze protect down A annulus. 18:00 22:00 4.00 22.00 W.O. K 9 P Little Red services pump 4 bbl packer fluid down the A Annulus then switch to rig pumps and chase packer fluid with 156 bbl 8.6 ppg 3% KCL Completion fluid. Switch back over to Little Red services and pump 80 bbl LVT freeze protect down A annulus. 22:00 00:00 2.00 24.00 W.O. K 12 P Pressure test tubing to 3,500 psi 30 min charted (good test). Leave 3,500 psi on tubing and pressure up on A Annulus to 2,500 psi 30 min charted Combo test (good test). Bleed off Tubing and A Annulus pressures to zero. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. Paul.Dillon@external.eni.com 907-685-0715 Eni representative Chad Gueco ASRC Energy Services Drilling Supervisor Chad.Gueco@external.eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Well Name: ODSN-29 Wellbore Name: Original Hole Well Code: 26872 Job: WORKOVER WCEI: N/A Daily Report Date: 11/22/2022 Report #: 53 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code DEVELOPMENT WELL Rotary Table Elevation (ft) Water Depth (ft) First Flange (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 11.3 Wind NW @ 36 MPH Days LTI (days) 1,180.00 Days RI (days) POB 45.0 Daily Summary Operations 24h Forecast Move rig from ODSN-29 to ODSN-25. 24h Summary Slickline to retrieve ball and rod. Nipple down BOPE & Nipple up Tree. (Release Rig at 11:59 hrs. on 11-22-2022). Operation at 07.00 No further work on ODSN-29. Release Rig at 11:59 hrs. on 11-22-2022. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. K 5 P Blow down Lines and rig down test equipment. Clear and clean rig floor. 01:30 06:00 4.50 6.00 W.O. R 12 P Rig up Halliburton Slickline full pressure control equipment. Test Lubricator 1,500 psi ( Good Test). 06:00 07:30 1.50 7.50 W.O. R 15 P Run in hole retrieve ball and rod at 8,055' WLM. Apply 200 psi -Unseat ball Pressure dropped to 0 psi. Pulled Slickline to a safe spot. Phase Three Condition at 06:30. 07:30 08:30 1.00 8.50 W.O. R 15 P Continue Slickline Operations. Pull out of the hole from 8,055' with ball and rod. 08:30 09:00 0.50 9.00 W.O. R 22 P Phase Three Conditions work on JSA's. 09:00 16:00 7.00 16.00 W.O. R 15 P Change out Slickline BHA. Run in the hole to 8,055' WLM and pull plug. Lay down plug and rig down Slickline equipment. Close TRSCSSSV. Terminate gauge wire & TRSCSSSV control line for Nipple down BOPE. Lay down landing joint. Vault Rep install TWC valve in well head profile. 16:00 19:30 3.50 19.50 W.O. C 5 P Nipple down BOPE. Bleed pressure of Accumulator & Power down. Remove choke / Kill lines from BOPs. Remove mouse hole & Lay down in pipe shed. Lay down bridge cellar and pick up BOP stack. Remove drill riser & stage in pipe shed. 19:30 00:00 4.50 24.00 W.O. C 5 P Nipple up tree. Terminate TRSCSSSV & Gauge wires at well head. Demobilize gauge wire spool from rig floor. Demobilize completion tools from rig floor. Nipple up production tree. Vault rig up for passport test on tree. Begin to pull Accumulator Hoses from cellar. Rig down pipe skate ramp. Rig down beaver slide. Blow down high pressure mud lines. (Release Rig at 11- 22-2022 at 11:59 hrs.) No further reports. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. Craig.Smith@external.eni.com 907-670-6606 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. Paul.Dillon@external.eni.com 907-685-0715 Eni representative Chad Gueco ASRC Energy Services Drilling Supervisor Chad.Gueco@external.eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 907-670-6622 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 1 Regg, James B (OGC) From:Turcotte, Matthew <Matthew.Turcotte@nabors.com> Sent:Monday, November 14, 2022 6:45 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Mbx ODSDrilling Cc:Henson, James; Henson, James; Beard, Seth; Holcomb, Sean Subject:Nabors 19AC 11-14-2022 Attachments:Nabors 19AC 11-14-22.xlsx Here is our test report. Thank you Matt Turcotte Nabors 19E Rig Manager NABORS ALASKA DRILLING INC. PHONE 1-907-670-6630 I Cell 1-907-232-7175 matthew.turcotte@nabors.com I www.nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Su bm it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:19AC DATE: 11/14/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name: PTD #2121060 Sundry #322-448 Operation: Drilling: Workover: X Explor.: Test: Initial: Weekly: X Bi-Weekly: Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:2001 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 FP Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2 7/8" X 5"P Flow Indicator P P #2 Rams 1 Blind/Shear P Meth Gas Detector P P #3 Rams 1 2 7/8" X 5"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 3 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"FP System Pressure (psi)3000 P Kill Line Valves 4 3 1/8" & 2" P Pressure After Closure (psi)1600 P Check Valve 0 NA 200 psi Attained (sec)10 P BOP Misc 0 NA Full Pressure Attained (sec)61 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6@2133 P No. Valves 15 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec) Test Result CH Misc 0 NA Annular Preventer 25 P #1 Rams 9 P Coiled Tubing Only:#2 Rams 10 P Inside Reel valves 0 NA #3 Rams 9 P #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:2 Test Time:8 hours HCR Choke 4 P Repair or replacement of equipment will be made within days. HCR Kill 4 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 11/11/22 12:57 Waived By Test Start Date/Time:11/14/2022 5:00 (date) (time)Witness Test Finish Date/Time:11/14/2022 13:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nabors Test Jt's 2 7/8"and 4" HCR Choke failed on low test, greased and worked it. Retested good. While testing Lower Rams TIW started to leak opened and closed it, retested good. Matt Turcotte/Sean Holcomb ENI Justin Hays/Craig Smith Oooguruk ODSN-29 Test Pressure (psi): matthew.turcotte@nabors.com odsdrilling@eni.com Form 10-424 (Revised 08/2022) 2022-1114_BOP_Nabors19AC_Oooguruk_ODSN-29 FP FP HCR Choke failed Lower Rams TIW started to leak 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Tuesday, November 15, 2022 4:51 PM To:Turcotte, Matthew Cc:Regg, James B (OGC) Subject:RE: Nabors 19AC 10-30-22 Attachments:Nabors 19AC 10-30-22 Revised.xlsx Matt, Attached is a revised report adding PTD #2121060 for ODSN‐29. Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Turcotte, Matthew <Matthew.Turcotte@nabors.com> Sent: Monday, October 31, 2022 2:37 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Mbx ODSDrilling <ODSDrilling@eni.com> Cc: Henson, James <Jim.Henson@nabors.com>; Henson, James <James.Henson@nabors.com>; Beard, Seth <Seth.Beard@nabors.com>; Holcomb, Sean <Sean.Holcomb@nabors.com> Subject: Nabors 19AC 10‐30‐22 Here is the test report. Thank you Matt Turcotte Nabors 19E Rig Manager CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Oooguruk ODSN-29 PTD 2121060 2 NABORS ALASKA DRILLING INC. PHONE 1-907-670-6630 I Cell 1-907-232-7175 matthew.turcotte@nabors.com I www.nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:19AC DATE:10/30/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2121060 Sundry #322-448 Operation:Drilling:Workover:X Explor.: Test:Initial:Weekly:X Bi-Weekly:Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2001 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2 7/8" X 5"P Flow Indicator P P #2 Rams 1 Blind/Shear P Meth Gas Detector P P #3 Rams 1 2 7/8" X 5"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 3 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"FP System Pressure (psi)3000 P Kill Line Valves 4 3 1/8" & 2" P Pressure After Closure (psi)1600 P Check Valve 0 NA 200 psi Attained (sec)9 P BOP Misc 0 NA Full Pressure Attained (sec)58 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):6 @ 2075 P No. Valves 15 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 25 P #1 Rams 10 P Coiled Tubing Only:#2 Rams 8 P Inside Reel valves 0 NA #3 Rams 10 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:5.0 HCR Choke 3 P Repair or replacement of equipment will be made within days. HCR Kill 3 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 10/28/22 12:48 Waived By Test Start Date/Time:10/30/2022 11:30 (date)(time)Witness Test Finish Date/Time:10/30/2022 16:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Lou Laubenstein Nabors Test Jt's 2 7/8"and 4" HCR Choke failed on low test, greased and worked it. Retested good. Matt Turcotte/Seth Beard ENI Tim Ashley/Mark Ashley Oooguruk ODSN-29 Test Pressure (psi): matthew.turcotte@nabors.com odsdrilling@eni.com Form 10-424 (Revised 08/2022)2022-1030_BOP_Nabors19AC_Oooguruk_ODSN-29 J. 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Inc. 3700 Centerpoint Dr., Suite 500 Anchorage, AK 99503 ͗ϵϬϳͲϴϲϱͲϯϯϳϵ ͗ϵϬϳͲϯϰϲͲϬϱϵϭD ͘ŵĂŝů͗ĂŵũĂĚ͘ĐŚĂƵĚŚƌLJΛĞŶŝ͘ĐŽŵ &$87,21 7KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH dŚŝƐĚŽĐƵŵĞŶƚĂŶĚĂŶLJĨŝůĞƐŽƌĞͲŵĂŝůŵĞƐƐĂŐĞƐĂƚƚĂĐŚĞĚƚŽŝƚĐŽŶƚĂŝŶĚĂƚĂŽƌŝŶĨŽƌŵĂƚŝŽŶƚŚĂƚŝƐĐŽŶĨŝĚĞŶƚŝĂů͕ƉƌŝǀŝůĞŐĞĚ ŽƌŽƚŚĞƌǁŝƐĞƌĞƐƚƌŝĐƚĞĚĨƌŽŵĚŝƐĐůŽƐƵƌĞ͘/ĨLJŽƵĂƌĞŶŽƚƚŚĞŝŶƚĞŶĚĞĚƌĞĐŝƉŝĞŶƚ͕ďĞĂǁĂƌĞƚŚĂƚĂŶLJĚŝƐĐůŽƐƵƌĞ͕ĐŽƉLJŝŶŐ͕ ĚŝƐƚƌŝďƵƚŝŽŶŽƌƵƐĞŽĨĂŶLJŽĨƚŚĞĚĂƚĂŽƌŝŶĨŽƌŵĂƚŝŽŶĐŽŶƚĂŝŶĞĚŚĞƌĞŝŶŽƌŝŶĂŶLJŽĨƚŚĞĂƚƚĂĐŚŵĞŶƚƐŝƐƐƚƌŝĐƚůLJƉƌŽŚŝďŝƚĞĚ͘/Ĩ LJŽƵŚĂǀĞƌĞĐĞŝǀĞĚƚŚŝƐĚŽĐƵŵĞŶƚŽƌƚƌĂŶƐŵŝƐƐŝŽŶŝŶĞƌƌŽƌ͕ƉůĞĂƐĞŝŵŵĞĚŝĂƚĞůLJŶŽƚŝĨLJƚŚĞƐĞŶĚĞƌĂŶĚĚĞƐƚƌŽLJ͕ĚĞůĞƚĞŽƌ ĞƌĂƐĞƚŚŝƐĚŽĐƵŵĞŶƚĂŶĚĂůůĂƚƚĂĐŚŵĞŶƚƐ͘ ---------------------------------------------------------------------------------------------------------------------------------------------------- -------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ 1 Regg, James B (OGC) From:Turcotte, Matthew <Matthew.Turcotte@nabors.com> Sent:Monday, November 14, 2022 6:45 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Mbx ODSDrilling Cc:Henson, James; Henson, James; Beard, Seth; Holcomb, Sean Subject:Nabors 19AC 11-14-2022 Attachments:Nabors 19AC 11-14-22.xlsx Here is our test report. Thank you Matt Turcotte Nabors 19E Rig Manager NABORS ALASKA DRILLING INC. PHONE 1-907-670-6630 I Cell 1-907-232-7175 matthew.turcotte@nabors.com I www.nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Oooguruk ODSN-29PTD 2121060 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:19AC DATE:11/14/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2121060 Sundry #322-448 Operation:Drilling:Workover:X Explor.: Test:Initial:Weekly:X Bi-Weekly:Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:2001 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 FP Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2 7/8" X 5"P Flow Indicator P P #2 Rams 1 Blind/Shear P Meth Gas Detector P P #3 Rams 1 2 7/8" X 5"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 3 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"FP System Pressure (psi)3000 P Kill Line Valves 4 3 1/8" & 2" P Pressure After Closure (psi)1600 P Check Valve 0 NA 200 psi Attained (sec)10 P BOP Misc 0 NA Full Pressure Attained (sec)61 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):6@2133 P No. Valves 15 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 25 P #1 Rams 9 P Coiled Tubing Only:#2 Rams 10 P Inside Reel valves 0 NA #3 Rams 9 P #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:2 Test Time:8 hours HCR Choke 4 P Repair or replacement of equipment will be made within days. HCR Kill 4 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 11/11/22 12:57 Waived By Test Start Date/Time:11/14/2022 5:00 (date)(time)Witness Test Finish Date/Time:11/14/2022 13:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nabors Test Jt's 2 7/8"and 4" HCR Choke failed on low test, greased and worked it. Retested good. While testing Lower Rams TIW started to leak opened and closed it, retested good. Matt Turcotte/Sean Holcomb ENI Justin Hays/Craig Smith Oooguruk ODSN-29 Test Pressure (psi): matthew.turcotte@nabors.com odsdrilling@eni.com Form 10-424 (Revised 08/2022)2022-1114_BOP_Nabors19AC_Oooguruk_ODSN-29 J. Regg; 12/27/2022 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Monday, November 7, 2022 12:30 PM To:Henson, James Cc:Regg, James B (OGC) Subject:RE: 19AC BOPE TEST 10-11-22 I removed the “sec” from the numeric only fields. Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Henson, James <James.Henson@nabors.com> Sent: Thursday, October 13, 2022 9:05 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: Henson, James <Jim.Henson@nabors.com>; Holcomb, Sean <Sean.Holcomb@nabors.com>; Turcotte, Matthew <Matthew.Turcotte@nabors.com>; Beard, Seth <Seth.Beard@nabors.com>; Mbx ODSDrilling <ODSDrilling@eni.com>; justin.hays@external.eni.com Subject: 19AC BOPE TEST 10‐11‐22 James Henson Jr. 19E Rig Manager NABORS ALASKA DRILLING, INC. Direct 907.670.6630 I Mobile 907.398.3080 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Oooguruk ODSN-29 PTD 2121060 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:19AC DATE:10/11/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2121060 Sundry #322-448 Operation:Drilling:Workover:X Explor.: Test:Initial:Weekly:X Bi-Weekly:Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:2001 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 FP Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2 7/8" X 5"P Flow Indicator P P #2 Rams 1 Blind/Shear P Meth Gas Detector P P #3 Rams 1 2 7/8" X 5"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 3 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"FP System Pressure (psi)3025 P Kill Line Valves 4 3 1/8" & 2" P Pressure After Closure (psi)1550 P Check Valve 0 NA 200 psi Attained (sec)13 sec P BOP Misc 0 NA Full Pressure Attained (sec)69 sec P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):6 @ 2208 P No. Valves 15 FP ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 28 sec P #1 Rams 8 sec P Coiled Tubing Only:#2 Rams 7 sec P Inside Reel valves 0 NA #3 Rams 8 sec P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:3 Test Time:11 hours HCR Choke 3 sec P Repair or replacement of equipment will be made within days. HCR Kill 2 sec P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 10/08/22 12:20 Waived By Test Start Date/Time:10/11/2022 3:30 (date)(time)Witness Test Finish Date/Time:10/11/2022 14:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Lou Laubenstein Nabors Test Jt's 2 7/8", 3 1/2", 4", Test #5 MGV #8 leaked at 250 psi, service valve, retest 250/3500 psi - good test, Test #7 HCR Choke leaked at 3500 psi, service valve, retest 250/3500 psi - good test, Test #11 TD LWR IBOP leaked 3500 psi, function valve, retest 250/3500 psi - good test James Henson/Sean Holcomb ENI Justin Hays/Craig Smith Oooguruk ODSN-29 Test Pressure (psi): james.henson@nabors.com odsdrilling@eni.com Form 10-424 (Revised 08/2022)2022-1011_BOP_Nabors19AC_Oooguruk_ODSN-29 J. Regg; 12/2/2022 === === === === === === === === STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________OOOGURUK NUQ ODSN-29 JBR 12/22/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Tested with 2 7/8" and 4" test joints, tested all gas alarms and PVT's. HCR was a FP serviced and passed retest. Precharge bottles= 16 each. 2@900psi, 3@950psi, 2@975psi, 3@1000psi, 5@1050psi and 1@ ZERO. Bottle #4 has a bad bladder. They are getting ahold of Yellow Jacket to get it fixed. Test Results TEST DATA Rig Rep:M. Turcotte/S. HolcomOperator:Eni US Operating Co. Inc.Operator Rep:T. Ashley/C. Smith Rig Owner/Rig No.:Nabors 19AC PTD#:2121060 DATE:11/6/2022 Type Operation:WRKOV Annular: 250/2500Type Test:WKLY Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopBDB221108080650 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4.5 MASP: 2001 Sundry No: 322-448 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 11"P #1 Rams 1 2 7/8"x5"P #2 Rams 1 Blind/Shear P #3 Rams 1 2 7/8"x5"P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 3 3 1/8"P HCR Valves 2 3 1/8"FP Kill Line Valves 4 3 1/8 & 2"P Check Valve 0 NA BOP Misc 0 NA System Pressure P2900 Pressure After Closure P1600 200 PSI Attained P11 Full Pressure Attained P60 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P6@2092 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P23 #1 Rams P11 #2 Rams P11 #3 Rams P9 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P5 HCR Kill P5 FP Tested with 2 7/8" and 4" test joints, tested all gas alarms and PVT's. HCR was a FP serviced and passed retest. Precharge CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Reporting BOPE use to Prevent the Flow of Fluids from a Well Date:Thursday, October 20, 2022 12:54:11 PM Oooguruk ODSN-29 (PTD 2121060) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Thursday, October 20, 2022 11:14 AM To: Mbx ODSDrilling <ODSDrilling@eni.com>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: Pierfelici Stefano <Stefano.Pierfelici@eni.com>; Carballo Nelson <Nelson.Carballo@eni.com>; Ashley Timothy <Timothy.Ashley@external.eni.com>; Ashley Mark <Mark.Ashley@external.eni.com> Subject: RE: Reporting BOPE use to Prevent the Flow of Fluids from a Well Well is ODSN-29 (PTD 2121060), not N-39 as indicated below Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Mbx ODSDrilling <ODSDrilling@eni.com> Sent: Thursday, October 20, 2022 9:18 AM To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: Pierfelici Stefano <Stefano.Pierfelici@eni.com>; Carballo Nelson <Nelson.Carballo@eni.com>; Ashley Timothy <Timothy.Ashley@external.eni.com>; Ashley Mark <Mark.Ashley@external.eni.com> Subject: FW: Reporting BOPE use to Prevent the Flow of Fluids from a Well Please see the revised use of BOP. The report did not send last night when written due to computer problems. The changes are the Lower rams have been inspected and the 2”” bleeder as well as the ½” bleeder has been connected. Thanks, Tim Ashley Company Man ODS Rig 19 From: Mbx ODSDrilling Sent: Thursday, October 20, 2022 6:22 AM To: 'doa.aogcc.prudhoe.bay@alaska.gov' <doa.aogcc.prudhoe.bay@alaska.gov> Cc: Pierfelici Stefano <Stefano.Pierfelici@eni.com>; Carballo Nelson <Nelson.Carballo@eni.com>; Mbx ODSDrilling <ODSDrilling@eni.com> Subject: Reporting BOPE use to Prevent the Flow of Fluids from a Well Gentlemen: Date of BOPE Usage ; 19 October 2022 at approximately 08:30 Hrs. Well ODSN-39; Oooguruk Drilling Site. PTD is 212-106 Nabors 19E Contact JR Henson, number 907-670-6630 Operations Summary: Rig was performing weekly BOPE test. Inner annulus had a bleeder hose attached to it routed to a bleed trailer for monitoring the annulus during the testing. Annulus wasn’t full of fluid due to the well bore taking the 8.6# kill fluid utilized for workover operations. Fluid level was 1050’. 10 Bbls per hour of 8.6# kill fluid has been added to the annulus on schedule since workover operation commenced.. The lower pipe rams had been tested and a pressure check was performed utilizing the bleeder hose attached to the annulus.. Upon opening the lower rams the test joint was ejected up the BOPE Stack initially contacting the lower rams and ultimately coming all the way out of BOPS. The Blind rams were closed to secure the well. Well bore was lined up to the choke manifold and ZERO pressure observed.. Opened up to Gas buster and no gas observed. Visual inspection of lower rams has been conducted. A 2” bleeder hose has been connected to the annulus through the production header with low pressure digital gauge along with the smaller bleeder hose to bleed trailer. Crews will monitor continuously during the BOPE testing. Lower rams will be retested along with the Blind rams. Once completed the rig will continue testing BOPE with the 2 7/8” test joint. The annular will be tested to 3500 Psi. Mitigation plan to prevent reoccurrence of above incident has been generated. Once plan is in place BOPE testing will resume. Regards, Mark Ashley Drilling Supervisor ODS 907-670-6606 ------------------------------------------------------------------------------------------------------------------------- ----------------------------------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ 5HJJ-DPHV% 2*& )URP %HDUG6HWK 6HWK%HDUG#QDERUVFRP! 6HQW 0RQGD\2FWREHU 30 7R 5HJJ-DPHV% 2*& %URRNV3KRHEH/ 2*& '2$$2*&&3UXGKRH%D\ &F RGVGULOOLQJ#HQLFRP 0DGVRQ5REHUW +HQVRQ-DPHV 7XUFRWWH0DWWKHZ +ROFRPE6HDQ 6XEMHFW (%23(7(675(3257UHYLVHG $WWDFKPHQWV 1DERUV $&UHYLVHG[OV[ ^ŽƌƌLJĨŽƌƚŚĞŝŶĐŽŶǀĞŶŝĞŶĐĞĂŶĚƉůĞĂƐĞĚŝƐƌĞŐĂƌĚƚŚĞůĂƐƚĞŵĂŝů͘ WůĞĂƐĞƐĞĞĂƚƚĂĐŚŵĞŶƚĨŽƌƚŚĞƌĞǀŝƐĞĚKW dĞƐƚZĞƉŽƌƚ͘ 6HWK%HDUG EĂďŽƌƐϭϵ dŽŽůƉƵƐŚĞƌ 1$%256$/$6.$'5,//,1*,1& 3KRQH ,&HOO &ƌŽŵ͗ĞĂƌĚ͕^ĞƚŚф^ĞƚŚ͘ĞĂƌĚΛŶĂďŽƌƐ͘ĐŽŵх ^ĞŶƚ͗DŽŶĚĂLJ͕KĐƚŽďĞƌϯ͕ϮϬϮϮϭ͗ϮϲWD dŽ͗DďdžK^ƌŝůůŝŶŐфK^ƌŝůůŝŶŐΛĞŶŝ͘ĐŽŵх ^ƵďũĞĐƚ͗ZĞ͗ yd ZE>ϭϵ KW d ^dZ WKZdϭϬͲϯͲϮϬϮϮ ^ŽƌƌLJĨŽƌƚŚĞŝŶĐŽŶǀĞŶŝĞŶĐĞĂŶĚƉůĞĂƐĞĚŝƐƌĞŐĂƌĚƚŚĞůĂƐƚĞŵĂŝů͘ WůĞĂƐĞƐĞĞĂƚƚĂĐŚŵĞŶƚĨŽƌƚŚĞƌĞǀŝƐĞĚKW dĞƐƚZĞƉŽƌƚ͘ 6HWK%HDUG EĂďŽƌƐϭϵ dŽŽůƉƵƐŚĞƌ 1$%256$/$6.$'5,//,1*,1& 3KRQH ,&HOO &ƌŽŵ͗DďdžK^ƌŝůůŝŶŐфK^ƌŝůůŝŶŐΛĞŶŝ͘ĐŽŵх ^ĞŶƚ͗DŽŶĚĂLJ͕KĐƚŽďĞƌϯ͕ϮϬϮϮϭ͗ϭϲWD dŽ͗ĞĂƌĚ͕^ĞƚŚф^ĞƚŚ͘ĞĂƌĚΛŶĂďŽƌƐ͘ĐŽŵх ^ƵďũĞĐƚ͗ ydZ ͗ yd ZE>ϭϵ KW d ^dZ WKZdϭϬͲϯͲϮϬϮϮ 6RPHSHRSOHZKRUHFHLYHGWKLVPHVVDJHGRQ WRIWHQJHWHPDLOIURPVHWKEHDUG#QDERUVFRP/HDUQZK\WKLVLVLPSRUWDQW &$87,21 7KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNV RURSHQDWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH 2RRJXUXN2'61 37' &$87,21(PDLO([WHUQDOWR1DERUV_£35(&$8&,Ï1&RUUHRHOHFWUyQLFRH[WHUQRD1DERUV_ϲΟέΎΧϲϧϭέΗϛϟ·ΩϳέΑϪϳΑϧΗ ίέϭΑΎϧϰϟ· ZĞǀŝƐĞƚĞƐƚƌĞƉŽƌƚ Justin Hays ENI Drilling Supervisor ODS Office 907-670-6606 Cell 719-640-4012 &ƌŽŵ͗ĞĂƌĚ͕^ĞƚŚф^ĞƚŚ͘ĞĂƌĚΛŶĂďŽƌƐ͘ĐŽŵх ^ĞŶƚ͗DŽŶĚĂLJ͕KĐƚŽďĞƌϯ͕ϮϬϮϮϭϮ͗ϰϴWD dŽ͗ĂŽŐĐĐ͘ŝŶƐƉĞĐƚŽƌƐΛĂůĂƐŬĂ͘ŐŽǀ͖ũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀ͖ƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀ Đ͗DďdžK^ƌŝůůŝŶŐфK^ƌŝůůŝŶŐΛĞŶŝ͘ĐŽŵх͖DĂĚƐŽŶ͕ZŽďĞƌƚфZŽďĞƌƚ͘DĂĚƐŽŶΛŶĂďŽƌƐ͘ĐŽŵх͖,ĞŶƐŽŶ͕:ĂŵĞƐ ф:ĂŵĞƐ͘,ĞŶƐŽŶΛŶĂďŽƌƐ͘ĐŽŵх͖dƵƌĐŽƚƚĞ͕DĂƚƚŚĞǁфDĂƚƚŚĞǁ͘dƵƌĐŽƚƚĞΛŶĂďŽƌƐ͘ĐŽŵх͖,ŽůĐŽŵď͕^ĞĂŶ ф^ĞĂŶ͘,ŽůĐŽŵďΛŶĂďŽƌƐ͘ĐŽŵх ^ƵďũĞĐƚ͗ yd ZE>ϭϵ KW d ^dZ WKZdϭϬͲϯͲϮϬϮϮ 6HWK%HDUG EĂďŽƌƐϭϵ dŽŽůƉƵƐŚĞƌ 1$%256$/$6.$'5,//,1*,1& 3KRQH ,&HOO ΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎ 1$%256(0$,/127,&(7KLVWUDQVPLVVLRQPD\EHVWULFWO\SURSULHWDU\DQGFRQILGHQWLDO,I\RXDUHQRWWKHLQWHQGHG UHFLSLHQWUHDGLQJGLVFORVLQJFRS\LQJGLVWULEXWLQJRUXVLQJWKHFRQWHQWVRIWKLVWUDQVPLVVLRQLVSURKLELWHG,I\RXKDYH UHFHLYHGWKLVLQHUURUSOHDVHUHSO\DQGQRWLI\WKHVHQGHU RQO\ DQGGHOHWHWKHPHVVDJH8QDXWKRUL]HGLQWHUFHSWLRQRIWKLV HPDLOLVDYLRODWLRQRIIHGHUDOFULPLQDOODZ7KLVFRPPXQLFDWLRQGRHVQRWUHIOHFWDQLQWHQWLRQE\WKHVHQGHURUWKHVHQGHU V SULQFLSDOWRFRQGXFWDWUDQVDFWLRQRUPDNHDQ\DJUHHPHQWE\HOHFWURQLFPHDQV1RWKLQJFRQWDLQHGLQWKLVPHVVDJHRULQ DQ\DWWDFKPHQWVKDOOVDWLVI\WKHUHTXLUHPHQWVIRUDZULWLQJDQGQRWKLQJFRQWDLQHGKHUHLQVKDOOFRQVWLWXWHDFRQWUDFWRU HOHFWURQLFVLJQDWXUHXQGHUWKH(OHFWURQLF6LJQDWXUHVLQ*OREDODQG1DWLRQDO&RPPHUFH$FWDQ\YHUVLRQRIWKH8QLIRUP (OHFWURQLF7UDQVDFWLRQV$FWRUDQ\RWKHUVWDWXWHJRYHUQLQJHOHFWURQLFWUDQVDFWLRQV ---------------------------------------------------------------------------------------------------------------------------------------------------- -------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ ΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎ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ĞĐƵƌŝƚLJtĂƌŶŝŶŐ͗7KLVHPDLORULJLQDWHGIURPRXWVLGHRIWKHRUJDQL]DWLRQ'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXKDYHYHULILHGWKHVHQGHU¶VHPDLODGGUHVVDQGNQRZWKHFRQWHQWLVVDIH STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:19AC DATE: 10/3/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2121060 Sundry #322-448 Operation: Drilling: Workover: X Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:2001 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2 7/8" X 5"P Flow Indicator PP #2 Rams 1 Blind/Shear P Meth Gas Detector PP #3 Rams 1 2 7/8" X 5"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 3 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"P System Pressure (psi)3000 P Kill Line Valves 4 3 1/8" & 2" P Pressure After Closure (psi)1700 P Check Valve 0NA200 psi Attained (sec)12 sec P BOP Misc 0NAFull Pressure Attained (sec)60 sec P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 2133 P No. Valves 15 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 28 sec P #1 Rams 10 sec P Coiled Tubing Only:#2 Rams 9 sec P Inside Reel valves 0NA #3 Rams 9 sec P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:6 hours HCR Choke 4 sec P Repair or replacement of equipment will be made within days. HCR Kill 4 sec P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 9-30-22/23:11pm Waived By Test Start Date/Time:10/3/2022 2:30 (date) (time)Witness Test Finish Date/Time:10/3/2022 8:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nabors Tested Annular, Rams #1, Rams #3 with a 3.5" and a 4" test jt. Tested 1ea. 4" FOSV and 1ea. 4" dart valve. 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This well was completed in the Kuparuk during the RWO. The well was put on gas lift and saw IA pressures over the 2,000 psi sustained casing pressure rule for about 8 days as we fought what we believed to be a partially plugged orifice valve. In our attempt to unplug the orifice we pressured up the IA, fluid flushed, surged the tubing, and eventually pulled and replaced the orifice twice before seeing normal gas lift pressures under 2,000 psi. Please let me know if you need any additional information. Thank you. Keith Lopez Production Engineer, Subsurface Direct 907.343.2142 I Cell 907.903.5432 Caelus Energy Alaska 3700 Centerpoint br I Ste 500 I Anchorage, AK 99503 Keith.Lopez@caelusenergy.com I www.CaelusEnergy.com AE I._ SCANNED ,i From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, November 14, 2017 2:08 PM To: Keith Lopez Cc: Wallace, Chris D (DOA) Subject: RE: OU SVS Testing October 2017 [External Email Source] IA Pressure in ODSN-29 (PTD 2121060) exceeds the 2000psi notification threshold in sustained casing pressure rules (CO 597). Send a TIO pressure plot covering the timeframe post RWO startup to present. Jim Regg Supervisor, Inspections AOGCC 333 W.7h Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. 1 • • The unauthorized review,use or disclosure such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: Keith Lopez [mailto:Keith.Lopez@caelusenergy.com] Sent:Tuesday, November 14, 2017 11:01 AM To: Brooks, Phoebe L(DOA) <phoebe.brooks@alaska.gov>; Regg,James B (DOA) <iim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Cc: Oooguruk ProdSuper<03.ProductionSupervisor@caelusenergy.com>;Theresa Williams <Theresa.Williams@caelusenergy.com>; Keith Lopez<Keith.Lopez@caelusenergy.com> Subject: OU SVS Testing October 2017 10/11/17 ODSN-04—test after RWO ODSN-28—test after RWO 10/24/17 ODSN-16—test after RWO ODSN-29—test after RWO and recompletion Keith Lopez Production Engineer, Subsurface birect 907.343.2142 I Cell 907.903.5432 Caelus Energy Alaska 3700 Centerpoint br I Ste 500 I Anchorage, AK 99503 Keith.Lopez@caelusenergy.com I www.CaelusEnergy.com Ca' CAELLS 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. Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 2 • c 4.10 a) coNCL Z o0 (i) u u_ .® c • • r- rA I � 21 . p Xl v 41.7.A.. r > � 00 1. ... co LI meq. 0 cO 5,M p p Sp E 6 Q Q - SJ ® a a a N Vh N to !! N Un��uisiwi. eq :44'.rwya - O 6 �� N � `— - •io ,.!, pp 8 -.t °J '�' N' E O O Ll .:.. d E (6 .� •..:y. •.. Q V N Q. . -•..H... ro L .., .:.... •... ..... .rte L E U r�r....�....'�.......... :J, c E a a a a 47) •f6 Q -+...++..watccv......................... .... ..........::AT... 6 7 cJ--- a Cl Q H 3 - ter- _ L0 �. .......... M...... ' ..,� 1 a a a E 6 CO ... ......... zzz es f(1 rN� /�� :1 7. 41, t 5 5 p 4y ::: P e l Q1 Nzs' 11 • l •...M4Ll ... 0 Ll n- G 4 r. ..,f....Ufa... ami m T. V N N N N stun mit" 1 •11 in Z Z Z Z $ us mK as rTX o R PI E 2 d LL 10rn .t0 ❑� ❑) ❑) ❑� • • Ooo j Ohs. - Regg, James B (DOA) 74Zrano From: Regg,James B (DOA) Sent: Tuesday, November 14, 2017 2:08 PM To: 'Keith Lopez' \C f4 101+1,7 Cc: Wallace, Chris D (DOA) Subject: RE: OU SVS Testing October 2017 Attachments: SVS Oooguruk 10-24-17 Misc.xls IA Pressure in ODSN-29 (PTD 2121060) exceeds the 2000psi notification threshold in sustained casing pressure rules (CO 597). Send a TIO pressure plot covering the timeframe post RWO startup to present. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Keith Lopez [mailto:Keith.Lopez@caelusenergy.com] Sent:Tuesday, November 14, 2017 11:01 AM To: Brooks, Phoebe L(DOA) <phoebe.brooks@alaska.gov>; Regg,James B (DOA)<jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Cc: Oooguruk ProdSuper<03.ProductionSupervisor@caelusenergy.com>;Theresa Williams <Theresa.Williams@caelusenergy.com>; Keith Lopez<Keith.Lopez@caelusenergy.com> Subject: OU SVS Testing October 2017 10/11/17 ODSN-04—test after RWO ODSN-28—test after RWO SCANNE® Is f 10/24/17 ODSN-16—test after RWO ODSN-29—test after RWO and recompletion Keith Lopez Production Engineer, Subsurface Direct 907,343,2142 I Cell 907,903.5432 Caelus Energy Alaska 3700 Centerpoint br I Ste 500 1 Anchorage, AK 99503 Keith.Lopez@caelusenergy.com www.CaelusEnergy.com 1 • @CAELES Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 2 0 • \ 2 0 0 / / x x / \ 0.4 z o ` ® x / y et \ \ / \ / 0 - z 0 \ ¥ L. \ / \ 1.00 Up 71- w r--- i. / C \ / k7 & \ \ C . 2 $ \\ / _ 5 0 / \/ \ \ \ \ \ a ) 2 - /t to = / ¥ 2 z % _ / � / ti 0 tJ / } \ \ t @ \/ \\ \ 0. 01.\ 0 t \ k / % _ _ o ) - 0 = = 0 f 4 \ •/ ) ! 3 \ $ 7 / { / / _ _ $ \ \ 0 2 ¥ 2 % 4. 0 0 "0 > z 0. N o c 2 f $ / 7 \ a : 2 2 / 4 } a 7 7 0 / / / , 0 ILO/ 0 \ \ \ tt / \ \ U / & z 0 0 § & & _ &- / 2 ' n \ / 2 2 11 G £ c © Q 244 =` § 3 2 .. 2 0 \ / /� � ~ ~ . / o / / t. % k / _ cC _ \ \ \ k 0 0 STATE OF ALASKA AIL OIL AND GAS CONSERVATION COM SION 'in ` . REPORT OF SUNDRY WELL OPERATIONS ¢ 1 f 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well❑ Other:Perf Kup C/Run GL 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Caelus Natural Resources Alaska,LLC Development 0 Exploratory❑ 212-106 3.Address: 3700 Centerpoint Drive,Suite 500 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-703-20661-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 355036/ADL 389958 ODSN-29 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Oooguruk-Nuiqsut Oil Pool/Kuparuk Oil Pool 11.Present Well Condition Summary: Total Depth measured 15,716 feet Plugs measured 8,595 feet true vertical 6,430 feet Junk measured N/A feet Effective Depth measured 15,706 feet Packer measured See attachment,pg.3 feet true vertical 6,430 feet true vertical See attachment,pg.3 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 4,101' 11-3/4" 4,140' 3,544' 5,830 psi 3,180 psi Intermediate 3,314' 9-5/8" 7,238' 5,506' 5,750 psi 3,090 psi Production 9,721' 7" 9,759' 6,430' 7,240 psi 5,410 psi Liner 6,182' 4-1/2" 15,706 6,430 8,430 psi 7,500 psi Perforation depth Measured depth See attachment,pg.2 feet CANNED I y True Vertical depth See attachment,pg.2 feet Tubing(size,grade,measured and true vertical depth) 3-1/2",9.2# TC-ll 9,538'MD 6,414'TVD Packers and SSSV(type,measured and true vertical depth) See attachment,pg.3 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 437 358 0 772 323 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil LJ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ 3USP0 SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Numbeor N/A if C.O.Exempt: 317-248 Authorized Name: Rami Jasser Contact Name: Rami Jasser Authorized Title: Senior Staff Compl io,i ngineer Contact Email: ram i.lasser( caelusenerov.com Authorized Signature: /.d` e0 / f l fi907-343-2182 g / df Date. / / Contact Phone: l/./6./ / -,�, Form 10-404 Revised 4/2017 RBDIS OCT 1 7 2U'i Submit Original Only 4,04 10517 • • Attachment 2 AOGCC Form 10-404 Sundry Report Box 11 - Perforation Locations Well: ODSN-29 „ M . Top (MD) Top (TVD) Baker Multi-Point Frac Sleeve w/segmented ball seat 10,179 6,445 Baker Multi-Point Frac Sleeve w/segmented ball seat 10,336 6,444 Baker Multi-Point Frac Sleeve w/segmented ball seat 10,750 6,433 Baker Multi-Point Frac Sleeve w/segmented ball seat 10,909 6,430 Baker Multi-Point Frac Sleeve w/segmented ball seat 11,379 6,415 Baker Multi-Point Frac Sleeve w/segmented ball seat 11,537 6,410 Baker Multi-Point Frac Sleeve w/segmented ball seat 12,231 6,407 Baker Multi-Point Frac Sleeve w/segmented ball seat 12,389 6,409 Baker Multi-Point Frac Sleeve w/segmented ball seat 12,903 6,415 Baker Multi-Point Frac Sleeve w/segmented ball seat 13,059 6,409 Baker Multi-Point Frac Sleeve w/segmented ball seat 13,726 6,417 Baker Multi-Point Frac Sleeve w/segmented ball seat 13,883 6,423 Baker Multi-Point Frac Sleeve w/segmented ball seat 14,263 6,425 Baker Multi-Point Frac Sleeve w/segmented ball seat 14,421 6,428 Baker Multi-Point Frac Sleeve w/segmented ball seat 14,786 6,429 Baker Multi-Point Frac Sleeve w/segmented ball seat 14,944 6,431 Baker Multi-Point Frac Sleeve w/solid ball seat 10,410 6,442 Baker Multi-Point Frac Sleeve w/solid ball seat 11,067 6,427 Baker Multi-Point Frac Sleeve w/solid ball seat 11,612 6,408 Baker Multi-Point Frac Sleeve w/solid ball seat 12,506 6,409 Baker Multi-Point Frac Sleeve w/solid ball seat 13,217 6,402 Baker Multi-Point Frac Sleeve w/solid ball seat 13,957 6,423 Baker Multi-Point Frac Sleeve w/solid ball seat 14,495 6,428 Baker Multi-Point Frac Sleeve w/solid ball seat 15,102 6,432 Pressure Activated Sleeve B 15,644 6,429 Pressure Activated Sleeve A 15,698 6,430 • • Attachment 3 AOGCC Form 10-404 Sundry Report Box 11 - Packers & SSSV Well: ODSN-29 SSSV MD TVD 3-1/2"TRMAXX 5E-SSSV w/2.813" X Profile 2,092 2,029 PACKERS Baker 3-1/2" x 7" Premier Retrievable Packer 8,080 6,034 Baker 5" x 7" ZXP Liner Top Packer w/Flex Lock Hanger 8,476 6,248 Baker 5" x 7" ZXP Liner Top Packer w/Flex Lock Hanger 9,524 6,413 Baker ECP Packer 9,949 6,364 Baker ECP Packer 10,647 6,365 Baker ECP Packer 11,178 6,367 Baker ECP Packer 12,017 6,366 Baker ECP Packer 12,701 6,355 Baker ECP Packer 13,370 6,355 Baker ECP Packer 13,508 6,354 Baker ECP Packer 14,110 6,343 Baker ECP Packer 14,648 6,344 Baker ECP Packer 15,249 6,345 • • G CAE J 1 (aSXl.a Operations Summary Report- State Well Name: ODSN-29 Well Name: Contractor: Rig Number: Job Category: Start Date: End Date: Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 7/28/2017 7/29/2017 0.0 00:00 7/28/17-00:00 7/29/17(Pre-RWO) *Complete well handover from Ops to Wells Group. *LRS freeze protected tubing w/40 bbls of diesel. *MIRU HES Slickline w/.125 wire. *Drifted w/3.83"gauge ring to SVLN @ 2,061'slm. *Pulled 4.5"FXE SSSV from SVLN @ 2,061'slm. *Drifted w/3.79"gauge ring to XN nipple @ 8,507'slm. *Set 4.5"Evo-Trieve RBP in center of first full tubing joint above XN nipple©8,478'slm. *Set 4.5"catcher sub on top of 4.5"Evo-Trieve @ 8,475'slm. *Pulled 1"Orifice GLV(BK)from GLM#1 @ 7,852'slm.Valve is flow cut in half,recovered top half of valve.Inform Anchorage team. *Pulled 1"Dome GLV(BK)from GLM#2 @ 6,359'slm. *Pulled 1"Dome GLV(BK)from GLM#3©4,267'slm. 7/29/2017 7/30/2017 0.0 00:00 7/29/17-00:00 7/30/17(Pre-RWO) *Pulled 1"Dome GLV(BK)from GLM#4 @ 2,215'slm. *Set 1"Dummy GLV(BK)in GLM#4 0 2,215'slm. *Set 1"Dummy GLV(BK)in GLM#3 @ 4,267'slm. *Set 1"Dummy GLV(Bttm Latch)in GLM#2 @ 6,359'slm. *Pulled 4.5"catcher sub from 8,475'slm.(C-sub empty) *LRS loaded IA x Tubing w/250 bbls of seawater w/additives as per program while taking returns up tubing to Ops flowback tanks.LRS followed seawater with 100 bbls of diesel down IA. *LRS performed Combo MIT-T x IA to 2000 psi for 30 minutes.Test passed on second attempt. Lost 72 psi first 15 min,lost 36 psi second 15 min. *U-tube 40 bbls of diesel freeze protect from IA to Tubing.(2500') *Bleed T x IA pressures down to 200 psi. *GE installed BPV in tubing hanger utilizing hydraulic lubricator. *Complete well handover from Wells to Ops. ***Nabors 19 AC Well Satus:Evo-Trieve RBP set 0 8,478'slm,T x IA freeze protected w/diesel to 2500',treated seawater 2,500'-7,856',GLM#1 has empty pocket,GLM#2-4 Dummy GLV5, BPV installed in tubing hanger&void tested to 5000 psi.*** 8/27/2017 8/28/2017 0.0 8.50 Accept rig on ODSN-29 at 00:00 on 8-27-2017 Freeze protect ODSN-31 down IA and up tubing with 115bbls of diesel Install TWC on ODSN-31 MDRO ODSN-31 to ODSN-29 Pull ODSN-29 BPV Circ out 100bbI freeze protection ND Tree,Install BPV, Install test dart,NU BOPE AOGCC Rep Chuck Scheve waived witness of ODSN-29 BOPE test at 10:44 hrs on 8-27-2017 8/28/2017 8/29/2017 0.0 8.50 PU BOPE test tools and fill lines with seawater �2 Phi Test BOPE Der AOGCC PTD: -Test 1,Annular w/2-7/8"test joint to 250 psi low/2500 psi high. Passed -Test 2-6,Choke manifold to 250 psi low/3500 psi high.Passed -Test 7,Choke manifold to 250 psi low/3500 psi high.Passed -Test 8-9,Upper and lower 2-7/8"x5"VBR w/4"test joint to 250 psi/3500 psi. Passed -Test 10-11,Upper and lower IBOP valves to 250 psi low/3500 psi high.Passed -Test all floor valves to 250 psi low/3500 psi high. Passed -Test 12,Blind rams.250 psi low/3500 psi high.Passed AOGCC Rep Chuck Scheve waived witness of ODSN-29 BOPE test at 10:44 hrs on 8-27-2017 Pull Test dart and BPV Circ 421 bbl down tubing and back through IA into flowback tank. RU HAL Slickline and pull Evo-Trieve plug at 8,482'SLMD Bullhead 150bbls down tubing RD HAL slickline Pull 4-1/2"frac completion hanger Page 1/7 Report Printed: 10/13/2017 • • Operations Summary Report- State Well Name: ODSN-29 AELL y� Alaska Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Iblgal) Summary 8/29/2017 8/30/2017 0.0 8.50 Cont to attempt to pull out of seal assembly at 9,538' -Footage gains continued to be inconsistent and not continuous. RU ExPro lubricator to shootstring shot -Run#1 Stringshot unable to pass through lubricator due to excessive centralization H2S alarm on rig -Evac to muster point while evaluating situation -H2S alarm determined to be false,return to work Run#2 RIH with stringshot to 8,807'ELMD -Stringshot charge did not fire Run#3 RIH with stringshot charge to 8,890'ELMD � � -Confirm stringshot fired ' RD ExPro Pull out of seal assembly at 9,538' 30min flow check POOH with 4-1/2"13.5#P-110 Hydril 521 completion 9,512'to 5,855' -Cont to fill IA with seawater,5bbls/30min plus 150%pipe displacement 8/30/2017 8/31/2017 0.0 8,600.00 8.50 POOH with 4-1/2"13.5#P-110 Hydril 521 completion 5,855'to surf Install 6.375"wear ring BOPE kick drill -2.5 minutes RIH with cleanout BHA on 4"DP to 8,600'. Circ and POOH -Cont to fill IA with seawater,5bbls/30min plus 150%pipe displacement 8/31/2017 9/1/2017 62.0 8.50 POH.LD BHA.Remove wear bushing. Install junk basket.Function all rams.Install Wear Bushing(ID 6.375")PU csg running tools and jewelry.Troubleshoot GBR Torque Turn.TIH w/3 1!2'9 2 ppf TC-II Liner Cop'letionvt/957'.Trouble shoot the XN nipple jt. TIH w/3 1/2"-0 2 ppf"- TC-II Liner Completion f/957't/1200'.C/O elevators.RIH w/3 1/2"9.2 ppf TC-II Liner Completion on 4"xt-39 Dp f/1200'U9533'.P/U single&Tag Liner top @ 9548'.Confirm tag depth.Drop 1 5/8"blue frac ball.Pump 278 stks @ 2bpm/1600psi.Slack off U80K to confirm liner hanger set.Bleed off pressure.R/U test pump.Pressure up in stages U 4500psi.Set ZXP Liner top packer @ 8465'.Pick up to previous 227K PU wt. --Released.Fill backside&test packer through kill U 3500 psi for 5 mins.Run back in to verify ZXP packer set.P/U 8'to close sleeve.Line up to Combo test IA and Tubing.Test Combo IA&Tubing to 3500 psi for 30 mins. 9/1/2017 9/2/2017 0.0 10.00 Finish Testing Combo IA&Tubing to 3500 psi for 30 mins.POH w/Running Tool on 4"DP f/ 8493't18366'.Displace well f/8.5 ppg sea water U 10.0 ppg KW Brine.Cut&Slip DL.Circulate 10.0 ppg Brine due to U-Tube up DP.POH w/Running Tool on 4"DP f/8366'U 6020'.Change out dies in Iron Roughneck.POH w/Running Tool on 4"DP f/6020'U BHA'.L/D Running Tool BHA.Hold PJSM to R/U&Run E-Line.R/U&Run E-Line CBL&CCL GR.Send logs to Caelus Office for evaluation.Hold PJSM to R/U SLB TCR.P/U&stage SLB TCP tools on rig floor&pine shed. ..✓� • L 9/2/2017 9/3/2017 0.0 8,480.00 10.05 P/U& (u.SLZ TCP Perforation Guns per SLB Supervisor f/surface U 335'.TIH w/TC�Perf � Guns f/335'U 8474'on 4"DP.Tag Liner top @ 8474'.Perform Space Out to ensure Pure Chambers will be placed across perf interval without L/D DP.P/U 39.5'for perf interval f/8271'U 8340'.Perform Perforation per SLB TCP Program.Good indications that guns fired.P/U drill string 75'.Good indications that Pure Chambers fired.TOH 3 stands U 8259'.Monitor well.Static loss rate @ 6 bph.TON w/TCP BHA on 4"DP f/8259'U 335'.Observed static losses increase U 21 bph average over TOH.L/D SLB TCP Perforation Guns per SLB Supervisor f/335'surface. All perforation shots fired.Clean&Clear rig floor of Perf handling equipment.P/U&stage Clean Out BHA tools on rig floor. NOTE: Provided 24 hour notice to AOGCC for BOPE test on 9/3/17 to AOGCC representative Brian Bixby. Page 2/7 Report Printed: 10/13/2017 • • CA[� �1� j Ataska Operations Summary Report- State Well Name: ODSN-29 E 1..J Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 9/3/2017 9/4/2017 0.0 8,474.00 10.00 P/U&M/U Clean Out BHA U 813'per Baker Rep.TIH w/Clean Out BHA on 4"DP f/813'U 8474'.Tag Liner top w/Dress off Mill @ 8474'.Dropped 9/16"ball for RSJB on std#79.Circulate &condition 1 DP volume to clean Liner top.POH w/Clean Out BHA f/8474'U 84'.L/D Clean Out BHA f/813'to surface per Baker Rep. Reverse circ BHA per Baker Rep. R/U to pull wear bushing.Clean&Clear rig floor.Rebuild&Replace 4 way valve on accumulator.4 way Valve not holding.Plan to continue BOPE testing per AOGCC inspector Brian Bixby. Begin testing BOPE per AOGCC PTD: -Test 2-15 choke manifold valves to 250 psi low/3500 psi high.Passed -Test Hand Choke.Failed. --Begin repair same. *All tests charted and all tests held for 5 min. *All tests performed with 8.5 ppg seawater. ***AOGCC Inspector Brian Bixby witnessed BOPE test.*** 9/4/2017 9/5/2017 8,474.0 0.00 9.80 Cont testing BOPE per AOGCC PTD:Test Super Choke to 2500 psi high.Attempt to test Hand Choke.Failed.All tests charted&all tests held for 5 min. All tests performed with 8.5 ppg seawater.***AOGCC Inspector Brian Bixby witnessed BOPE test.***Pull VG wear bushing.Inst junk bskt.Function rams.Flush stk.Remove junk bskt. Inst VG test plug w/3.5"test joint. Repair Koomey press switch.Cont testing BOPE per AOGCC PTD.Test choke valve#15 to 250 psi low/3500 psi high.Test blind rams,upper&lower 2 7/8"x 5"VBR to 250/3500.Test upper& lower IBOP valves to 250 psi low/3500 psi high.Upper IBOP test failed.Test annular to 250 psi low/2500 psi high.Test all floor valves to 250 psi low/3500 psi high.All tests charted&all tests held for 5 min.***AOGCC Inspector Brian Bixby witnessed BOPE test.***Pull VG test plug w/ 3.5"test joint.Fill hole&close blinds.Continue BOPE repairs.C/O upper pipe rams 4 way valve on the Koomey.Valve cont leaking.C/O upper IBOP.Install new seal on hand choke.Inst new seat&paddle for valve#1 on the choke manifold.Inst VG test plug w/3.5"test joint.Cont test BOPE per AOGCC PTD.Retest upper IBOP valves to 250 psi low/3500 psi high.Passed.Retest choke manifold valve#1 to 250 psi low/3500 psi high.Passed.Retest Hand Choke.Passed.All tests charted&all tests held for 5 min.***AOGCC Inspector Brian Bixby waived witness this portion of BOPE test.***Pull VG test plug w/3.5"test joint.Cont trouble shooting Koomey leak at 4 way valve.C/O piston seals on upper pipe rams x 4.Stopped 4 way valve leak.Inst VG test plug w/3.5"test joint.Function test upper pipe rams.Perform draw down test on Koomey.*Initial system psi:3000;2100 after closure;200 psi=23 sec,full pressure 129 sec.BOPE testing complete. 9/5/2017 9/6/2017 8,474.0 0.00 9.80 RAJA°run 3 1/2"Upper CompletionyString..Hold PJSM w/all parties.RIH w/3 1/2"Upper Completion String U 3021'.Nabors Beard Crew performed Kick while Tripping drill.RIH w/3 1/2" Upper Completion String f/3021'U 8425'. 9/6/2017 9/7/2017 8,474.0 0.00 8.50 RIH w/3 1/2"Upper Completion String f/8425'U 8465',Slowly enter liner top with guide shoe. Locate no-go on PBR.S/O 10,000 lbs.Calculate space-out.L/D 4 jts 3'/2"Tbg.RIH w/14.75" pup,&2 Jts 3%2"Tbg.VG M/U Tubing Hanger.Connect feed through for TRSV Control, Pressure,Temp lines.M/U landing joint to tubing hanger.Pressure test control,pressure, temperature lines.Pump—50 bbls 9.8 brine w/Corrosion Inhibitor down IA.Work seal assembly into the PBR.Land hanger. VG run in LDS.Test tubing hanger seals to 10,000 psi.Test Tbg to 500 psi for 5 mins to confirm seals are stabbed in.Set packer per Baker Hughes rep:Increase Tbg pressure to 3500 psi.Chart same and hold for 30 min.Bleed down to 2500 psi.Increase pressure on the IA to 3500 psi.Chart same and hold for 30 min.Bleed tubing pressure down to zero&shear out valve.Pump fluid both ways to confirm communication.L/D landing jt.VG install 2-way check into tubing hanger.Pressure up IA to 1500 psi to test two way check.C&C rig floor of 3rd party equipment.N/D BOPE.N/U 10,000 psi FracTree.Pressure test hanger void U 5000 psi/5 min.Pressure test tree to 10,000psi/5min,R/U Expro lubricator.VG pull TWC.Ops& Little Red freeze protect well w/93 bbls diesel.Install jumper line to allow diesel to U-Tube. Begin RDMO ODSN-29. Release rig from ODSN-29 at 23:59 on 9-6-2017 NOTE: Provided 24 hour notice to AOGCC for BOPE test on 09-07-2017 1:00 PM. Page 3/7 Report Printed: 10/13/2017 CArl • ! Operations Summary Report- State Well Name: ODSN-29 Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud db/gat) Summary 9/22/2017 9/23/2017 8,474.0 0.00 8.50 00:00 9/22/17-00:00 9/23/17(Post-RWO) *Completed well handover from Operations to Wells Group. *GE pulled Two Way Check from tubing hanger utilizing hydraulic lubricator. *MIRU HES Slickline w/.125 wire and HES recommended toolstring. *Set 3.5"Bait sub,2'weight,&2.70"cent in BHI SS @ 8,490'slm.(C-sub) *Pulled 1"DCK Shear Valve(BEK)from GLM#2 @ 3,721'slm. *Set 1"Dummy GLV(BK)in GLM#2 @ 3,721'slm. *LRS MIT-Tubing to 2500 psi for 30 minutes.Good test. *Pulled 1"Dummy GLV(BK)from GLM#1 @ 7,809'slm. *Set 1"Orifice GLV(BK,1/4")in GLM#1 @ 7,809'slm. *LRS MIT-Tubing to 2500 psi for 30 minutes.Good test. *Slickline crew layed down for the night. 9/23/2017 9/24/2017 8,474.0 0.00 8.50 00:00 9/23/17-00:00 9/24/17(Post-RWO) *MIRU HES Slickline w/.125 wire. *Attempt to pull 3.5"baited catcher sub assembly @ 8,484'slm,unable to latch. *Ran 10'of 2.25"pump bailer to 8,484'slm.Recovered 2 gallons of black thick debris,possibly pipe dope.Take sample. *Ran 10'of 2.25"pump bailer to 8,487'slm.Work bailer and pull out of hole.On surface w/bailer pump rod.Threads on pump rod pulled. ***10'of 2.25"bailer barrel left in hole w/1-3/8"fishing neck on bailer top sub as per HES*** *Discuss plan forward w/Anchorage team. *Attempt to fish 10'of 2.25"bailer w/2.60"Bellguide&2"RS.Unable to get latched @ 8,478' slm. *Ran multiple fishing assemblies and lead impression blocks.Tools appear to be getting to the side of 2.25"bailer fishing neck.Run tally on middle completion shows 5.25"-4.25"ID at 8,478' slm. *Slickline crew layed down for the night.Will continue fishing operations in the morning. 9/24/2017 9/25/2017 8,474.0 0.00 8.50 00:00 9/24/17-00:00 9/25/17(Post-RWO) *MIRU HES Slickline w/.125 wire. *Ran stiff Bow Spring Centralizer w/2.62"Bellguide w/2"RS to 8,479'slm.Unable to latch fish. *Discuss plan forward w/Anchorage team. *Ran Knuckle Joint,2.60"Decentralizer,2.75"centralizer,&2.75"Lead Impression Block to 8,479'slm. Impression shows partial FN on high side of block @ 1:00 looking downhole. *Ran multiple fishing assemblies and lead impression blocks.Metal marks on fishing tools indicate they are getting to the side of 2.25"bailer fishing neck. Run tally on middle completion shows 4.36"ID at 8,479'slm/8,483'MD. *Sat down in BHI sliding sleeve @ 8,129'slm,+4'correction to measured depth.This would indicate fish depth of 8,479'slm/8,483'MD=5"x 7"BOT ZXP Liner Top Packer @ 8,476.28' MD-8,485'MD. ***10'of 2.25"bailer barrel in hole w/1-3/8"fishing neck on bailer top sub as per HES*** *Slickline crew layed down for the night.Will continue fishing operations in the morning. 9/25/2017 9/26/2017 8,474.0 0.00 8.50 00:00 9/25/17-00:00 9/26/17(Post-RWO) *MIRU HES Slickline w/.125 wire. *Ran Double Bow Spring Centralizer w/2.70"Mule Shoe Bellguide w/tattle tale pins to 8,479' slm.Jar down to get over fish.On surface tattle tale pins indicate bellguide not getting over fishing neck.Metal marks indicate FN off to one side. *Discuss plan forward w/Anchorage team. *Made several attempts to latch 2.25"bailer w/2.70"Obannon Overshot,unable to get bite on fishing neck.Ran overshot on double knuckle joint then on Bow Spring Centralizer.Metal marks indicate getting next to FN. *Ran multiple fishing assemblies and lead impression blocks.Metal marks on fishing tools indicate they are getting to the side of 2.25"bailer fishing neck. *Slickline crew layed down for the night.Continue fishing operations in the morning. ***10'of 2.25"bailer barrel in hole @ 8,479'slm w/1-3/8"fishing neck on bailer top sub as per HES.*** ***2.70"Baitsub,2'weight bar,&2.70"centralizer set @ 8,490'slm as catcher sub*** Page 4/7 Report Printed: 10/13/2017 i • Ca c AEU Operations Summary Report- State Well Name: ODSN-29 1� a t�li7sla.a Start Depth FootrMeters Dens Last Start Date End Date (ftKB) (ft) Mud(Ibrgal) Summary 9/26/2017 9/27/2017 8,474.0 0.00 8.50 00:00 9/26/17-00:00 9/27/17 (Fish 2.25"Bailer) *MIRU HES Slickline w/.125 wire. *Ran KJ,2.70"Cent,&2"SB w/2.60"welded bellguide to fish @ 8,479'slm. Unable to latch fish. *Discuss plan forward w/Anchorage team. *Secure well.RDMO HES Slickline&move over to ODSN-16. ***10'of 2.25"bailer barrel in hole @ 8,479'slm w/1-3/8"fishing neck on bailer top sub as per HES.*** ***2.70"Baitsub,2'weight bar,&2.70"centralizer set @ 8,490'slm as catcher sub*** 9/28/2017 9/29/2017 8,474.0 0.00 8.50 00:00 9/28/17-00:00 9/29/17 (Fish 2.25"Bailer) *Mobilize fishing tools via HES Slickline service leader to ODS. *MIRU HES Slickline w/.125 wire. *Ran KJ,5'x 1.875"STM,KJ,Bow Spring Centralizer, 11"ext w/2.00"LIB.Tag at 8,481'slm. indication of getting beside the 2.25"Bailer. *Discuss With The Anchorage team. *Ran KJ,5'x 1.875"STM,KJ,Bow Spring Centralizer,6"ext w/2.70"LIB.Tag at 8,478'slm. Imprint of 1/3 of fishing neck.Unable to get a clear picture of entire fishing neck. *Discuss With The Anchorage team. *Ran KJ,5'x 1.875"STM,KJ,Bow Spring Centralizer,O'bannon overshot(1 3/8"fishing neck Dye).Tag at 8,478'slm.Unable to latch the fish. *Lay down HES Slickline for the night. 9/29/2017 9/30/2017 8,474.0 0.00 8.50 00:00 9/29/17-00:00 9/30/17 (Fish 2.25"Bailer) *MIRU HES Slickline w/.125 wire. "Ran KJ,Swivel,D-Centralizer,Clock,OM-1 (trayless),4"Ext w/2.25"LIB.Kick out arm at 8,440'slm,tag fish at 8,480'slm.Clock was set at 01:00.Confirmed imprint of fishing neck at 9 O'clock. *Discuss With The Anchorage team. *Ran KJ,Swivel,D-Centralizer,Clock,OM-1 (trayless)w/2.53"belled 2"JD.Clock set at 11:00. Tag the fish at 8,478'slm.Unable to latch. *Discuss With The Anchorage team. *Ran KJ,Swivel,D-Centralizer,Clock,OM-1 (trayless),w/2.53"belled 2"JD.Clock set at 09:00. Tag the fish at 8,481'slm.See hit a 800#and 1200#OJ lick.Pull free. POOH to surface.No fish. Metal marks on belled JD at 01:00. *Discuss With The Anchorage team. *Ran KJ,Swivel,D-Centralizer,Clock, OM-1 (trayless w/double kick springs),w/2.53"belled 2" JD.Clock set at 01:00.Tag the fish at 8,481'slm. Pull free.POOH to surface. No fish.Metal marks on belled JD at 01:00 KOT arm broke over. *Discuss With The Anchorage team. *Ran KJ,Swivel,D-Centralizer,Clock, OM-1 (trayless w/double kick springs),w/2.53"belled 2" JD.Clock set at 01:00.Tag the fish at 8,481'slm. Pull free.POOH to surface.No fish.Metal marks on belled JD at 01:00 KOT arm broke over with brass x brass pins in arm. *Lay down HES Slickline for the night. 10/1/2017 10/2/2017 8,474.0 0.00 8.50 00:00 10/1/17-00:00 10/2/17 (Fish 2.25"Bailer) *MIRU HES Slickline w/.125 wire. *Ran KJ,Swivel,D-Centralizer,Clock,OM-1 (trayless),w/2.53"belled 2"JD.Clock set at 12:00. Tag the fish at 8,482'slm. Pull free.POOH to surface.No fish. Metal marks on belled JD at 09:00 KOT arm not broke over.All steel pins in the arm. *Ran KJ,Swivel,D-Centralizer,Clock,OM-1 (trayless),w/2.53"belled 2"JO.Clock set at 9:00. Tag the fish at 8,482'slm. Pull free.POOH to surface.No fish.Metal marks on belled JD at 01:00 KOT arm not broke over.All steel pins in the arm. *Ran 2.33"Centralizer,and 8'of 1.25"Drive Down bailer.Tag fish at 8,78'slm.work bailer for 10 min POOH to surface.Marks on 2.33"Centralizer indicating the bailer went 8'past the fishing neck.2 cups of debris recovered. *Ran 20'of 2.625"dummy guns w/2.53"bell guided SB.Tag fish at 8,478'slm.Tag 15 times. Unable to latch.POOH.Marks on the face of the 2.53"bell guide indicating fish is still on the sidewall of TBG. *Rig down HES slickline to enable Nabors 19AC to move to ODSN-17. Page 5/7 Report Printed: 10/13/2017 • • CAEE LU Operations Summary Report- State Well Name: ODSN-29 AEaska Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 10/6/2017 10/7/2017 8,474.0 0.00 8.50 00:00 10/6/17-00:00 10/7/17 (Fish 2.25"Bailer) *MIRU HES Slickline w/.125 wire. *Ran 2.3"Swage, 10'x 1.5"stem and a 2.00"LIB.Tag fish at 8,482'slm.POOH no marks indicating 3.5"Bait sub beside the 2.25"Fish. *Ran 2.62"Swage,3'x 1.5"stem,TBG end locator and 2.70"cent.Locate the fish at 8,481'slm. Pick up to 3.5"TBG tail XO at 8,459'slm.This verifies the fish is in the 4.36"ID. *Ran Swivel, De-Centralizer,Clock at 12:00,3.5"OM-1 (trayless)and 2.73"Steel wedge.Tag fish at 8,480'slm and jar down 30 times in attempt to re-orient the fish.POOH Metal marks on the steel wedge face. *Ran swivel,De-Centralizer and 2.75"LIB.POOH,Verify that the fish is sitting at 09:00. *Ran Swivel,De-centralizer,Clock at 03:00,OM-1 (Trayless)w/2.7"muleshoe bellguide and 2.3"0 bannon.Tag fish at 8,481'slm Unable to latch.POOH.Once on surface there was metal marks at the 09:00 on the 2.70"bell guide.Tool was oriented wrong.Disassemble the tool and ensure all HES on location verifies the de-centralizer position. 10/7/2017 10/8/2017 8,474.0 0.00 8.50 00:00 10/7/17-00:00 10/8/17 (Post RWO) *MIRU HES Slickline w/.125 wire. *Ran Swivel,De-centralizer,Clock at 09:00,OM-1 (Trayless)w/2.7"muleshoe bellguide and 2.3"0 bannon.Tag fish at 8,481'slm Unable to latch.POOH.Once on surface there was metal marks at the 10:00 on the 2.70"bell guide. *Ran Swivel,De-centralizer,Clock at 11:00,OM-5(Trayless)w/2.7"muleshoe bellguide and 2.3"0 bannon.Tag fish at 8,481'slm Unable to latch.POOH.Once on surface there was metal marks at the 01:00 on the 2.70"bell guide. *Ran Swivel,De-centralizer,Clock at 01:00,OM-5(Trayless)w/2.7"muleshoe bellguide and 2.3"0 bannon.Tag fish at 8,481'slm.Latch the fish and hit 10 1000#OJ licks.Fish pulls free. POOH to surface. *2.25"Bailer on surface.***Fish retrieved*** *Lay down HES S/L and clean/return all fishing tools. 10/8/2017 10/9/2017 8,474.0 0.00 8.50 00:00 10/8/17-00:00 10/9/17 (Post RWO) *MIRU HES Slickline w/.125 wire. *Bail fill with a 10'x 2.50"Drive Down bailer,work tools from 8,484'slm to 8,485 slm.POOH inspect tools.Metal marks match a 3.5"fishing neck. *Bail fill with a 2.30 swage and 10'x 2.00"Pump bailer,work tools from 8,485 slm to 8,489'slm. Metal marks on the 2.00"pump bailer indicating we got inside the 3.5"bait sub with"soupy" returns recovered,no solid returns. *Ran a KJ and 3.5"GR.Latch the 3.5"bait sub,jar for 10 min and pull free.S/L operator is convinced the bait sub has been pulled.No Bait sub on tool when on surface.GR pin sheared. *Ran a KJ and 3.5"GR.Latch the 3.5"bait sub,jar for 25 min with OJ licks with a maximum OJ lick at 1700#.Pin shears on the GR,bait sub did not move. *Ran a KJ and 3.5"GR.Latch the 3.5"bait sub,jar for 25 min with OJ licks with a maximum OJ lick at 1700#.Pin shears on the GR,bait sub looked like it moved 1'possibly. *Lay down HES S/L and clean/return all fishing tools. 10/10/2017 10/11/2017 8,474.0 0.00 8.50 00:00 10/10/17-00:00 10/11/17 (Post RWO) *MIRU HES Slickline w/.125 wire. *Cut 100'of.125"wire for PM to ensure all is in sufficient working order. *Ran a KJ and 3.5"GR(Steel pin),latch C sub at 8,487'slm,hit 12 OJ licks at 1750#.Shear tool and POOH to surface. *Ran a KJ and 3.5"GR(Steel pin),latch C sub at 8,487'slm,hit 4 OJ licks at 1750#.Shear tool and POOH to surface. *Ran a KJ and 3.5"GR(Steel pin),latch C sub at 8,487'slm, hit 29 OJ licks at 900#.Shear tool and POOH to surface. *Ran a KJ and 3.5"GR(Steel pin),latch C sub at 8,487'slm, hit 29 OJ licks at 1200#.Shear tool and POOH to surface. *Ran a KJ and 3.5"GR(Steel pin),latch C sub at 8,487'slm, hit 29 OJ licks at 1200#.Shear tool and POOH to surface. *Ran a KJ and 3.5"GR(Steel pin),latch C sub at 8,487'slm, pull and 1800#bind and set the brake,hold for 30 min.No movement.Hit 20 OJ licks at 1200#,shear tool POOH to surface. *Cut 250'of.125"wire,inspect all connections on tools string. *Ran a KJ and 3.5"GR(Steel pin),latch C sub at 8,487'slm,had to tag 5 times to latch up,hit 7 OJ licks at 1300#and hold tension for 5 min after each jar.Shear tool and POOH to surface. *Lay down HES S/L for the night. Page 6/7 Report Printed: 10/13/2017 GCAULOperations Summary Report- State Well Name: ODSN-29 Alaska Start Depth FoodMeters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 10/11/2017 10/12/2017 8,474.0 0.00 8.50 00:00 10/11/17-00:00 10/12/17 (Post RWO) *MIRU HES Slickline w/.125 wire. *RIH w/Keyless GS to ensure we can shear the release pin.Tag at 8,487'slm and jar down 10 times.POOH and inspect tools. *RIH w/3.5"GR,latch 3.5"bait sub at 8,487'slm.Hit 20 OJ licks at 14004.GR shears.POOH to surface. *RIH w/3.5"GR,latch 3.5"bait sub at 8,487'slm.Hit 20 OJ licks at 1400#.GR shears.POOH to surface. *RIH w/3.5"GR,latch 3.5"Bait sub at 8,487'slm.Hit 20 OJ licks at 1400#.GR shears.POOH to surface. *RIH w/KJ and keyless 3.5"GS.Verify we can shear the GS.Tag the 3.5"bait sub at 8,487'slm. Jar down 5 times.POOH to surface. *RIH w/KJ and GS.Tag and latch the 8,487'slm.Spang jar on the C-sub for 40 min.GS shears. POOH to surface. *Cut 250'of.125"wire,inspect all connections on tools string. *Lay down HES S/L for the night. 10/12/2017 10/13/2017 8,474.0 0.00 8.50 00:00 10/12/17-00:00 10/13/17 (Post RWO) *MIRU HES Slickline w/.125 wire. *RIH w/3.5"GS and spang on the 3.5"bait sub(C-Sub)for 10 min.Catcher pulls free.POOH. *3.5"Catcher sub on surface. *RDMO HES S/L and move to ODSN-02 and complete the Pre RWO Program. Page 7/7 Report Printed: 10/13/2017 • • 10-13-2017 ODSN-29 Nuiqsut Production Completion FINAL i..... I1 Land Upper Completion u peer Cn"'p4etipm E4u;pna en2 MDIft) TA:4ft; ith 40,000 lbs 31 9 2 51 )'i`• 1 Slack-Off 8 31/2`81_=-_. I D 3-1,71-51-241 RULLr 1/diCi!Eke.v.Fn i 3-h r TflM€1935EwJl 833 1T"pss,ExeVa 3-1/2,52- - max v5,-, -... _r.,...s,* E I , y 1© 16"Conductor R ELi 4 { I Packer Fluid mix: gam{,}1F :r 214a,er F.: I Inhibited Kill :--- i.... --_-. : - weight Brine "/33$rD L-a1'Crossover P Jte3 1 - 0,/31/2-9.2xEu£88DBoxxXvx h with 2000'TVD ELE-FQ.5 E_ 55 3.22TC-aFin L-EECrossover Pip J31, .10 diesel cao - - : _ -.--:- -�T I F 15 f1.:-12 529 TG-1 Bo..3-12 92*EUE 8 RD Pen L,10 Crasswcr Fur1-3 © Q 31/7 x l`GVM a 192.E11SRD6*P 7815 '-- � - I T 15 it >ld E" _nerFLA I 01,4 u 31 212=-- ..pin 7917 r...- V 15ft -:.= ELESF._ _-ti3- 5,,erFLL 'dr 3342 92x I X 15 ft.3-12 31€TL-9&-. 5 RD B +a F, 7 11/2 SU Presure/Te-: ..}lit _xP:m.,, E.12 5933 I 11-3/4"60 ppf L-80 BTC z 15ft.3-1219 2*FUE 7' :=fat P,L 5-..erFLA 3.3 312 1 Surface Casing CC BH 3112'. " . ,- -.ex31/2"921TC-48w[a PI, 8280 5033 I @ 4140'MD/3544'TVD 3LR'924Jft' -a .1 t . cemented to surface FF 15ft.3-1.Q-921TC-11 Box x112-92*RE8RDPPL-FSiCrossover Pup J 1 GG BH CMU IShift Up to()peal SSaTingSkreve X ProtdeIv/31/2'414 Vam Top Bax x P;n 8133 67E5 HH 15 ft.3-132 920 BE B RD Baa x 3-37'9.83 TC-1 Pin L-83 Crossover Pt J drrt ti 31,,2"921tft TC T k,rgg'.13j TOC Estimated I 1.1_15 it 1tQ"92$TC-1Box xlir7"9T*E]lEB RD Fa L-ffi Gasswvr FtnJdtY I @ 500 ft above 9-5/8" 2727 31/2'`X`Nipple 43(2.812 Xprofde) /31,/2'92,£UTa e....as 522 6174 LL 15ft 1/Q"925 BE SRD Bac x3VT 9 TC-1 Pin L-83 Crossover PuaJart Shoe 31/2 925/RTC-d Ttbom1111l WI BL35TlgNT45 }1f2`93P PS719 TC]91mxx 3-3J293tl£08 p'ua 3" niCPr 3.91S'a2925 ID MU 6131 I I 9-5/8"40 ppf L-80 Do MAST JOINTS O4,3,2-31/29.1,P1113£1.1EM BMA pin 212 Ion 001597x2.962' ET63 6142 1 Hydril 521 PP 81457 KN14T 41-3-1/2939 P110 EUE M box x3l/293PTC-8 PSa 2174mng oD3915'x.2.425"1D 3331 5175 12Q 30/2'9.2t/fTC-6Ttb36 II.11 1 Intermediate 1 RR 15 ft.31R"92*TC-e Bax x 112-920 Vam Toe Pis L-E Crossover Pup-Joint Casing SS BH CMU{Shift Up to Open Sred 3- Sveeve X Profdew/ lir 99 Yam Top Bax x Pin 823 33 0 61 @ 7238'MD/5506' TT 15ft.3-12"920 Vans Tan Box x 3-VT 922{1 TC-I Pin L-38 Crossover Pu.Joirt 1 II 31,,2592ift7C-C4b il4i TVD W 1511.3-1.2-920 TC-1 Bae z 31.25'920 BE S RD Pin 1.83 Crossover Pap Joint I WW 31/2'X`DT*,64{2E13-xprofaxi w/31/279.20EU£gsD8ox IP,* 8397 gI O XX 15 ft3-132'920 E11E S RD Bar x 3-U'2'9-Ai TC-1 Pin1-99Crossover PLpJcnt I 3-1/2"9.2 ppf rf 31/2 9.2,,ft-0'" rg I L-80 TC-II ZE 3.12'92*TC-9 Box x4-1i2126ft F1vdn1521 Pin Crossover 0 1 811&Met Seel Amend*xith Dashed Locator Sub 4-1/2'12.6,tfydr3 521 X Tubing 2 HID self ATIgnimil Mae End atAs sem'13 8�2 9245 1 OWaddleC piettion Equipment MDtfx) TVDItI _ SC ft 5.25'to Beck eater... 840 E.2 y_ 4 eager 5'X 72XP Liner Te.=: Ftx tod Hanger 8476 42:5 0 7"TOC Estimated 5 4,10 1254 Ey MI 5715, Orr-ii Pic Crossover Sliding ` 6 4ft3-1/z'TC-tIBoxxPsnp -_-. C i i' @ 500 ft above / 15 ft 31a2-474Tr-1Hat x2-=.-- - -- ="into- = Sleeves 5 2/2'59 S.eeve,23124 X Pr-r 117E-: 5215 5267 Closed GG 111Kuparuk 9 1 12 11 , '97 Ei�3R ea r (Up to Open) 'x2 Kuparuk C Planned 10 312"92,,,f 'dim ® Perforations: 11 15ft 111"9122Tall Box x11%2 5 12 31/Z""Xf£-C4 rpe 17=-Go, =-sf/ce, 808ox*Pin 8395 6292 IV 8,263'-8,332'MD 13 151133-2'9aaREaRDBoxx1U2 - ,-FpI-BCa P a 00 14 31„2"920/ft E.7,6r6 1,139'-6,177'TVD 15 1/2 Mute Shoe bucked up to Lia:nt of Il/2"921/6 TE-111 Tuh:ry 9536 8414 ® Q"i,O End d Assembler 9535 6414 © ��© PXN Plug ©. 0 nstalled in XN r� -4. ;%-. With 1.745" + using neck Sliding Slee. s . . \,..., Ojhosed * (Down to open) ® �� 2s 32 Fault @ 13,470' MD 7"26 ppf L 80 BTC 412) \ ��®' \ - as - sa ss ss �a so eo ,1 Mod Hydril521 ® so + 'CD, !® _iii: _ -i =ii- _, _ _ _i= : _ _ii_i�_ = i= _i Intermediate 2 Casing --- - -- @ 9759' MD/6430' (11) 6-1/8" TVD Fault @ ' 6-1/8" Hole TD at 11 Fault ft MD 4-1/3" Hydril 521 Liner with Baker Hughes at 15716' MD/ 980 FAILED ECP Multi-Point Frac Sleeves(3 per stage) isolated 6430'TVD with ECP's + Resman Carriers ♦. ' ! • 10-13-2017 ODSN-29 Nuiqsut Production Completion FINAL Land Upper i I Completion Lower Completion �Q IyQ i I 20)Baker 5-'/z'X 7"ZXP Liner Top Packer with 15ft Tie Back 9524' 6413' iii with 40,000 lbs 1 extension and Flex Lock Hanger i Slack-Off 21)4-'/z"13.5#/ft Hydril 521 Liner 22)Baker ECP Packer(4-14"Hydril 521) 9949' 6436' i 23)4-'/:"13.5#/ft Hydril 521 Liner i , 24)Baker Multi-Point Frac Sleeve with segmented ball seat(3.000 ball/2.948 Seat) 10179' 6445' 16"Conductor 25)4'/4"13.5#/ft Hydril 521 Liner ' __,2%.491 g1 26)4-1z'Resman Tracer Carrier w/15 ft pups on each side 1 , 1 1 Al ,Packer Fluid mix. 27)4-%"13.5#/ft Hydril 521 Liner I Inhibited Kill 28)Baker Multi-Point Frac Sleeve with segmented ball seat(3.000 ball/2.948 Seat) 10336' 6444' weight Brine 29)4-%"13.5#/ft Hydril 521 Liner I 30)Baker Multi-Point Frac Sleeve with solid ball seat(3.000 ball/2.948 Seat) 10411' 6442' with 2000'TVD GLM#2 I 31)4-1/2"13.5#/ft Hydril 521 Liner ;,CL, a ] diesel cap 32)Baker ECP Packer(4-'s Hydnl 521) 10647' 6434. M 33)4'/y'13.5#/ft Hydril 521 Liner 34)Baker Multi-Point Frac Sleeve with segmented ball seat(2.938 ball/2.885 Seat) 10750' 6433' I 35)4-'/z'13.5#/ft Hydril 521 Liner 1 36)4-'/"Resman Tracer Carrier w/15 ft pups on each side 10826' 6431' 37)4-1A"13.5#/ft Hydril 521 Liner 38)Baker Multi-Point Frac Sleeve with segmented ball seat(2.938 ball/2.885 Seat) 10909' 6430' I 39)4-'/z"13.5#/ft Hydril 521 Liner 11 3/4"60 ppf L 80 BTC 40)4-�/"Resman Tracer Carrier w/15 ft pups on each side 10985' 6429' I41)4-%z'13.5#/ft Hydril 521 Liner I Surface Casing 42)Baker Multi-Point Frac Sleeve with solid ball seat(2.938 ball/2.885 Seat) 11067' 6427' I @ 4140'MD/3544'TVD 43)4-'/z"13.5#/ft Hydril 521 Liner I cemented to surface 44)Baker ECP Packer(4-'/z"Hydril 521) 11178' 6423' 45)4-/:"13.5#/ft Hydril 521 Liner 1 46)Baker Multi-Point Frac Sleeve with segmented ball seat(2.875 ball/2.823 Seat) 11379' 6415' 1 TOC Estimated 47)4'/z'13.5#/ft Hydril 521 Liner @ 500 ft above 9-5/8" 48)4-'14"Resman Tracer Carrier w/15 ft pups on each side 11454' 6413' l Shoe 49)4-'/z'13.5#/ft Hydril 521 Liner 1 50)Baker Multi-Point Frac Sleeve with segmented ball seat(2.875 ball/2.823 Seat) 11537' 6410' I 9-5/8"40 ppf L-80 51)4-'/z'13.5#/ft Hydril 521 Liner Hydril 521 52)Baker Multi-Point Frac Sleeve with solid ball seat(2.875 ball/2.823 Seat) 11612' 6408' 53)4'/z"13.5#/ft Hydril 521 Liner 1 Intermediate 1 54)4'/z"13.5#/ft Hydril 521 Liner with 2 HLB slide on centralizers 11756' 6407' Casing 55)4'/z'13.5#/ft Hydril 521 Liner I @ 7238'MD/5506' 56)Baker ECP Packer(4-'/z'Hydril 521) 12017' 6407' I TVD 57)4'/z'13.5#/ft Hydril 521 Liner 1 58)Baker Multi-Point Frac Sleeve with segmented ball seat(2.813 ball/2.760 Seat) 12231' 6407' O I 3-1/2"9.2 ppf 59)4-'/z'13.5#/ft Hydril 521 Liner GLM#1 a60)4-'/z'Resman Tracer Carrierw/15 ft pups on each side 12306' 6408' '/d'OV I L-80 TC-Il 61)4-14"13.5#/ft Hydril 521 Liner © 10 Tubing 62)Baker Multi-Point Frac Sleeve with segmented ball seat(2.813 ball/2.760 Seat) 12389' 6409' �J 63)4-'/z'13.5#/ft Hydril 521 Liner 1 64)Baker Multi-Point Frac Sleeve with solid ball seat(2.813 ball/2.760 Seat) 12506' 6409' 0 ` 65)4-'/z"13.5#/ft Hydril 521 Liner 66)Baker ECP Packer(4-14'Hydril 521) 12701' 6416' Sliding 0 7"TOC Estimated 67)4-'/z'13.5#/ft Hydril 521 Liner @ 500 ft above 68)Baker Multi-Point Frac Sleeve with segmented ball seat(2.750 ball/2.698 Seat) 12903' 6415' Sleeves Closed GG 111 ® Kuparuk '/ 69)4-'/z'13.5#/ft Hydril 521 Liner 70)4- "Resman Tracer Carrier w/15 ft pups on each side 12977' 6412' (Up to Open) X Kuparuk C Planned 71)4-14"13.5#/ft Hydril 521 Liner 0 Perforations: 72)Baker Multi-Point Frac Sleeve with segmented ball seat(2.750 ball/2.698 Seat) 13059' 6409' 8,263'-8,332'MD 73)4-'/2"13.5#/ft Hydril 521 Liner 00 6,139'-6,177'TVD 74)4-1z'Resman Tracer Carrier w/15 ft pups on each side 13134' 6405' A � 75)4-14 13.5#/ft Hydril 521 Liner 0 ;0 © . PXN Plug © '`r �nW With 1.745"N 04 J fising neck Sliding Sleeve O.l.,. Closed ® zs Fault @ 13,470' MD (Down to Open) 32 __ _C>44 54 ss ss is s so ,00 7"26 ppf L-80 BTC- '® - nt + Hydra 521 I ® -11 - - - -� - - - 7-1 :1E -I -II-�-I -II- - -� - -I � zantermediate 2 Casing ; @ 9759' MD/6430' 6-1/8" Hole TD at TVD Fault @ ft MD 4-'/2" Hydril 521 Liner with Baker Hughes at 15716' MD/ 1198 FAILED ECP Multi-Point Frac Sleeves(3 per stage)isolated 6430'TVD with ECP's + Resman Carriers t • • 10-13-2017 ODSN-29 Nuiqsut Production Completion FINAL 1 i Land Upper I pp Lower Completion MO ID 1 Completion with 40,000 lbs 76)Baker Multi-Point Frac Sleeve with solid ball seat(2.750 ball/2.698 Seat) 13217' 6402' 1 77)4-'/2'13.5#/ft Hydril 521 Liner i Slack-Off y i I 78)Baker ECP Packer(4-'/z"Hydril 521) 13370' 6402' 79)4-'/z'13.5#/ft Hydril 521 Liner I 80)Baker ECP Packer(4-'/z'Hydril 521) 13508' 6408' I 81)4-W 13.5#/ft Hydril 521 Liner i +w+ I© 16"Conductor 82)Baker Multi-Point Frac Sleeve with segmented ball seat(2.688 ball/2.635 Seat) 13726' 6417' Packer Fluid mix' 83)4-1/2"13.5#/ft Hydril 521 Liner 84)4-'W Resman Tracer Carrier w/15 ft pups on each side 13801' 6420' I Inhibited Kill 85)4-'/2'13.5#/ft Hydril 521 Liner 1 weight Brine 86)Baker Multi-Point Frac Sleeve with segmented ball seat(2.688 ball/2.635 Seat) 13883' 6423' GLM#2 with 2000'TVD 87)4-'/?13.5#/ft Hydril 521 Liner D GL's a ,1 i diesel cap 88)Baker Multi-Point Frac Sleeve with solid ball seat(2.688 ball/2.635 Seat) 13957' 6423' 89)4-'/z'13.5#/ft Hydril 521 Liner X 90)Baker ECP Packer(4-'/ Hydril 521) 14110' 6424' 91)4-'/2"13.5#/ft Hydril 521 Liner I I I I 11-3/4"60 ppf L-80 BTC I Surface Casing I @ 4140'MD/3544'TVD I 92)Baker Multi-Point Frac Sleeve with segmented ball seat(2.625 ball/2.573 Seat) 14263' 6425' 93)4-W"13.5#/ft Hydril 521 Liner 94)4-'/i'Resman Tracer Carrier w/15 ft pups on each side 14339' 6426' 95)4-W 13.5#/ft Hydril 521 Liner 96)Baker Multi-Point Frac Sleeve with segmented ball seat(2.625 ball/2.573 Seat) 14421' 6428' 97)4-%"13.5#/ft Hydril 521 Liner 98)Baker Multi-Point Frac Sleeve with solid ball seat(2.625 ball/2.573 Seat) 14495' 6428' 99)4-'/"13.5#/ft Hydril 521 Liner 100)Baker ECP Packer(4--'/i'Hydril 521) 14648' 6427' cemented to surface 101)4-%" 13.5#/ft Hydril 521 Liner 1 102)Baker Multi-Point Frac Sleeve with segmented ball seat(2.563 ball/2.510 Seat) 14786' 6429' TOC Estimated 1 @ 500 ft above 9-5/8" 103)4'%" 13.5#/ft Hydril 521 Liner 104)4-1/2"Resman Tracer Carrier w/15 ft pups on each side 14862' 6430' 105)4-1/2"13.5#/ft Hydril 521 Liner Shoe 106)Baker Multi-Point Frac Sleeve with segmented ball seat(2.563 ball/2.510 Seat) 14944' 6431' 107)4-'/2'13.5#/ft Hydril 521 Liner 9 5/8"40 ppf L 80 108)4-'/"Resman Tracer Carrier w/15 ft pups on each side 15020' 6431' 1 Hydril 521 109)4'/3'13.5#/ft Hydril 521 Liner Intermediate 1 110)Baker Multi-Point Frac Sleeve with solid ball seat(2.563 ball/2.510 Seat) 15102' 6432' 111)4-%" 13.5#/ft Hydril 521 Liner 7238'MCasing 112)Baker ECP Packer(4'/i'Hydril 521) 15249' 6432' 1 @ /5506' 113)4'%"13.5#/ft Hydril 521 Liner TVD 114)4-'W 13.5#/ft Hydril 521—10 ft Pup I 115)4-'W Resman Tracer Carrier w/15 ft pups on each side 15469' 6431' GLM#1 O a I 3-1/2"9.2 ppf 116)Pressure Activated Sleeve"B"5,800 psi 15644' 6430' ''/4"OV 1 L-80 TC-II 117)Pressure Activated Sleeve"A"5,600 psi 15698' 6430' Tubing 118)Wellbore Isdation Valve"WIV' 15700' 6430' © 119)Eccentric Shoe 15705' 6430' 1 Bottom of Shoe 15706' 6430' Sliding 0 7"TOC Estimated Sleeves @ 500 ft above Closed GG ® ® Kuparuk (up to Open) U Kuparuk C Planned OF 0 Perforations: 8,263'—8,332'MD _a � ...C/A 6,139'—6,177'TVD 43101114111 a `�, PXN Plug '`{ ®nstalled in XN With 1.745" CO �Q �' fising neck Sliding Sleeve O I,. r Closed 411) (Down to Open) 2e Fault @ 13,470'MD �` 32 O 7"26 ppf L-80 BTC-�� as so sa ss ss 7a eo so Mod + Hydril 521 ®'®,4 - —n— — — — — — — — - — - — - — - - Intermediate 2 \ za =III— - - -� -I - — -I — — —I-II- —1 =II-I -I - I- -I , Casing @ 9759' MD/6430' 6-1/8" Hole TD at TVD 11,980 Fault @ ft MD 4-Y2" Hydril 521 Liner with Baker Hughes at 15716'MD/ FAILED ECPMulti-Point Frac Sleeves(3 per stage)isolated 6430'TVD with ECP's + Resman Carders • roc .. CAE Lii LETTER OF TRANSMITTAL Energy Alaska RECEIVED E DATLOGGED LoG D w1.K.BENDER OCT 13 2017 AOGCC DATE: October 12, 2017 FROM: TO: Shannon Koh AOGCC Caelus Energy Alaska Attn: Makana Bender 3700 Centerpoint Dr., Suite 500 333 W. 7th Avenue, Suite 100 Anchorage, AK 99503 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps ▪ CD-R • Other - Logs ❑ Agreement DETAIL QTY DESCRIPTION ODSN-29 (AP1:50-703-20661-0000) 1 CD Radial Cement Bond Log—LAS data, digital logs (Run date: September 1, 2017) 1 Log Radial Cement Bond Log sage \, 1 Received byfM,,Q(-,e�, Date: Plea e sign and return one copy to: Caelus Energy Alaska ATTN: Shannon Koh 3700 Centerpoint Dr., Suite 500, Anchorage, AK 99503 907-343-2193 fax 907-343-2128 phone shannon.koh(a�caelusenergy.com y OF Tit, • S 0+P*I I/j,..• THE STATE Alaska Oil and Gas �� �-s=dam=-'� of e T ASK e Conservation Commission .���, ALAS OM 333 West Seventh Avenue N C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 of ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Rami Jasser Senior Staff Completion Engineer Caelus Natural Resources Alaska, LLC ); 0 Q�,�� 3700 Centerpoint Drive, Suite 500 SCO"‘ Anchorage, AK 99503 Re: Oooguruk Field,Nuiqsut Oil Pool, ODSN-29 Permit to Drill Number: 212-106 Sundry Number: 317-248 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 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, /3444.4, Cathy . Foerster ,,, -� Chair DATED this Gv� day of June, 2017. RBDMS JuoJ L 6 2017 III • RECEIVED STATE OF ALASKA JUN 1 3 201 ALASKA OIL AND GAS CONSERVATION COMMISSION 137.5) 6/ZQ(/7 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool.0 Re-enter Susp Well ❑ Alter Casing ❑ Other:Perf Kup C/Run Gas Lift 0 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Caelus Natural Resources Alaska,LLC Exploratory ❑ Development ❑ , 212-106 - 3.Address: i 6.API Number: Stratigraphic ❑ Service 3700 Centerpoint Drive,Suite 500,Anchorage,AK 99503 50-703-20661-00-00 . 7.If perforating: la it 6 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? ,...41.4.7*----S5 ODSN-29 Will planned perforations require a spacing exception? Yes ❑ No 0 I 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036/ADL 389958 . Oooguruk-Nuiqsut Oil Pool/Kuparuk Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi):719 psi prior to Plugs(MD): Junk(MD): 15,716' ‘ 6,430' 15,705' • 6,430' . perf/2,460 with Kuparuk open N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 4,101' 11-3/4" 4,140' 3,544' 5,830 psi 3,180 psi Intermediate 1 3,314' 9-5/8" 3,924'-7,238' 3,413'-5,506' 5,750 psi 3,090 psi Intermediate 2 9,721' 7" 9,759' 6,430' 7,240 psi 5,410 psi Liner 6,182' 4-1/2" 9,524'-15,706' 6,413'-6'430' 8,430 psi 7,500 psi 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" 13.5#,P-110,Hyd 521 9,540' Packers and SSSV Type: See attachment pg.3 Packers and SSSV MD(ft)and TVD(ft): See attachment pg.3 , 12.Attachments: Proposal Summary 0 Wellbore schematic 0 '13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0. Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 8/25/2017 OIL 0 • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Rami Jasser Contact Name: Rami Jasser Authorized Title: Senior Staff C. eletion EngineerContact Email: rami.iasser( caeluserteray.com /�—/� Contact Phone: 907-343-2182 Authorized Signature: /- 4 Date: L COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 _2LI- Plug Integrity ❑ BOP Test 1/1 Mechanical Integrity Test ❑ Location Clearance ❑ t (c•I \ Other:COfl ,y/ ?rodrov., fr•Ad tJ4#( u/dr✓ 6w. 4i61:4 d„der 2o44G 2f2y ,t- 3500 pc Qt”) `7. fi Post Initial Injection MIT Req'd? Yes ❑ No ❑ L.� Spacing Exception Requir^O Yes /<o t Subsequent Form Required: /(� [ Ct`I RBDMS JUN 2 6 2017 co SCJu r O c � hoc ,/ 6.)X11, APPROVED BY Approved by: 4--^. COMMISSIONER THE COMMISSION Dater — �_,iK/�$'' cm - �, C� - j 1-i - Vis"! f...{'/ � °AfilaliNAL Submit and 1=0 10-ao3 Revise � n for 12 months from the date of approval. Attachments in Duplicate • • i ' ' CAE1JJS RECEIVED June 8, 2017 JUN 1 3 [017 State of Alaska AOGCC Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue, Suite #100 Anchorage, AK 99501 RE: ODSN-29 Sundry Application to pull out Frac String, perforate the Kuparuk C formation and install a Selective Single Completion REF: Approved Permit to Drill #212-106 Caelus Natural Resources Alaska, LLC. (CNRA) hereby submits an Application for Sundry to pull the existing 4-1/2" frac upper completion string out on ODSN-29, perforate the Kuparuk C formation, and install a 3-1/2" selective single upper completion string to straddle the Kuparuk C perforated zone in preparation for a future fracture stimulation. / Please see the proposed plan attachments and supporting documentation. liy Sincere' //,.. Rami Jasser Senior Staff Completion Engineer Attachments: Form 10-403 Supporting Information cc: ODSN-29 Well File • • 2 ODSN-29 Procedure Summary: Pre-Rig: 1. Set EVO-trieve above deep XN nipple or set PXN plug in XN nipple 2. Pull GLV from GLM#4, Install DV in GLM#4 3. Pull GLV from GLM#3, Install DV in GLM#3 4. Pull GLV from GLM#2, Install DV in GLM#2 5. Pull OV from GLM#1 6. Fluid pack tubing and IA with treated/filtered seawater 7. Freeze protect tubing and IA to 2,500' TVD with diesel 8. Combo Test Tubing x IA to 3500psi c; 9. Set BPV 10. Test Pack-offs to 5000psi 11. Lube and bleed Tubing and IA to ensure fluid packed Rig Work: 1. MIRU N19AC 2. Install test dart 3. ND Tree/ NU BOPE 6yg 4. Test BOPE 250psi low/3500psi high, Annular to 2500psi 5. Circulate out diesel freeze protect with treated/filtered seawater 6. Circulate IA to tubing at high rate with surfactants to clean IA 7. SL - Install DV in GLM#1 8, SL - Pull EVO-trieve or PXN plug • 9. Monitor fluid level in tubing, establish loss rate 10. Follow Caelus Well Control SOP with no fluid level at surface - minimizing losses to formation 11. BOLDS 12, Pull seals from SBR 13. Monitor fluid level in tubing and IA, establish loss rate 14. Follow Caelus Well Control SOP with no fluid level at surface - minimizing losses to formation 15. POOH with 4-1/2" Frac/ GL string and LD 16. RIH with bit, scraper and magnets to 9,524' MD, top of SBR ,1e17. POOH Cleanout BHA 1�. � 18. PU and RIH with middle completion: 7"x5" ZXP liner hanger/ packer with SBR, (r Sliding Sleeve (open), XN nipple (PXN plug installed) and tubing tail without seals 19. Land ZXP liner hanger assembly at -8,460' MD with tubing tail inserted into existing 4-1/2" lower completion 20. Drop setting ball to set ZXP liner hanger assembly utilizing pusher tool for Liner Top Packer 21. Pull setting tool out of ZXP liner hanger assembly, lower stinger will close sliding sleeve 22. Fill hole with treated/filtered seawater 23. Pressure test 7"casing and ZXP liner hanger assembly to 3500psi 24. Circulate hole from treated/filtered seawater to 10.0ppg brine 25. POOH with liner hanger setting tool and LD 26. EL - Log Kuparuk - CCL, GR, CBL; tag lower Liner Hanger packer (middle completion), pull to 750' MD above top of Kuparuk 27. PU and RIH with TCP guns with no-go 28. Tag middle completion for depth control, space out 29. Perforate - 69' of Kuparuk If 3 3 30. POOH and LD TCP guns C 544 / 31. RIH with bit, scraper and magnets to 8,460' MD • . 3 32. Circulate clean, POOH with clean out BHA 33. PU and RIH with 3-1/2" selective single gas lift upper completion string as per attached schematic 34. Place inhibited packer fluid in IA from packer to GLM#2 35. Land 7x3-1/2" retrievable packer at -8,100' MD, sting into lower 5-1/4" SBR with seals 36. Pressure up against lower PXN plug to set packer / 37. Pressure test tubing to 3500psi, Pressure IA to 3500psi 38. Shear SOV in GLM#2 39. Place inhibited packer fluid in tubing and IA with diesel freeze protect to 2,500' TVD 40. Close ScSSSV 41. Set BPV 42. ND BOPE / NU Tree 43. RDMO Naborsl9AC Post Rig (Slick-line): 1. Set catcher below GLM#1 2. Pull SOV from GLM#2 3, Set DV in GLM#2 4. Pull DV from GLM#1 5. Set OV in GLM#1 6. Pull catcher 7. Open lower Kuparuk sliding sleeve 'A-A ,�-- • • 4 Reservoir Pressures: Nuiqsut Pressure: estimated BHP after 30 days of shut-in is —1,350 psi (4.1 ppge) at 6,306' TVD (current ROC gauge depth) Kuparuk Pressure: estimated BHP is 3,066 psi (9.7.e) at 6,100' TVD (from N06 closest offset GeoTap in 2015) Maximum Anticipated Surface Pressure (prior to perforating the Kuparuk), assuming gas from surface to 7" shoe (ROC gauge, 6,306' TVD), is 719 psi. Gas gradient 0.1 psi/ft. Maximum Anticipated Surface Pressure (after perforating the Kuparuk), assuming gas from surface to 6100' TVD, is 2,460 psi. ODSN-29 Nuiqsut Bottomhole Pressure Build Ups 3,500 —2013 Initial Pressure 3,000 ----Seawater(8.55 ppge) LVT/Diesel(6.8 ppge) (73 2,500 • June 2014 io Sept.2014 to 2,000 April 2015 a y May 2015 3 _ _ _ _ - _ ••• Estimated Pressure Build Up P_) 1,500 _ _ _ _ __ -_ - o = = O - ' - - - L 2016 Reported PBUs 3 2016 PBU m W 1,000 o u O t 500 0 0 20 40 60 80 100 Shut-in Time,Days • III 5 Original Well Schematic: ODSN-29 Nuiqsut Production Well Completion Final 8/5/2014 I No. upper Completion Equipment MOM WO(ft) 'ret.3*ay'Tuning Haver 34 34 I , 4',"'3 ft Hydra 52'Tutg 16"Conductor 4 -albbtrbn'XXO"SVLNwt 3813-"X'"profile RTS to 3 sfnybel'4-x0049-srscantrolline.Cannon clamps on 2,082 2.02) 1 Packer Fluid mix; every girt Inhibited Kill weight 4 4',13.5*itHydd 521 Tubing IBrine 5 i';x 1"GLM#4,K9IG Hyd it 521 2231 2,155 1 s4-!,;-13 8 .5att Hydra 521 Tubing With 2000'DLI-1 7 HES X 3.813- 2299 2.208 Seri 1 diesel cap S 4-" 13.5=h Hydra 521 Tubing 1'."x 1"GLM e3.KBAG Hydril 521 4277 9635 4'.13 91.9Hydra 521 Tubng 'x 1-GLM 9 t2,K .G Hydril 521 4,957 12 4;;'13.*it Hydra 521 Tubing 11 3/4"60 f L 80 BTC 13 i'.-x 1-GLM*1.KE3MG Hydril 521 - , 5,9,60 I pp 14 4!;*13*ft Hydra 521 Tubing I Surface Casing 15 HES XN 3813-(3.725-NoGot 8,512 6.255 GL @ 4140'MD/3544'TVD 18 4 -13.5`�tHy°rr 521 Tubing ® 17 1.117 HaIiburton'ROC'Gauge Carrie rnit V4'x 0.0(9-srscontrol line 8,617 6,306 I -I cemented to surface 18 4..''3 x=tI dri521Tubeng 019 1 19 3.ec S m Fssembye+lr Rat etrig M ue Shoe 9,538 8.413 1 F' End of Assembly 9.`_43 8,414 I si' ® ill t GL j —1 9-5/8"40 ppf L-80 Hydril 521 Intermediate 1 Casing @ 7238' MD/5506'TVD 1 • GL J 4-1/2" 13.5 ppf —1 P-110 Hydril I 521 I Tubing ® GL 1 4111 -pH 1 0R«� TOC Estimated ''` Si'above top of k“V e`` . Kuparuk(C ) 0 \ 0 ® Fault @ 13,470' MD sz 0 \� �� ,.,0 /0 66 78 J 80 CD0 410 7"26 ppf L-80 BTC .41 — -0—n- At I Mod + Hydril 521 \ za 4;4 -I } 1-II II 1 IIr-ll ---: 1--- 1 :11::1211=1::I I t ) 1 Intermediate 2 1 Casing -® @ 9759' MD/6430' TVD / Fault @ FAILED ECP 11,980 ft MD 6-1/8"Hole TD at at 15716' MD/ 4-'h"Hydril 521 Liner with Baker Hughes Multi- 6430'TVD Point Frac Sleeves(3 per stage)isolated with ECP's + Resman Carriers II III 6 Proposed Well Schematic: 6-8-2017 ODSN-29 Proposed Nuiqsut Production Completion DRAFT t 1 Na. UpperCompleton Equipment MD(ft) TVD(ft) Ilililil Land Upper 1 GE Tubing Hanger 34 34 I I Completion 2 3-1/29.2+1/ftTC-IITubing(2jts) I jlllllll with 40,000 lbs 3 31/2 9.20 ft TC-II Tubing Slack-Off SV 3 St B 3-1/2"NE TRw/1813""R'profile with single 1/4"x 0.049"S5 Control 2 2 2C20 I j l'-e tc surface.Cannon Cross-coupling damps on every joint II 5 3-1/2'9.2#/ftTC-11Tubing 1..I " I 16°Conductor 8 SLB 3-1/2' x 1 G 1121#2 92e TC-II BaP w/DCK2 3725 32.90 a 7 3-1/2-9.2e/ftTC-11Tubing(2its/ I ,Packer Fluid mix' 8 SIB 2.813' "X"Nipple 9 Cr w/3-12"9.2#/ftTC•II 8&P t 3225 3353 Inhibited Kill 9 3-1/2'9.20/ft TC-Il Tubing I weight RrinP __ SIB 3-1/7 x1 GINtel9.2eTCIIBit Pw/DV 7300 58x2 GLM#2 with 200(LL(f� 11 3-1/2-9.2#/ft TC-11 Tubing(Zits) SOV 6 12 5182.813' "X"Nipple 9 Cr w/3-1/2'9.2#/ftIC-11 IC-115(P 7900 5524 X j a 13 3-1/2'9.2#/ft TC-II Tubing j 14 3-1/2 51B Pressure/Temperature Gauge Carrier with single I-Wire to �k'K SKS surface 'ill 15 3-1/2-9.20/ft TC-ii Tubing 16 17 lg 19 x1 21 433-H1 3-1/2"x T'Premier r�trievabie Packer#2(10,000 psi rated] 8100 6046 I 3-k7'9.2#/ftTC-IlTuhing(2jt} 11-3/4"60 ppf L-80 BTC 8HI CMU Sliding Sieve w/3-1/2"928/ft TC-II SeP 8150 6075 Surface Casing 3-112"9.2#lftTC•IlTubing(Ijt) @ 4140'MD/3544'TVD 518 2.813""X"Nipple 9 Cr w/3-1/2'9.2#/ft TC-II 111#PxP 8200 6104 cemented to surface TOC Estimated 3112"9.2#/ftTC-11Tubng(ijt} BLAST JOINT#5-3-1/2"9.3#P110 TC-ti Box z 3-1/2 938 EIDE Pin 20°long OD 3.915"x1925"ID 8250 6132 22 ©500ftabove9-5/8" 23 BLAST JOINTS#4,3,2-3-1/29.34P110DIEM Box xpin 20'long 004.50"x Shoe 2,g ° I 24 BLAST301M#1-31/29.20PiioEt�7Abox x3l/29. 0TCIIPin20longOD 83517 6186 9-5/8"40 ppf L-80 Hydril 521 3515"x1925 ID 25 3-1/2-9.2#/ftTC-IITubing(ijt) Intermediate 1 Casing 26 BHI CMU Sliding Sleeve w/3-1/2"92#/ft TC-II PAP 8350 6186 @ 7238'MD/5506'TVD 27 3-1/2'9.20/ftTC-II Tubing(ljt) I'28 5182.813""X"Nipple 9 Cr w/3-1/2"9.2#/ftTC-ii PO moo 6212 0 29 3-yr 9.20/ft TC-II Tubing GLM#1 3 1/2"9.2 ppf • 30 BHl Bullet Seal Assembly with No Go Sub 8450 • 6235.9 DGLV I L-80 TC-II # 31 HLB Auto Entry Mule Shoe 8460 1 6240.6 © ATA Tubing End o&Assemby 846.5 6243 0 No• Paddle Completion Equipment WIDOIZ Tit(ft) . 32 10 ft 5.25"Tie Bade extension 8460 6241 Sliding 0 @ 7"TOC Estimated F. 33 Baker 5"X7"DCPliner Top Packer with Flex lock Hanger Sleeves Closed _-` r 500 ft above 34 3-1/2"9.2#/ft TC-11 Tubing (UptoOpen) 18 101 Kuparuk / • 35 BHI CMD Sliding Sleeve w/3-1/2"9.2#/ftTC-IiBUP 8550 6280 X 4 Kuparuk C Planned -1 • 36 31n-9.2e/ft TC-II Tubing Perforations: 37 5L8175""XN"Nipple 9C w/3-1/2"9.20/ftTC-ii BO8600 6299 2314.- c 22 8,263'-8,332'MDl 38 31/2"92#/ft TC-II Tubing ' e 0 6,139'-6,177'TVD 39 1/2 Mule Shoe 9538 6414 End ofAssemby 9540 6414 3 ( .4 ,`(.t/ Al�� 0*4. c) i -.N PI •• Installed in XN ✓p , - /_ t V Sliding osed es d ` L�j 1 l �t S Nt.t °a.� C r.� (Down to Open) s7 4, 70 Fault @,13,470'MD 7"26ppf L806TC\\ • / \ ': ____ ____ ____ J Mod+Hydril 521 ® _ __ _ -i_ _ _ _ _ _ _ _ _ _ _ _ _� _ 1 Intermediate2 \.'®; :11 -I:I - III :I -II > 1 Casing @ 9759'MD/6430' 6-1/8"Hole TD at TVD Fault @ 4-W Hydril 521 Liner with Baker Hughes Multi- at 15716'MD/ FAILED ECP 11,980 ft MD Point Frac Sleeves(3 per stage)isolated with 6430'TVD ECP's+Resman Carriers • • Attachment 2 AOGCC Form 10-403 Sundry Application Box 11 - Perforation Locations Well: ODSN-29 Top (MD) Top (TVD) Baker Multi-Point Frac Sleeve w/segmented ball seat 10,179 6,445 Baker Multi-Point Frac Sleeve w/segmented ball seat 10,336 6,444 Baker Multi-Point Frac Sleeve w/segmented ball seat 10,750 6,433 Baker Multi-Point Frac Sleeve w/segmented ball seat 10,909 6,430 Baker Multi-Point Frac Sleeve w/segmented ball seat 11,379 6,415 Baker Multi-Point Frac Sleeve w/segmented ball seat 11,537 6,410 Baker Multi-Point Frac Sleeve w/segmented ball seat 12,231 6,407 Baker Multi-Point Frac Sleeve w/segmented ball seat 12,389 6,409 Baker Multi-Point Frac Sleeve w/segmented ball seat 12,903 6,415 Baker Multi-Point Frac Sleeve w/segmented ball seat 13,059 6,409 Baker Multi-Point Frac Sleeve w/segmented ball seat 13,726 6,417 Baker Multi-Point Frac Sleeve w/segmented ball seat 13,883 6,423 Baker Multi-Point Frac Sleeve w/segmented ball seat 14,263 6,425 Baker Multi-Point Frac Sleeve w/segmented ball seat 14,421 6,428 Baker Multi-Point Frac Sleeve w/segmented ball seat 14,786 6,429 Baker Multi-Point Frac Sleeve w/segmented ball seat 14,944 6,431 Baker Multi-Point Frac Sleeve w/solid ball seat 10,410 6,442 Baker Multi-Point Frac Sleeve w/solid ball seat 11,067 6,427 Baker Multi-Point Frac Sleeve w/solid ball seat 11,612 6,408 Baker Multi-Point Frac Sleeve w/solid ball seat 12,506 6,409 Baker Multi-Point Frac Sleeve w/solid ball seat 13,217 6,402 Baker Multi-Point Frac Sleeve w/solid ball seat 13,957 6,423 Baker Multi-Point Frac Sleeve w/solid ball seat 14,495 6,428 Baker Multi-Point Frac Sleeve w/solid ball seat 15,102 6,432 Pressure Activated Sleeve B 15,644 6,429 Pressure Activated Sleeve A 15,698 6,430 • • Attachment 3 AOGCC Form 10-403 Application for Sundry Box 11 - Packers & SSSV Well: ODSN-29 SSSV MD TVD 4-1/2" Halliburton 'XXO' SVLN 2,082 2,020 PACKERS 5" x 7" Baker ZXP Liner Top Packer 9,524 6,413 Baker ECP Packer 9,949 6,364 Baker ECP Packer 10,647 6,365 Baker ECP Packer 11,178 6,367 Baker ECP Packer 12,017 6,366 Baker ECP Packer 12,701 6,355 Baker ECP Packer 13,370 6,355 Baker ECP Packer 13,508 6,354 Baker ECP Packer 14,110 6,343 Baker ECP Packer 14,648 6,344 Baker ECP Packer 15,249 6,345 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-29 PN5 50-703-20661-00-00 Sperry Drilling Services Definitive Survey Report 14 December, 2012 vommisiit HALL BURTON )'t �`' Sperry Drilling Services • 0 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 Database: EDM Alaska Project Oooguruk Development Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well ODSN-29 Well Position +N/-S 0.00 ft Northing: 6,031,108.44 ft Latitude: 70°29'45.820 N +E/-W 0.00 ft Easting: 469,923.95 ft Longitude: 150° 14'45.357 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSN-29 PN5 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF2010 10/10/2012 20.57 80.97 57,668 Design ODSN-29 PN5 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 13,041.26 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (bearing) 42.70 0.00 0.00 350.27 Survey Program Date 12/14/2012 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 100.00 729.00 ODSN-29 GYRO(ODSN-29 PN5 PB1) SRG-SS Surface readout gyro single shot 11/07/2012 775.48 4,138.70 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 4,139.70 7,238.00 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 7,238.00 9,697.60 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 9,776.70 11,885.85 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 11,930.00 13,041.26 ODSN-29 PN5 MWD(ODSN-29 PN5 PB MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/20/2012 13,138.40 15,641.71 ODSN-29 MWD(ODSN-29 PN5) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/26/2012 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°11001 (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,108.44 469,923.95 0.00 0.00 UNDEFINED 100.00 0.12 142.74 100.00 43.80 -0.05 0.04 6,031,108.39 469,923.99 0.21 -0.05 SRG-SS(1) 172.00 0.15 342.94 172.00 115.80 -0.02 0.05 6,031,108.42 469,924.00 0.37 -0.03 SRG-SS(1) 261.00 1.50 148.91 260.99 204.79 -0.90 0.62 6,031,107.53 469,924.57 1.85 -1.00 SRG-SS(1) 354.00 4.95 146.57 353.83 297.63 -5.30 3.46 6,031,103.13 469,927.39 3.71 -5.80 SRG-SS(1) 448.00 9.11 143.99 447.10 390.90 -14.70 10.07 6,031,093.70 469,933.96 4.44 -16.20 SRG-SS(1) 541.00 11.62 142.76 538.58 482.38 -28.12 20.07 6,031,080.24 469,943.91 2.71 -31.11 SRG-SS(1) 636.00 10.55 138.46 631.81 575.61 -42.25 31.63 6,031,066.07 469,955.41 1.42 -46.98 SRG-SS(1) 729.00 10.64 121.05 723.24 667.04 -53.05 44.63 6,031,055.22 469,968.36 3.43 -59.83 SRG-SS(1) 12/14/2012 11:00:26AM Page 2 COMPASS 2003.16 Build 42 • 0 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development ND Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 Database: EDM Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (11001 (ft) Survey Tool Name 775.48 10.70 114.93 768.92 712.72 -57.08 52.22 6,031,051.15 469,975.94 2.44 -65.09 MWD+IFR2+MS+sag(2) 871.35 10.29 106.10 863.19 806.99 -63.21 68.52 6,031,044.96 469,992.21 1.73 -73.88 MWD+IFR2+MS+sag(2) 967.21 8.57 109.64 957.76 901.56 -67.98 83.48 6,031,040.13 470,007.14 1.89 -81.11 MWD+IFR2+MS+sag(2) 1,057.98 8.88 89.26 1,047.50 991.30 -70.17 96.85 6,031,037.89 470,020.51 , 3.40 -85.53 MWD+IFR2+MS+sag(2) 1,156.87 8.63 82.17 1,145.24 1,089.04 -69.06 111.84 6,031,038.94 470,035.50 1.12 -86.96 MWD+IFR2+MS+sag(2) 1,252.66 9.64 75.68 1,239.81 1,183.61 -66.09 126.73 6,031,041.84 470,050.40 1.50 -86.56 MWD+IFR2+MS+sag(2) 1,344.56 11.97 66.08 1,330.09 1,273.89 -60.33 142.90 6,031,047.54 470,066.59 3.20 -83.61 MWD+IFR2+MS+sag(2) 1,443.83 14.03 61.93 1,426.81 1,370.61 -50.49 162.93 6,031,057.30 470,086.66 2.28 -77.30 MWD+IFR2+MS+sag(2) 1,538.72 16.10 60.74 1,518.43 1,462.23 -38.64 184.56 6,031,069.05 470,108.33 2.21 -69.28 MWD+IFR2+MS+sag(2) 1,630.58 18.58 58.48 1,606.11 1,549.91 -24.76 208.15 6,031,082.84 470,131.98 2.80 -59.59 MWD+IFR2+MS+sag(2) 1,726.05 20.24 53.90 1,696.16 1,639.96 -7.08 234.46 6,031,100.41 470,158.36 2.36 -46.60 MWD+IFR2+MS+sag(2) 1,823.57 23.59 50.42 1,786.62 1,730.42 15.30 263.14 6,031,122.67 470,187.13 3.68 -29.39 MWD+IFR2+MS+sag(2) 1,919.50 24.52 50.45 1,874.22 1,818.02 40.20 293.29 6,031,147.45 470,217.37 0.97 -9.94 MWD+IFR2+MS+sag(2) 2,012.11 26.18 49.20 1,957.91 1,901.71 65.79 323.57 6,031,172.92 470,247.75 1.88 10.16 MWD+IFR2+MS+sag(2) 2,108.98 29.74 46.35 2,043.46 1,987.26 96.35 357.14 6,031,203.34 470,281.45 3.92 34.61 MWD+IFR2+MS+sag(2) 2,203.85 30.55 43.54 2,125.51 2,069.31 130.07 390.78 6,031,236.92 470,315.22 1.71 62.16 MWD+IFR2+MS+sag(2) 2,300.31 30.90 43.41 2,208.43 2,152.23 165.84 424.69 6,031,272.54 470,349.27 0.37 91.68 MWD+IFR2+MS+sag(2) 2,394.61 30.17 41.08 2,289.65 2,233.45 201.29 456.90 6,031,307.86 470,381.62 1.47 121.18 MWD+IFR2+MS+sag(2) 2,485.66 32.87 41.15 2,367.26 2,311.06 237.15 488.20 6,031,343.59 470,413.06 2.97 151.23 MWD+IFR2+MS+sag(2) 2,582.97 34.96 40.94 2,448.01 2,391.81 278.10 523.85 6,031,384.39 470,448.87 2.15 185.56 MWD+IFR2+MS+sag(2) 2,676.49 35.93 37.95 2,524.20 2,468.00 319.98 558.29 6,031,426.12 470,483.47 2.12 221.02 MWD+IFR2+MS+sag(2) 2,772.74 37.48 37.32 2,601.37 2,545.17 365.54 593.41 6,031,471.54 470,518.77 1.66 259.99 MWD+IFR2+MS+sag(2) 2,866.80 38.36 38.20 2,675.57 2,619.37 411.23 628.81 6,031,517.08 470,554.35 1.10 299.05 MWD+IFR2+MS+sag(2) 2,962.28 39.48 38.14 2,749.85 2,693.65 458.39 665.88 6,031,564.09 470,591.61 1.17 339.26 MWD+IFR2+MS+sag(2) 3,056.78 42.54 37.76 2,821.15 2,764.95 507.29 704.00 6,031,612.82 470,629.93 3.25 381.01 MWD+IFR2+MS+sag(2) 3,152.51 44.40 38.36 2,890.62 2,834.42 559.14 744.61 6,031,664.50 470,670.74 1.99 425.25 MWD+IFR2+MS+sag(2) 3,244.56 45.78 38.50 2,955.61 2,899.41 610.20 785.13 6,031,715.40 470,711.46 1.50 468.73 MWD+IFR2+MS+sag(2) 3,339.91 44.52 38.40 3,022.85 2,966.65 663.14 827.16 6,031,768.16 470,753.70 1.32 513.81 MWD+IFR2+MS+sag(2) 3,437.78 44.79 38.83 3,092.47 3,036.27 716.89 870.09 6,031,821.73 470,796.84 0.41 559.52 MWD+IFR2+MS+sag(2) 3,531.82 46.35 36.87 3,158.31 3,102.11 769.92 911.28 6,031,874.59 470,838.24 2.23 604.83 MWD+IFR2+MS+sag(2) 3,628.46 46.31 36.78 3,225.04 3,168.84 825.87 953.18 6,031,930.36 470,880.36 0.08 652.90 MWD+IFR2+MS+sag(2) 3,721.08 49.15 38.54 3,287.33 3,231.13 880.10 995.06 6,031,984.42 470,922.46 3.37 699.27 MWD+IFR2+MS+sag(2) 3,815.98 52.06 38.95 3,347.55 3,291.35 937.29 1,040.96 6,032,041.42 470,968.59 3.08 747.88 MWD+IFR2+MS+sag(2) 3,913.69 53.35 38.96 3,406.76 3,350.56 997.74 1,089.83 6,032,101.66 471,017.70 1.32 799.20 MWD+IFR2+MS+sag(2) 4,007.06 52.27 39.23 3,463.20 3,407.00 1,055.47 1,136.73 6,032,159.19 471,064.83 1.18 848.17 MWD+IFR2+MS+sag(2) 4,093.51 53.19 39.45 3,515.55 3,459.35 1,108.67 1,180.34 6,032,212.22 471,108.65 1.08 893.24 MWD+IFR2+MS+sag(2) 4,193.35 50.77 38.33 3,577.04 3,520.84 1,169.88 1,229.73 6,032,273.22 471,158.28 2.58 945.22 MWD+IFR2+MS+sag(3) 4,235.17 50.22 38.20 3,603.64 3,547.44 1,195.21 1,249.71 6,032,298.47 471,178.36 1.34 966.81 MWD+IFR2+MS+sag(3) 4,329.62 50.67 36.91 3,663.79 3,607.59 1,252.94 1,294.10 6,032,356.01 471,222.97 1.16 1,016.21 MWD+IFR2+MS+sag(3) 4,424.83 50.66 37.77 3,724.14 3,667.94 1,311.49 1,338.76 6,032,414.37 471,267.87 0.70 1,066.37 MWD+IFR2+MS+sag(3) 12/14/2012 11:00:26AM Page 3 COMPASS 2003.16 Build 42 • Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development ND Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 Database: EDM Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (1100') (ft) Survey Tool Name 4,520.03 51.23 38.51 3,784.12 3,727.92 1,369.63 1,384.42 6,032,472.32 471,313.76 0.85 1,115.96 MWD+IFR2+MS+sag(3) 4,614.29 51.72 40.80 3,842.84 3,786.64 1,426.40 1,431.48 6,032,528.89 471,361.04 1.97 1,163.95 MWD+IFR2+MS+sag(3) 4,710.58 51.23 38.43 3,902.82 3,846.62 1,484.42 1,479.51 6,032,586.71 471,409.30 1.99 1,213.02 MWD+IFR2+MS+sag(3) 4,805.30 49.64 37.91 3,963.15 3,906.95 1,541.82 1,524.63 6,032,643.92 471,454.66 1.73 1,261.97 MWD+IFR2+MS+sag(3) 4,899.73 49.48 38.02 4,024.40 3,968.20 1,598.48 1,568.85 6,032,700.40 471,499.09 0.19 1,310.34 MWD+IFR2+MS+sag(3) 4,992.80 50.29 38.34 4,084.37 4,028.17 1,654.43 1,612.84 6,032,756.16 471,543.31 0.91 1,358.05 MWD+IFR2+MS+sag(3) 5,090.15 50.44 39.45 4,146.47 4,090.27 1,712.78 1,659.92 6,032,814.31 471,590.61 0.89 1,407.60 MWD+IFR2+MS+sag(3) 5,185.51 51.01 37.43 4,206.84 4,150.64 1,770.59 1,705.80 6,032,871.94 471,636.73 1.75 1,456.83 MWD+IFR2+MS+sag(3) 5,280.47 50.10 37.49 4,267.17 4,210.97 1,828.80 1,750.40 6,032,929.96 471,681.56 0.96 1,506.67 MWD+IFR2+MS+sag(3) 5,375.64 49.67 38.02 4,328.49 4,272.29 1,886.35 1,794.96 6,032,987.32 471,726.35 0.62 1,555.85 MWD+IFR2+MS+sag(3) 5,471.03 51.32 37.62 4,389.17 4,332.97 1,944.48 1,840.09 6,033,045.27 471,771.70 1.76 1,605.53 MWD+IFR2+MS+sag(3) 5,565.75 51.40 38.05 4,448.32 4,392.12 2,002.92 1,885.47 6,033,103.51 471,817.32 0.36 1,655.45 MWD+IFR2+MS+sag(3) 5,661.24 51.07 37.96 4,508.10 4,451.90 2,061.58 1,931.31 6,033,161.98 471,863.39 0.35 1,705.52 MWD+IFR2+MS+sag(3) 5,755.74 50.60 37.62 4,567.79 4,511.59 2,119.48 1,976.21 6,033,219.70 471,908.52 0.57 1,755.00 MWD+IFR2+MS+sag(3) 5,852.58 50.84 37.86 4,629.10 4,572.90 2,178.76 2,022.09 6,033,278.78 471,954.64 0.31 1,805.68 MWD+IFR2+MS+sag(3) 5,948,17 51.25 37.06 4,689.20 4,633.00 2,237.77 2,067.30 6,033,337.60 472,000.08 0.78 1,856.19 MWD+IFR2+MS+sag(3) 6,041.98 50.15 37.38 4,748.61 4,692.41 2,295.57 2,111.21 6,033,395.22 472,044.22 1.20 1,905.75 MWD+IFR2+MS+sag(3) 6,136.90 49.57 37.71 4,809.80 4,753.60 2,353.11 2,155.43 6,033,452.57 472,088.66 0.67 1,954.98 MWD+IFR2+MS+sag(3) 6,233.24 49.87 39.47 4,872.09 4,815.89 2,410.55 2,201.27 6,033,509.82 472,134.73 1.43 2,003.85 MWD+IFR2+MS+sag(3) 6,327.80 50.83 38.16 4,932.43 4,876.23 2,467.28 2,246.90 6,033,566.36 472,180.59 1.47 2,052.05 MWD+IFR2+MS+sag(3) 6,422.21 50.76 37.12 4,992.11 4,935.91 2,525.21 2,291.58 6,033,624.10 472,225.49 0.86 2,101.60 MWD+IFR2+MS+sag(3) 6,517.54 51.12 37.06 5,052.18 4,995.98 2,584.26 2,336.22 6,033,682.96 472,270.37 0.38 2,152.25 MWD+IFR2+MS+sag(3) 6,612.58 50.97 38.58 5,111.93 5,055.73 2,642.64 2,381.53 6,033,741.15 472,315.91 1.25 2,202.13 MWD+IFR2+MS+sag(3) 6,708.03 50.51 38.55 5,172.34 5,116.14 2,700.42 2,427.60 6,033,798.75 472,362.21 0.48 2,251.30 MWD+IFR2+MS+sag(3) 6,803.17 50.84 38.39 5,232.63 5,176.43 2,758.04 2,473.39 6,033,856.18 472,408.23 0.37 2,300.35 MWD+IFR2+MS+sag(3) 6,898.93 51.00 39.16 5,293.00 5,236.80 2,816.00 2,519.94 6,033,913.93 472,455.01 0.65 2,349.60 MWD+IFR2+MS+sag(3) 6,994.31 51.17 38.97 5,352.91 5,296.71 2,873.62 2,566.71 6,033,971.36 472,502.01 0.24 2,398.49 MWD+IFR2+MS+sag(3) 7,089.04 51.17 37.23 5,412.31 5,356.11 2,931.69 2,612.24 6,034,029.24 472,547.77 1.43 2,448.03 MWD+IFR2+MS+sag(3) 7,186.05 50.62 36.84 5,473.50 5,417.30 2,991.78 2,657.58 6,034,089.14 472,593.35 0.65 2,499.59 MWD+IFR2+MS+sag(3) 7,239.97 51.01 37.04 5,507.57 5,451.37 3,025.18 2,682.70 6,034,122.44 472,618.60 0.78 2,528.27 MWD+IFR2+MS+sag(4) 7,253.31 51.20 37.06 5,515.94 5,459.74 3,033.47 2,688.96 6,034,130.70 472,624.89 1.43 2,535.38 MWD+IFR2+MS+sag(4) 7,347.99 51.20 38.68 5,575.27 5,519.07 3,091.71 2,734.25 6,034,188.75 472,670.41 1.33 2,585.14 MWD+IFR2+MS+sag(4) 7,443.25 50.19 38.10 5,635.62 5,579.42 3,149.48 2,780.03 6,034,246.33 472,716.42 1.16 2,634.34 MWD+IFR2+MS+sag(4) 7,538.01 49.51 37.02 5,696.72 5,640.52 3,206.90 2,824.18 6,034,303.56 472,760.80 1.13 2,683.46 MWD+IFR2+MS+sag(4) 7,633.13 50.49 34.29 5,757.86 5,701.66 3,266.10 2,866.64 6,034,362.59 472,803.49 2.43 2,734.64 MWD+IFR2+MS+sag(4) 7,728.76 51.43 30.23 5,818.11 5,761.91 3,328.90 2,906.25 6,034,425.22 472,843.35 3.44 2,789.84 MWD+IFR2+MS+sag(4) 7,822.71 52.22 26.12 5,876.20 5,820.00 3,393.98 2,941.10 6,034,490.15 472,878.46 3.54 2,848.10 MWD+IFR2+MS+sag(4) 7,919.13 51.97 19.97 5,935.47 5,879.27 3,463.93 2,970.86 6,034,559.97 472,908.50 5.04 2,912.01 MWD+IFR2+MS+sag(4) 8,014.10 52.00 15.77 5,993.97 5,937.77 3,535.11 2,993.81 6,034,631.06 472,931.74 3.48 2,978.29 MWD+IFR2+MS+sag(4) 8,109.08 54.08 9.02 6,051.12 5,994.92 3,609.17 3,010.03 6,034,705.04 472,948.25 6.08 3,048.54 MWD+IFR2+MS+sag(4) 12/14/2012 11:00:26AM Page 4 COMPASS 2003.16 Build 42 • Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 Database: EDM Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (7) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 8,204.65 55.50 4.49 6,106.24 6,050.04 3,686.68 3,019.18 6,034,782.51 472,957.72 4.15 3,123.39 MWD+IFR2+MS+sag(4) 8,299.52 56.76 357.64 6,159.15 6,102.95 3,765.36 3,020.61 6,034,861.17 472,959.46 6.14 3,200.70 MWD+IFR2+MS+sag(4) 8,395.04 59.96 354.49 6,209.26 6,153.06 3,846.47 3,014.99 6,034,942.29 472,954.17 4.37 3,281.58 MWD+IFR2+MS+sag(4) 8,490.01 63.54 352.73 6,254.21 6,198.01 3,929.58 3,005.66 6,035,025.43 472,945.18 4.11 3,365.08 MWD+IFR2+MS+sag(4) 8,585.18 68.13 351.60 6,293.16 6,236.96 4,015.58 2,993.81 6,035,111.47 472,933.68 4.94 3,451.84 MWD+IFR2+MS+sag(4) 8,680.70 72.73 351.59 6,325.15 6,268.95 4,104.59 2,980.66 6,035,200.52 472,920.89 4.82 3,541.80 MWD+IFR2+MS+sag(4) 8,775.68 77.59 351.73 6,349.47 6,293.27 4,195.40 2,967.35 6,035,291.38 472,907.95 5.12 3,633.55 MWD+IFR2+MS+sag(4) 8,871.40 81.78 350.38 6,366.60 6,310.40 4,288.40 2,952.70 6,035,384.43 472,893.68 4.59 3,727.69 MWD+IFR2+MS+sag(4) 8,966.20 85.58 350.25 6,377.04 6,320.84 4,381.27 2,936.85 6,035,477.35 472,878.21 4.01 3,821.90 MWD+IFR2+MS+sag(4) 9,017.12 87.31 349.59 6,380.19 6,323.99 4,431.30 2,927.96 6,035,527.41 472,869.52 3.64 3,872.72 MWD+IFR2+MS+sag(4) 9,060.56 87.43 349.78 6,382.19 6,325.99 4,474.00 2,920.19 6,035,570.13 472,861.92 0.52 3,916.11 MWD+IFR2+MS+sag(4) 9,112.53 87.43 349.67 6,384.52 6,328.32 4,525.08 2,910.93 6,035,621.25 472,852.87 0.21 3,968.03 MWD+IFR2+MS+sag(4) 9,156.56 87.01 349.26 6,386.65 6,330.45 4,568.32 2,902.89 6,035,664.52 472,845.00 1.33 4,012.00 MWD+IFR2+MS+sag(4) 9,252.44 87.06 344.00 6,391.62 6,335.42 4,661.44 2,880.75 6,035,757.72 472,823.25 5.48 4,107.53 MWD+IFR2+MS+sag(4) 9,346.04 85.39 339.79 6,397.78 6,341.58 4,750.19 2,851.74 6,035,846.58 472,794.60 4.83 4,199.90 MWD+IFR2+MS+sag(4) 9,442.51 84.96 334.69 6,405.90 6,349.70 4,838.81 2,814.56 6,035,935.33 472,757.78 5.29 4,293.52 MWD+IFR2+MS+sag(4) 9,537.10 85.58 330.13 6,413.70 6,357.50 4,922.33 2,770.91 6,036,019.02 472,714.48 4.85 4,383.22 MWD+IFR2+MS+sag(4) 9,632.57 85.64 324.03 6,421.02 6,364.82 5,002.20 2,719.21 6,036,099.09 472,663.10 6.37 4,470.68 MWD+IFR2+MS+sag(4) 9,663.68 85.70 322.57 6,423.37 6,367.17 5,027.07 2,700.67 6,036,124.03 472,644.66 4.68 4,498.33 MWD+IFR2+MS+sag(4) 9,697.60 85.58 320.58 6,425.95 6,369.75 5,053.56 2,679.65 6,036,150.61 472,623.75 5.86 4,527.99 MWD+IFR2+MS+sag(4) 9,776.75 87.78 318.00 6,430.53 6,374.33 5,113.45 2,628.12 6,036,210.70 472,572.47 4.28 4,595.73 MWD+IFR2+MS+sag(5) 9,862.68 88.58 317.11 6,433.26 6,377.06 5,176.83 2,570.16 6,036,274.30 472,514.77 1.39 4,667.99 MWD+IFR2+MS+sag(5) 9,959.37 88.46 317.67 6,435.76 6,379.56 5,247.97 2,504.72 6,036,345.70 472,449.63 0.59 4,749.16 MWD+IFR2+MS+sag(5) 10,055.30 86.60 317.60 6,439.89 6,383.69 5,318.78 2,440.14 6,036,416.76 472,385.34 1.94 4,829.87 MWD+IFR2+MS+sag(5) 10,152.06 88.21 316.05 6,444.27 6,388.07 5,389.26 2,374.00 6,036,487.51 472,319.50 2.31 4,910.52 MWD+IFR2+MS+sag(5) 10,248.25 90.74 313.95 6,445.15 6,388.95 5,457.27 2,306.00 6,036,555.78 472,251.78 3.42 4,989.04 MWD+IFR2+MS+sag(5) 10,344.58 90.99 313.70 6,443.70 6,387.50 5,523.96 2,236.51 6,036,622.75 472,182.56 0.37 5,066.52 MWD+IFR2+MS+sag(5) 10,441.15 91.67 313.39 6,441.46 6,385.26 5,590.47 2,166.53 6,036,689.54 472,112.86 0.77 5,143.90 MWD+IFR2+MS+sag(5) 10,536.95 92.22 312.87 6,438.21 6,382.01 5,655.93 2,096.66 6,036,755.27 472,043.26 0.79 5,220.22 MWD+IFR2+MS+sag(5) 10,633.35 91.85 314.43 6,434.78 6,378.58 5,722.43 2,026.95 6,036,822.04 471,973.83 1.66 5,297.54 MWD+IFR2+MS+sag(5) 10,729.68 90.56 314.67 6,432.76 6,376.56 5,789.99 1,958.32 6,036,889.87 471,905.48 1.36 5,375.73 MWD+IFR2+MS+sag(5) 10,825.68 91.30 314.76 6,431.20 6,375.00 5,857.52 1,890.11 6,036,957.68 471,837.55 0.78 5,453.82 MWD+IFR2+MS+sag(5) 10,922.06 90.37 313.66 6,429.80 6,373.60 5,924.72 1,821.03 6,037,025.15 471,768.76 1.49 5,531.73 MWD+IFR2+MS+sag(5) 11,018.42 91.17 310.85 6,428.50 6,372.30 5,989.50 1,749.73 6,037,090.21 471,697.72 3.03 5,607.63 MWD+IFR2+MS+sag(5) 11,115.04 92.47 310.17 6,425.43 6,369.23 6,052.23 1,676.31 6,037,153.23 471,624.56 1.52 5,681.87 MWD+IFR2+MS+sag(5) 11,210.97 92.59 309.82 6,421.20 6,365.00 6,113.83 1,602.89 6,037,215.12 471,551.40 0.39 5,754.98 MWD+IFR2+MS+sag(5) 11,307.49 92.29 311.57 6,417.09 6,360.89 6,176.70 1,529.78 6,037,278.28 471,478.55 1.84 5,829.31 MWD+IFR2+MS+sag(5) 11,403.74 91.54 313.13 6,413.87 6,357.67 6,241.50 1,458.69 6,037,343.36 471,407.73 1.80 5,905.19 MWD+IFR2+MS+sag(5) 11,500.65 91.61 314.11 6,411.21 6,355.01 6,308.33 1,388.56 6,037,410.47 471,337.88 1.01 5,982.91 MWD+IFR2+MS+sag(5) 11,595.80 92.16 315.42 6,408.08 6,351.88 6,375.30 1,321.04 6,037,477.70 471,270.64 1.49 6,060.33 MWD+IFR2+MS+sag(5) 12/14/2012 11:00:26AM Page 5 COMPASS 2003.16 Build 42 • • Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (7) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (41100') (ft) Survey Tool Name 11,692.96 89.82 317.05 6,406.40 6,350.20 6,445.45 1,253.85 6,037,548.11 471,203.74 2.93 6,140.82 MWD+IFR2+MS+sag(5) 11,787.10 89.75 316.37 6,406.75 6,350.55 6,513.97 1,189.30 6,037,616.89 471,139.47 0.73 6,219.27 MWD+IFR2+MS+sag(5) 11,885.85 90.06 316.41 6,406.92 6,350.72 6,585.47 1,121.19 6,037,688.66 471,071.66 0.32 6,301.25 MWD+IFR2+MS+sag(5) 11,930.00 91.64 315.62 6,406.26 6,350.06 6,617.23 1,090.53 6,037,720.54 471,041.13 4.00 6,337.74 MWD+IFR2+MS+sag(6) 11,982.38 88.70 316.59 6,406.11 6,349.91 6,654.98 1,054.22 6,037,758.42 471,004.98 5.91 6,381.08 MWD+IFR2+MS+sag(6) 12,078.63 90.49 317.22 6,406.79 6,350.59 6,725.25 988.46 6,037,828.96 470,939.51 1.97 6,461.46 MWD+IFR2+MS+sag(6) 12,173.76 89.69 319.77 6,406.64 6,350.44 6,796.49 925.43 6,037,900.44 470,876.77 2.81 6,542.32 MWD+IFR2+MS+sag(6) 12,270.70 88.95 319.99 6,407.79 6,351.59 6,870.61 862.97 6,037,974.81 470,814.62 0.80 6,625.94 MWD+IFR2+MS+sag(6) 12,367.70 90.00 322.34 6,408.68 6,352.48 6,946.16 802.15 6,038,050.60 470,754.11 2.65 6,710.68 MWD+IFR2+MS+sag(6) 12,463.93 90.37 324.79 6,408.36 6,352.16 7,023.58 745.00 6,038,128.24 470,697.28 2.57 6,796.63 MWD+IFR2+MS+sag(6) 12,560.38 87.10 323.14 6,410.49 6,354.29 7,101.54 688.28 6,038,206.42 470,640.89 3.80 6,883.06 MWD+IFR2+MS+sag(6) 12,656.14 88.21 318.40 6,414.41 6,358.21 7,175.63 627.79 6,038,280.75 470,580.70 5.08 6,966.31 MWD+IFR2+MS+sag(6) 12,753.18 88.46 312.81 6,417.24 6,361.04 7,244.91 559.96 6,038,350.30 470,513.16 5.76 7,046.06 MWD+IFR2+MS+sag(6) 12,849.23 92.10 310.33 6,416.77 6,360.57 7,308.63 488.12 6,038,414.30 470,441.58 4.59 7,121.00 MWD+IFR2+MS+sag(6) 12,945.70 91.91 311.58 6,413.39 6,357.19 7,371.82 415.31 6,038,477.78 470,369.03 1.31 7,195.59 MWD+IFR2+MS+sag(6) 13,041.26 92.60 311.23 6,409.63 6,353.43 7,434.97 343.69 6,038,541.21 470,297.68 0.81 7,269.94 MWD+IFR2+MS+sag(6) 13,138.40 92.78 310.74 6,405.07 6,348.87 7,498.61 270.44 6,038,605.14 470,224.70 0.54 7,345.04 MWD+IFR2+MS+sag(7) 13,160.00 92.77 310.86 6,404.03 6,347.83 7,512.71 254.11 6,038,619.30 470,208.42 0.56 7,361.70 MWD+IFR2+MS+sag(7) 13,234.94 90.68 312.66 6,401.77 6,345.57 7,562.60 198.24 6,038,669.41 470,152.76 3.68 7,420.30 MWD+IFR2+MS+sag(7) 13,266.42 91.23 316.02 6,401.25 6,345.05 7,584.59 175.73 6,038,691.49 470,130.34 10.81 7,445.79 MWD+IFR2+MS+sag(7) 13,298.81 91.05 319.60 6,400.60 6,344.40 7,608.58 153.98 6,038,715.57 470,108.70 11.06 7,473.11 MWD+IFR2+MS+sag(7) 13,331.05 89.75 321.63 6,400.38 6,344.18 7,633.50 133.53 6,038,740.56 470,088.35 7.48 7,501.12 MWD+IFR2+MS+sag(7) 13,375.93 87.03 320.97 6,401.64 6,345.44 7,668.50 105.48 6,038,775.68 470,060.44 6.24 7,540.37 MWD+IFR2+MS+sag(7) 13,425.25 87.30 320.72 6,404.08 6,347.88 7,706.70 74.38 6,038,814.00 470,029.50 0.75 7,583.27 MWD+IFR2+MS+sag(7) 13,521.42 87.61 320.24 6,408.35 6,352.15 7,780.82 13.24 6,038,888.35 469,968.67 0.59 7,666.65 MWD+IFR2+MS+sag(7) 13,620.64 87.37 318.22 6,412.69 6,356.49 7,855.88 -51.49 6,038,963.67 469,904.25 2.05 7,751.58 MWD+IFR2+MS+sag(7) 13,713.69 88.09 316.20 6,416.38 6,360.18 7,924.11 -114.64 6,039,032.15 469,841.38 2.30 7,829.50 MWD+IFR2+MS+sag(7) 13,813.11 87.22 317.68 6,420.45 6,364.25 7,996.69 -182.46 6,039,104.99 469,773.86 1.73 7,912.49 MWD+IFR2+MS+sag(7) 13,908.93 89.73 316.11 6,423.00 6,366.80 8,066.61 -247.91 6,039,175.17 469,708.70 3.09 7,992.47 MWD+IFR2+MS+sag(7) 14,006.48 90.23 315.81 6,423.03 6,366.83 8,136.73 -315.72 6,039,245.56 469,641.18 0.60 8,073.05 MWD+IFR2+MS+sag(7) 14,102.79 89.29 314.52 6,423.43 6,367.23 8,205.03 -383.63 6,039,314.13 469,573.56 1.66 8,151.84 MWD+IFR2+MS+sag(7) 14,195.99 89.38 313.30 6,424.52 6,368.32 8,269.66 -450.76 6,039,379.02 469,506.69 1.31 8,226.88 MWD+IFR2+MS+sag(7) 14,293.79 89.56 313.82 6,425.42 6,369.22 8,337.05 -521.63 6,039,446.69 469,436.10 0.56 8,305.28 MWD+IFR2+MS+sag(7) 14,390.20 88.63 314.82 6,426.94 6,370.74 8,404.40 -590.60 6,039,514.31 469,367.42 1.42 8,383.32 MWD+IFR2+MS+sag(7) 14,485.27 90.58 314.45 6,427.60 6,371.40 8,471.19 -658.25 6,039,581.37 469,300.05 2.09 8,460.58 MWD+IFR2+MS+sag(7) 14,581.72 89.93 314.43 6,427.17 6,370.97 8,538.72 -727.11 6,039,649.17 469,231.47 0.67 8,538.78 MWD+IFR2+MS+sag(7) 14,679.67 89.62 313.98 6,427.55 6,371.35 8,607.01 -797.32 6,039,717.74 469,161.54 0.56 8,617.95 MWD+IFR2+MS+sag(7) 14,776.13 89.10 313.02 6,428.63 6,372.43 8,673.41 -867.29 6,039,784.41 469,091.85 1.13 8,695.22 MWD+IFR2+MS+sag(7) 14,872.86 89.03 312.36 6,430.21 6,374.01 8,738.98 -938.38 6,039,850.27 469,021.03 0.69 8,771.86 MWD+IFR2+MS+sag(7) 14,964.83 89.75 313.07 6,431.19 6,374.99 8,801.37 -1,005.95 6,039,912.92 468,953.72 1.10 8,844.77 MWD+IFR2+MS+sag(7) 12/14/2012 11:00:26AM Page 6 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 Database: EDM Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°l100') (ft) Survey Tool Name 15,063.55 89.94 312.28 6,431.46 6,375.26 8,868.28 -1,078.53 6,039,980.12 468,881.42 0.82 8,922.99 MWD+IFR2+MS+sag(7) 15,155.42 90.03 312.05 6,431.48 6,375.28 8,929.95 -1,146.62 6,040,042.06 468,813.58 0.27 8,995.28 MWD+IFR2+MS+sag(7) 15,254.31 90.00 312.14 6,431.45 6,375.25 8,996.24 -1,220.00 6,040,108.64 468,740.48 0.10 9,073.02 MWD+IFR2+MS+sag(7) 15,351.08 90.52 313.51 6,431.02 6,374.82 9,062.02 -1,290.97 6,040,174.70 468,669.78 1.51 9,149.85 MWD+IFR2+MS+sag(7) 15,448.71 90.06 314.71 6,430.52 6,374.32 9,129.97 -1,361.07 6,040,242.92 468,599.97 1.32 9,228.67 MWD+IFR2+MS+sag(7) 15,545.35 90.69 316.31 6,429.89 6,373.69 9,198.91 -1,428.79 6,040,312.13 468,532.53 1.78 9,308.06 MWD+IFR2+MS+sag(7) 15,641.71 89.87 316.89 6,429.42 6,373.22 9,268.92 -1,494.99 6,040,382.40 468,466.62 1.04 9,388.25 MWD+IFR2+MS+sag(7) 15,716.00 89.87 316.89 6,429.59 6,373.39 9,323.16 -1,545.76 6,040,436.83 468,416.07 0.00 9,450.29 PROJECTED to TD 12/14/201211:00:26AM Page 7 COMPASS 2003.16 Build 42 • Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-29 PN5 PB1 50-703-20661-00-70 Sperry Drilling Services Definitive Survey Report 14 December, 2012 HALLIBURTON Sperry Drilling Services • 0 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB1 Database: EDM Alaska Project Oooguruk Development Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well ODSN-29 Well Position +N/-S 0.00 ft Northing: 6,031,108.44 ft Latitude: 70°29'45.820 N +E/-W 0.00 ft Easting: 469,923.95 ft Longitude: 150° 14'45.357 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSN-29 PN5 PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF2010 10/10/2012 20.57 80.97 57,668 Design ODSN-29 PN5 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) (bearing) 42.70 0.00 0.00 350.27 Survey Program Date 12/14/2012 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 100.00 729.00 ODSN-29 GYRO(ODSN-29 PN5 PB1) SRG-SS Surface readout gyro single shot 11/07/2012 775.48 4,139.70 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 4,139.70 7,238.00 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 7,238.00 9,759.10 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 9,759.10 12,367.53 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (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 6,031,108.44 469,923.95 0.00 0.00 UNDEFINED 100.00 0.12 142.74 100.00 43.80 -0.05 0.04 6,031,108.39 469,923.99 0.21 -0.05 SRG-SS(1) 172.00 0.15 342.94 172.00 115.80 -0.02 0.05 6,031,108.42 469,924.00 0.37 -0.03 SRG-SS(1) 261.00 1.50 148.91 260.99 204.79 -0.90 0.62 6,031,107.53 469,924.57 1.85 -1.00 SRG-SS(1) 354.00 4.95 146.57 353.83 297.63 -5.30 3.46 6,031,103.13 469,927.39 3.71 -5.80 SRG-SS(1) 448.00 9.11 143.99 447.10 390.90 -14.70 10.07 6,031,093.70 469,933.96 4.44 -16.20 SRG-SS(1) 541.00 11.62 142.76 538.58 482.38 -28.12 20.07 6,031,080.24 469,943.91 2.71 -31.11 SRG-SS(1) 636.00 10.55 138.46 631.81 575.61 -42.25 31.63 6,031,066.07 469,955.41 1.42 -46.98 SRG-SS(1) 729.00 10.64 121.05 723.24 667.04 -53.05 44.63 6,031,055.22 469,968.36 3.43 -59.83 SRG-SS(1) 775.48 10.70 114.93 768.92 712.72 -57.08 52.22 6,031,051.15 469,975.94 2.44 -65.09 MWD+IFR2+MS+sag(2) 12/14/2012 12:52:27PM Page 2 COMPASS 2003.16 Build 42 • r Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB1 Database: EDM Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (%100') (ft) Survey Tool Name 871.35 10.29 106.10 863.19 806.99 -63.21 68.52 6,031,044.96 469,992.21 1.73 -73.88 MWD+IFR2+MS+sag(2) 967.21 8.57 109.64 957.76 901.56 -67.98 83.48 6,031,040.13 470,007.14 1.89 -81.11 MWD+IFR2+MS+sag(2) 1,057.98 8.88 89.26 1,047.50 991.30 -70.17 96.85 6,031,037.89 470,020.51 3.40 -85.53 MWD+IFR2+MS+sag(2) 1,156.87 8.63 82.17 1,145.24 1,089.04 -69.06 111.84 6,031,038.94 470,035.50 1.12 -86.96 MWD+IFR2+MS+sag(2) 1,252.66 9.64 75.68 1,239.81 1,183.61 -66.09 126.73 6,031,041.84 470,050.40 1.50 -86.56 MWD+IFR2+MS+sag(2) 1,344.56 11.97 66.08 1,330.09 1,273.89 -60.33 142.90 6,031,047.54 470,066.59 3.20 -83.61 MWD+IFR2+MS+sag(2) 1,443.83 14.03 61.93 1,426.81 1,370.61 -50.49 162.93 6,031,057.30 470,086.66 2.28 -77.30 MWD+IFR2+MS+sag(2) 1,538.72 16.10 60.74 1,518.43 1,462.23 -38.64 184.56 6,031,069.05 470,108.33 2.21 -69.28 MWD+IFR2+MS+sag(2) 1,630.58 18.58 58.48 1,606.11 1,549.91 -24.76 208.15 6,031,082.84 470,131.98 2.80 -59.59 MWD+IFR2+MS+sag(2) 1,726.05 20.24 53.90 1,696.16 1,639.96 -7.08 234.46 6,031,100.41 470,158.36 2.36 -46.60 MWD+IFR2+MS+sag(2) 1,823.57 23.59 50.42 1,786.62 1,730.42 15.30 263.14 6,031,122.67 470,187.13 3.68 -29.39 MWD+IFR2+MS+sag(2) 1,919.50 24.52 50.45 1,874.22 1,818.02 40.20 293.29 6,031,147.45 470,217.37 0.97 -9.94 MWD+IFR2+MS+sag(2) 2,012.11 26.18 49.20 1,957.91 1,901.71 65.79 323.57 6,031,172.92 470,247.75 1.88 10.16 MWD+IFR2+MS+sag(2) 2,108.98 29.74 46.35 2,043.46 1,987.26 96.35 357.14 6,031,203.34 470,281.45 3.92 34.61 MWD+IFR2+MS+sag(2) 2,203.85 30.55 43.54 2,125.51 2,069.31 130.07 390.78 6,031,236.92 470,315.22 1.71 62.16 MWD+IFR2+MS+sag(2) 2,300.31 30.90 43.41 2,208.43 2,152.23 165.84 424.69 6,031,272.54 470,349.27 0.37 91.68 MWD+IFR2+MS+sag(2) 2,394.61 30.17 41.08 2,289.65 2,233.45 201.29 456.90 6,031,307.86 470,381.62 1.47 121.18 MWD+IFR2+MS+sag(2) 2,485.66 32.87 41.15 2,367.26 2,311.06 237.15 488.20 6,031,343.59 470,413.06 2.97 151.23 MWD+IFR2+MS+sag(2) 2,582.97 34.96 40.94 2,448.01 2,391.81 278.10 523.85 6,031,384.39 470,448.87 2.15 185.56 MWD+IFR2+MS+sag(2) 2,676.49 35.93 37.95 2,524.20 2,468.00 319.98 558.29 6,031,426.12 470,483.47 2.12 221.02 MWD+IFR2+MS+sag(2) 2,772.74 37.48 37.32 2,601.37 2,545.17 365.54 593.41 6,031,471.54 470,518.77 1.66 259.99 MWD+IFR2+MS+sag(2) 2,866.80 38.36 38.20 2,675.57 2,619.37 411.23 628.81 6,031,517.08 470,554.35 1.10 299.05 MWD+IFR2+MS+sag(2) 2,962.28 39.48 38.14 2,749.85 2,693.65 458.39 665.88 6,031,564.09 470,591.61 1.17 339.26 MWD+IFR2+MS+sag(2) 3,056.78 42.54 37.76 2,821.15 2,764.95 507.29 704.00 6,031,612.82 470,629.93 3.25 381.01 MWD+IFR2+MS+sag(2) 3,152.51 44.40 38.36 2,890.62 2,834.42 559.14 744.61 6,031,664.50 470,670.74 1.99 425.25 MWD+IFR2+MS+sag(2) 3,244.56 45.78 38.50 2,955.61 2,899.41 610.20 785.13 6,031,715.40 470,711.46 1.50 468.73 MWD+IFR2+MS+sag(2) 3,339.91 44.52 38.40 3,022.85 2,966.65 663.14 827.16 6,031,768.16 470,753.70 1.32 513.81 MWD+IFR2+MS+sag(2) 3,437.78 44.79 38.83 3,092.47 3,036.27 716.89 870.09 6,031,821.73 470,796.84 0.41 559.52 MWD+IFR2+MS+sag(2) 3,531.82 46.35 36.87 3,158.31 3,102.11 769.92 911.28 6,031,874.59 470,838.24 2.23 604.83 MWD+IFR2+MS+sag(2) 3,628.46 46.31 36.78 3,225.04 3,168.84 825.87 953.18 6,031,930.36 470,880.36 0.08 652.90 MWD+IFR2+MS+sag(2) 3,721.08 49.15 38.54 3,287.33 3,231.13 880.10 995.06 6,031,984.42 470,922.46 3.37 699.27 MWD+IFR2+MS+sag(2) 3,815.98 52.06 38.95 3,347.55 3,291.35 937.29 1,040.96 6,032,041.42 470,968.59 3.08 747.88 MWD+IFR2+MS+sag(2) 3,913.69 53.35 38.96 3,406.76 3,350.56 997.74 1,089.83 6,032,101.66 471,017.70 1.32 799.20 MWD+IFR2+MS+sag(2) 4,007.06 52.27 39.23 3,463.20 3,407.00 1,055.47 1,136.73 6,032,159.19 471,064.83 1.18 848.17 MWD+IFR2+MS+sag(2) 4,093.51 53.19 39.45 3,515.55 3,459.35 1,108.67 1,180.34 6,032,212.22 471,108.65 1.08 893.24 MWD+IFR2+MS+sag(2) 4,193.35 50.77 38.33 3,577.04 3,520.84 1,169.88 1,229.73 6,032,273.22 471,158.28 2.58 945.22 MWD+IFR2+MS+sag(3) 4,235.17 50.22 38.20 3,603.64 3,547.44 1,195.21 1,249.71 6,032,298.47 471,178.36 1.34 966.81 MWD+IFR2+MS+sag(3) 4,329.62 50.67 36.91 3,663.79 3,607.59 1,252.94 1,294.10 6,032,356.01 471,222.97 1.16 1,016.21 MWD+IFR2+MS+sag(3) 4,424.83 50.66 37.77 3,724.14 3,667.94 1,311.49 1,338.76 6,032,414.37 471,267.87 0.70 1,066.37 MWD+IFR2+MS+sag(3) 4,520.03 51.23 38.51 3,784.12 3,727.92 1,369.63 1,384.42 6,032,472.32 471,313.76 0.85 1,115.96 MWD+IFR2+MS+sag(3) 12/14/2012 12:52:27PM Page 3 COMPASS 2003.16 Build 42 • • Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB1 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N!-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°floo') (ft) Survey Tool Name 4,614.29 51.72 40.80 3,842.84 3,786.64 1,426.40 1,431.48 6,032,528.89 471,361.04 1.97 1,163.95 MWD+IFR2+MS+sag(3) 4,710.58 51.23 38.43 3,902.82 3,846.62 1,484.42 1,479.51 6,032,586.71 471,409.30 1.99 1,213.02 MWD+IFR2+MS+sag(3) 4,805.30 49.64 37.91 3,963.15 3,906.95 1,541.82 1,524.63 6,032,643.92 471,454.66 1.73 1,261.97 MWD+IFR2+MS+sag(3) 4,899.73 49.48 38.02 4,024.40 3,968.20 1,598.48 1,568.85 6,032,700.40 471,499.09 0.19 1,310.34 MWD+IFR2+MS+sag(3) 4,992.80 50.29 38.34 4,084.37 4,028.17 1,654.43 1,612.84 6,032,756.16 471,543.31 0.91 1,358.05 MWD+IFR2+MS+sag(3) 5,090.15 50.44 39.45 4,146.47 4,090.27 1,712.78 1,659.92 6,032,814.31 471,590.61 0.89 1,407.60 MWD+IFR2+MS+sag(3) 5,185.51 51.01 37.43 4,206.84 4,150.64 1,770.59 1,705.80 6,032,871.94 471,636.73 1.75 1,456.83 MWD+IFR2+MS+sag(3) 5,280.47 50.10 37.49 4,267.17 4,210.97 1,828.80 1,750.40 6,032,929.96 471,681.56 0.96 1,506.67 MWD+IFR2+MS+sag(3) 5,375.64 49.67 38.02 4,328.49 4,272.29 1,886.35 1,794.96 6,032,987.32 471,726.35 0.62 1,555.85 MWD+IFR2+MS+sag(3) 5,471.03 51.32 37.62 4,389.17 4,332.97 1,944.48 1,840.09 6,033,045.27 471,771.70 1.76 1,605.53 MWD+IFR2+MS+sag(3) 5,565.75 51.40 38.05 4,448.32 4,392.12 2,002.92 1,885.47 6,033,103.51 471,817.32 0.36 1,655.45 MWD+IFR2+MS+sag(3) 5,661.24 51.07 37.96 4,508.10 4,451.90 2,061.58 1,931.31 6,033,161.98 471,863.39 0.35 1,705.52 MWD+IFR2+MS+sag(3) 5,755.74 50.60 37.62 4,567.79 4,511.59 2,119.48 1,976.21 6,033,219.70 471,908.52 0.57 1,755.00 MWD+IFR2+MS+sag(3) 5,852.58 50.84 37.86 4,629.10 4,572.90 2,178.76 2,022.09 6,033,278.78 471,954.64 0.31 1,805.68 MWD+IFR2+MS+sag(3) 5,948.17 51.25 37.06 4,689.20 4,633.00 2,237.77 2,067.30 6,033,337.60 472,000.08 0.78 1,856.19 MWD+IFR2+MS+sag(3) 6,041.98 50.15 37.38 4,748.61 4,692.41 2,295.57 2,111.21 6,033,395.22 472,044.22 1.20 1,905.75 MWD+IFR2+MS+sag(3) 6,136.90 49.57 37.71 4,809.80 4,753.60 2,353.11 2,155.43 6,033,452.57 472,088.66 0.67 1,954.98 MWD+IFR2+MS+sag(3) 6,233.24 49.87 39.47 4,872.09 4,815.89 2,410.55 2,201.27 6,033,509.82 472,134.73 1.43 2,003.85 MWD+IFR2+MS+sag(3) 6,327.80 50.83 38.16 4,932.43 4,876.23 2,467.28 2,246.90 6,033,566.36 472,180.59 1.47 2,052.05 MWD+IFR2+MS+sag(3) 6,422.21 50.76 37.12 4,992.11 4,935.91 2,525.21 2,291.58 6,033,624.10 472,225.49 0.86 2,101.60 MWD+IFR2+MS+sag(3) 6,517.54 51.12 37.06 5,052.18 4,995.98 2,584.26 2,336.22 6,033,682.96 472,270.37 0.38 2,152.25 MWD+IFR2+MS+sag(3) 6,612.58 50.97 38.58 5,111.93 5,055.73 2,642.64 2,381.53 6,033,741.15 472,315.91 1.25 2,202.13 MWD+IFR2+MS+sag(3) 6,708.03 50.51 38.55 5,172.34 5,116.14 2,700.42 2,427.60 6,033,798.75 472,362.21 0.48 2,251.30 MWD+IFR2+MS+sag(3) 6,803.17 50.84 38.39 5,232.63 5,176.43 2,758.04 2,473.39 6,033,856.18 472,408.23 0.37 2,300.35 MWD+IFR2+MS+sag(3) 6,898.93 51.00 39.16 5,293.00 5,236.80 2,816.00 2,519.94 6,033,913.93 472,455.01 0.65 2,349.60 MWD+IFR2+MS+sag(3) 6,994.31 51.17 38.97 5,352.91 5,296.71 2,873.62 2,566.71 6,033,971.36 472,502.01 0.24 2,398.49 MWD+IFR2+MS+sag(3) 7,089.04 51.17 37.23 5,412.31 5,356.11 2,931.69 2,612.24 6,034,029.24 472,547.77 1.43 2,448.03 MWD+IFR2+MS+sag(3) 7,186.05 50.62 36.84 5,473.50 5,417.30 2,991.78 2,657.58 6,034,089.14 472,593.35 0.65 2,499.59 MWD+IFR2+MS+sag(3) 7,239.97 51.01 37.04 5,507.57 5,451.37 3,025.18 2,682.70 6,034,122.44 472,618.60 0.78 2,528.27 MWD+IFR2+MS+sag(4) 7,253.31 51.20 37.06 5,515.94 5,459.74 3,033.47 2,688.96 6,034,130.70 472,624.89 1.43 2,535.38 MWD+IFR2+MS+sag(4) 7,347.99 51.20 38.68 5,575.27 5,519.07 3,091.71 2,734.25 6,034,188.75 472,670.41 1.33 2,585.14 MWD+IFR2+MS+sag(4) 7,443.25 50.19 38.10 5,635.62 5,579.42 3,149.48 2,780.03 6,034,246.33 472,716.42 1.16 2,634.34 MWD+IFR2+MS+sag(4) 7,538.01 49.51 37.02 5,696.72 5,640.52 3,206.90 2,824.18 6,034,303.56 472,760.80 1.13 2,683.46 MWD+IFR2+MS+sag(4) 7,633.13 50.49 34.29 5,757.86 5,701.66 3,266.10 2,866.64 6,034,362.59 472,803.49 2.43 2,734.64 MWD+IFR2+MS+sag(4) 7,728.76 51.43 30.23 5,818.11 5,761.91 3,328.90 2,906.25 6,034,425.22 472,843.35 3.44 2,789.84 MWD+IFR2+MS+sag(4) 7,822.71 52.22 26.12 5,876.20 5,820.00 3,393.98 2,941.10 6,034,490.15 472,878.46 3.54 2,848.10 MWD+IFR2+MS+sag(4) 7,919.13 51.97 19.97 5,935.47 5,879.27 3,463.93 2,970.86 6,034,559.97 472,908.50 5.04 2,912.01 MWD+IFR2+MS+sag(4) 8,014.10 52.00 15.77 5,993.97 5,937.77 3,535.11 2,993.81 6,034,631.06 472,931.74 3.48 2,978.29 MWD+IFR2+MS+sag(4) 8,109.08 54.08 9.02 6,051.12 5,994.92 3,609.17 3,010.03 6,034,705.04 472,948.25 6.08 3,048.54 MWD+IFR2+MS+sag(4) 8,204.65 55.50 4.49 6,106.24 6,050.04 3,686.68 3,019.18 6,034,782.51 472,957.72 4.15 3,123.39 MWD+IFR2+MS+sag(4) 12/14/2012 12:52:27PM Page 4 COMPASS 2003.16 Build 42 r i Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB1 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +N/.S +E/.W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) 0100) (ft) Survey Tool Name 8,299.52 56.76 357.64 6,159.15 6,102.95 3,765.36 3,020.61 6,034,861.17 472,959.46 6.14 3,200.70 MWD+IFR2+MS+sag(4) 8,395.04 59.96 354.49 6,209.26 6,153.06 3,846.47 3,014.99 6,034,942.29 472,954.17 4.37 3,281.58 MWD+IFR2+MS+sag(4) 8,490.01 63.54 352.73 6,254.21 6,198.01 3,929.58 3,005.66 6,035,025.43 472,945.18 4.11 3,365.08 MWD+IFR2+MS+sag(4) 8,585.18 68.13 351.60 6,293.16 6,236.96 4,015.58 2,993.81 6,035,111.47 472,933.68 4.94 3,451.84 MWD+IFR2+MS+sag(4) 8,680.70 72.73 351.59 6,325.15 6,268.95 4,104.59 2,980.66 6,035,200.52 472,920.89 4.82 3,541.80 MWD+IFR2+MS+sag(4) 8,775.68 77.59 351.73 6,349.47 6,293.27 4,195.40 2,967.35 6,035,291.38 472,907.95 5.12 3,633.55 MWD+IFR2+MS+sag(4) 8,871.40 81.78 350.38 6,366.60 6,310.40 4,288.40 2,952.70 6,035,384.43 472,893.68 4.59 3,727.69 MWD+IFR2+MS+sag(4) 8,966.20 85.58 350.25 6,377.04 6,320.84 4,381.27 2,936.85 6,035,477.35 472,878.21 4.01 3,821.90 MWD+IFR2+MS+sag(4) 9,017.12 87.31 349.59 6,380.19 6,323.99 4,431.30 2,927.96 6,035,527.41 472,869.52 3.64 3,872.72 MWD+IFR2+MS+sag(4) 9,060.56 87.43 349.78 6,382.19 6,325.99 4,474.00 2,920.19 6,035,570.13 472,861.92 0.52 3,916.11 MWD+IFR2+MS+sag(4) 9,112.53 87.43 349.67 6,384.52 6,328.32 4,525.08 2,910.93 6,035,621.25 472,852.87 0.21 3,968.03 MWD+IFR2+MS+sag(4) 9,156.56 87.01 349.26 6,386.65 6,330.45 4,568.32 2,902.89 6,035,664.52 472,845.00 1.33 4,012.00 MWD+IFR2+MS+sag(4) 9,252.44 87.06 344.00 6,391.62 6,335.42 4,661.44 2,880.75 6,035,757.72 472,823.25 5.48 4,107.53 MWD+IFR2+MS+sag(4) 9,346.04 85.39 339.79 6,397.78 6,341.58 4,750.19 2,851.74 6,035,846.58 472,794.60 4.83 4,199.90 MWD+IFR2+MS+sag(4) 9,442.51 84.96 334.69 6,405.90 6,349.70 4,838.81 2,814.56 6,035,935.33 472,757.78 5.29 4,293.52 MWD+IFR2+MS+sag(4) 9,537.10 85.58 330.13 6,413.70 6,357.50 4,922.33 2,770.91 6,036,019.02 472,714.48 4.85 4,383.22 MWD+IFR2+MS+sag(4) 9,632.57 85.64 324.03 6,421.02 6,364.82 5,002.20 2,719.21 6,036,099.09 472,663.10 6.37 4,470.68 MWD+IFR2+MS+sag(4) 9,663.68 85.70 322.57 6,423.37 6,367.17 5,027.07 2,700.67 6,036,124.03 472,644.66 4.68 4,498.33 MWD+IFR2+MS+sag(4) 9,697.60 85.58 320.58 6,425.95 6,369.75 5,053.56 2,679.65 6,036,150.61 472,623.75 5.86 4,527.99 MWD+IFR2+MS+sag(4) 9,776.75 87.78 318.00 6,430.53 6,374.33 5,113.45 2,628.12 6,036,210.70 472,572.47 4.28 4,595.73 MWD+IFR2+MS+sag(5) 9,862.68 88.58 317.11 6,433.26 6,377.06 5,176.83 2,570.16 6,036,274.30 472,514.77 1.39 4,667.99 MWD+IFR2+MS+sag(5) 9,959.37 88.46 317.67 6,435.76 6,379.56 5,247.97 2,504.72 6,036,345.70 472,449.63 0.59 4,749.16 MWD+IFR2+MS+sag(5) 10,055.30 86.60 317.60 6,439.89 6,383.69 5,318.78 2,440.14 6,036,416.76 472,385.34 1.94 4,829.87 MWD+IFR2+MS+sag(5) 10,152.06 88.21 316.05 6,444.27 6,388.07 5,389.26 2,374.00 6,036,487.51 472,319.50 2.31 4,910.52 MWD+IFR2+MS+sag(5) 10,248.25 90.74 313.95 6,445.15 6,388.95 5,457.27 2,306.00 6,036,555.78 472,251.78 3.42 4,989.04 MWD+IFR2+MS+sag(5) 10,344.58 90.99 313.70 6,443.70 6,387.50 5,523.96 2,236.51 6,036,622.75 472,182.56 0.37 5,066.52 MWD+IFR2+MS+sag(5) 10,441.15 91.67 313.39 6,441.46 6,385.26 5,590.47 2,166.53 6,036,689.54 472,112.86 0.77 5,143.90 MWD+IFR2+MS+sag(5) 10,536.95 92.22 312.87 6,438.21 6,382.01 5,655.93 2,096.66 6,036,755.27 472,043.26 0.79 5,220.22 MWD+IFR2+MS+sag(5) 10,633.35 91.85 314.43 6,434.78 6,378.58 5,722.43 2,026.95 6,036,822.04 471,973.83 1.66 5,297.54 MWD+IFR2+MS+sag(5) 10,729.68 90.56 314.67 6,432.76 6,376.56 5,789.99 1,958.32 6,036,889.87 471,905.48 1.36 5,375.73 MWD+IFR2+MS+sag(5) 10,825.68 91.30 314.76 6,431.20 6,375.00 5,857.52 1,890.11 6,036,957.68 471,837.55 0.78 5,453.82 MWD+IFR2+MS+sag(5) 10,922.06 90.37 313.66 6,429.80 6,373.60 5,924.72 1,821.03 6,037,025.15 471,768.76 1.49 5,531.73 MWD+IFR2+MS+sag(5) 11,018.42 91.17 310.85 6,428.50 6,372.30 5,989.50 1,749.73 6,037,090.21 471,697.72 3.03 5,607.63 MWD+IFR2+MS+sag(5) 11,115.04 92.47 310.17 6,425.43 6,369.23 6,052.23 1,676.31 6,037,153.23 471,624.56 1.52 5,681.87 MWD+IFR2+MS+sag(5) 11,210.97 92.59 309.82 6,421.20 6,365.00 6,113.83 1,602.89 6,037,215.12 471,551.40 0.39 5,754.98 MWD+IFR2+MS+sag(5) 11,307.49 92.29 311.57 6,417.09 6,360.89 6,176.70 1,529.78 6,037,278.28 471,478.55 1.84 5,829.31 MWD+IFR2+MS+sag(5) 11,403.74 91.54 313.13 6,413.87 6,357.67 6,241.50 1,458.69 6,037,343.36 471,407.73 1.80 5,905.19 MWD+IFR2+MS+sag(5) 11,500.65 91.61 314.11 6,411.21 6,355.01 6,308.33 1,388.56 6,037,410.47 471,337.88 1.01 5,982.91 MWD+IFR2+MS+sag(5) 11,595.80 92.16 315.42 6,408.08 6,351.88 6,375.30 1,321.04 6,037,477.70 471,270.64 1.49 6,060.33 MWD+IFR2+MS+sag(5) 11,692.96 89.82 317.05 6,406.40 6,350.20 6,445.45 1,253.85 6,037,548.11 471,203.74 2.93 6,140.82 MWD+IFR2+MS+sag(5) 12/14/2012 12:52:27PM Page 5 COMPASS 2003.16 Build 42 • • Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB1 Database: EDM Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,787.10 89.75 316.37 6,406.75 6,350.55 6,513.97 1,189.30 6,037,616.89 471,139.47 0.73 6,219.27 MWD+IFR2+MS+sag(5) 11,885.85 90.06 316.41 6,406.92 6,350.72 6,585.47 1,121.19 6,037,688.66 471,071.66 0.32 6,301.25 MWD+IFR2+MS+sag(5) 11,982.48 93.52 314.68 6,403.90 6,347.70 6,654.40 1,053.56 6,037,757.85 471,004.32 4.00 6,380.62 MWD+IFR2+MS+sag(5) 12,078.69 93.09 316.94 6,398.35 6,342.15 6,723.27 986.61 6,037,826.98 470,937.66 2.39 6,459.81 MWD+IFR2+MS+sag(5) 12,175.48 92.28 316.73 6,393.82 6,337.62 6,793.79 920.47 6,037,897.76 470,871.81 0.86 6,540.49 MWD+IFR2+MS+sag(5) 12,270.85 92.59 315.57 6,389.76 6,333.56 6,862.50 854.46 6,037,966.73 470,806.08 1.26 6,619.37 MWD+IFR2+MS+sag(5) 12,367.53 92.59 314.85 6,385.40 6,329.20 6,931.04 786.42 6,038,035.54 470,738.33 0.74 6,698.43 MWD+IFR2+MS+sag(5) 12,464.00 92.59 314.85 6,381.04 6,324.84 6,999.01 718.10 6,038,103.78 470,670.29 0.00 6,776.97 PROJECTED to TD 12/14/2012 12:52:27PM Page 6 COMPASS 2003.16 Build 42 • Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-29 PN5 PB2 50-703-20661-00-71 Sperry Drilling Services Definitive Survey Report 14 December, 2012 HAL-LIP - RT 11, t .M11 Sperry Drilling Services 0 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB2 Database: EDM Alaska Project Oooguruk Development Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well ODSN-29 Well Position +N/-S 0.00 ft Northing: 6,031,108.44 ft Latitude: 70°29'45.820N +E/-W 0.00 ft Easting: 469,923.95 ft Longitude: 150° 14'45.357 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSN-29 PN5 PB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF2010 10/10/2012 20.57 80.97 57,668 Design ODSN-29 PN5 PB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,885.85 Vertical Section: Depth From(ND) +N/-S +El-W Direction (ft) (ft) (ft) (bearing) 42.70 0.00 0.00 350.27 Survey Program Date 12/14/2012 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 100.00 729.00 ODSN-29 GYRO(ODSN-29 PN5 PB1) SRG-SS Surface readout gyro single shot 11/07/2012 775.48 4,138.70 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 4,139.70 7,238.00 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 7,238.00 9,759.10 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 9,759.10 11,885.85 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 11,930.00 14,292.19 ODSN-29 PN5 MWD(ODSN-29 PN5 PB MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/20/2012 Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°l100') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,108.44 469,923.95 0.00 0.00 UNDEFINED 100.00 0.12 142.74 100.00 43.80 -0.05 0.04 6,031,108.39 469,923.99 0.21 -0.05 SRG-SS(1) 172.00 0.15 342.94 172.00 115.80 -0.02 0.05 6,031,108.42 469,924.00 0.37 -0.03 SRG-SS(1) 261.00 1.50 148.91 260.99 204.79 -0.90 0.62 6,031,107.53 469,924.57 1.85 -1.00 SRG-SS(1) 354.00 4.95 146.57 353.83 297.63 -5.30 3.46 6,031,103.13 469,927.39 3.71 -5.80 SRG-SS(1) 448.00 9.11 143.99 447.10 390.90 -14.70 10.07 6,031,093.70 469,933.96 4.44 -16.20 SRG-SS(1) 541.00 11.62 142.76 538.58 482.38 -28.12 20.07 6,031,080.24 469,943.91 2.71 -31.11 SRG-SS(1) 636.00 10.55 138.46 631.81 575.61 -42.25 31.63 6,031,066.07 469,955.41 1.42 -46.98 SRG-SS(1) 729.00 10.64 121.05 723.24 667.04 -53.05 44.63 6,031,055.22 469,968.36 3.43 -59.83 SRG-SS(1) 775.48 10.70 114.93 768.92 712.72 -57.08 52.22 6,031,051.15 469,975.94 2.44 -65.09 MWD+IFR2+MS+sag(2) 12/14/2012 1:08:21PM Page 2 COMPASS 2003.16 Build 42 • 0 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development ND Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB2 Database: EDM Alaska Survey Map Map Vertical MD Inc Az! TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 871.35 10.29 106.10 863.19 806.99 -63.21 68.52 6,031,044.96 469,992.21 1.73 -73.88 MWD+IFR2+MS+sag(2) 967.21 8.57 109.64 957.76 901.56 -67.98 83.48 6,031,040.13 470,007.14 1.89 -81.11 MWD+IFR2+MS+sag(2) 1,057.98 8.88 89.26 1,047.50 991.30 -70.17 96.85 6,031,037.89 470,020.51 3.40 -85.53 MWD+IFR2+MS+sag(2) 1,156.87 8.63 82.17 1,145.24 1,089.04 -69.06 111.84 6,031,038.94 470,035.50 1.12 -86.96 MWD+IFR2+MS+sag(2) 1,252.66 9.64 75.68 1,239.81 1,183.61 -66.09 126.73 6,031,041.84 470,050.40 1.50 -86.56 MWD+IFR2+MS+sag(2) 1,344.56 11.97 66.08 1,330.09 1,273.89 -60.33 142.90 6,031,047.54 470,066.59 3.20 -83.61 MWD+IFR2+MS+sag(2) 1,443.83 14.03 61.93 1,426.81 1,370.61 -50.49 162.93 6,031,057.30 470,086.66 2.28 -77.30 MWD+IFR2+MS+sag(2) 1,538.72 16.10 60.74 1,518.43 1,462.23 -38.64 184.56 6,031,069.05 470,108.33 2.21 -69.28 MWD+IFR2+MS+sag(2) 1,630.58 18.58 58.48 1,606.11 1,549.91 -24.76 208.15 6,031,082.84 470,131.98 2.80 -59.59 MWD+IFR2+MS+sag(2) 1,726.05 20.24 53.90 1,696.16 1,639.96 -7.08 234.46 6,031,100.41 470,158.36 2.36 -46.60 MWD+IFR2+MS+sag(2) 1,823.57 23.59 50.42 1,786.62 1,730.42 15.30 263.14 6,031,122.67 470,187.13 3.68 -29.39 MWD+IFR2+MS+sag(2) 1,919.50 24.52 50.45 1,874.22 1,818.02 40.20 293.29 6,031,147.45 470,217.37 0.97 -9.94 MWD+IFR2+MS+sag(2) 2,012.11 26.18 49.20 1,957.91 1,901.71 65.79 323.57 6,031,172.92 470,247.75 1.88 10.16 MWD+IFR2+MS+sag(2) 2,108.98 29.74 46.35 2,043.46 1,987.26 96.35 357.14 6,031,203.34 470,281.45 3.92 34.61 MWD+IFR2+MS+sag(2) 2,203.85 30.55 43.54 2,125.51 2,069.31 130.07 390.78 6,031,236.92 470,315.22 1.71 62.16 MWD+IFR2+MS+sag(2) 2,300.31 30.90 43.41 2,208.43 2,152.23 165.84 424.69 6,031,272.54 470,349.27 0.37 91.68 MWD+IFR2+MS+sag(2) 2,394.61 30.17 41.08 2,289.65 2,233.45 201.29 456.90 6,031,307.86 470,381.62 1.47 121.18 MWD+IFR2+MS+sag(2) 2,485.66 32.87 41.15 2,367.26 2,311.06 237.15 488.20 6,031,343.59 470,413.06 2.97 151.23 MWD+IFR2+MS+sag(2) 2,582.97 34.96 40.94 2,448.01 2,391.81 278.10 523.85 6,031,384.39 470,448.87 2.15 185.56 MWD+IFR2+MS+sag(2) 2,676.49 35.93 37.95 2,524.20 2,468.00 319.98 558.29 6,031,426.12 470,483.47 2.12 221.02 MWD+IFR2+MS+sag(2) 2,772.74 37.48 37.32 2,601.37 2,545.17 365.54 593.41 6,031,471.54 470,518.77 1.66 259.99 MWD+IFR2+MS+sag(2) 2,866.80 38.36 38.20 2,675.57 2,619.37 411.23 628.81 6,031,517.08 470,554.35 1.10 299.05 MWD+IFR2+MS+sag(2) 2,962.28 39.48 38.14 2,749.85 2,693.65 458.39 665.88 6,031,564.09 470,591.61 1.17 339.26 MWD+IFR2+MS+sag(2) 3,056.78 42.54 37.76 2,821.15 2,764.95 507.29 704.00 6,031,612.82 470,629.93 3.25 381.01 MWD+IFR2+MS+sag(2) 3,152.51 44.40 38.36 2,890.62 2,834.42 559.14 744.61 6,031,664.50 470,670.74 1.99 425.25 MWD+IFR2+MS+sag(2) 3,244.56 45.78 38.50 2,955.61 2,899.41 610.20 785.13 6,031,715.40 470,711.46 1.50 468.73 MWD+IFR2+MS+sag(2) 3,339.91 44.52 38.40 3,022.85 2,966.65 663.14 827.16 6,031,768.16 470,753.70 1.32 513.81 MWD+IFR2+MS+sag(2) 3,437.78 44.79 38.83 3,092.47 3,036.27 716.89 870.09 6,031,821.73 470,796.84 0.41 559.52 MWD+IFR2+MS+sag(2) 3,531.82 46.35 36.87 3,158.31 3,102.11 769.92 911.28 6,031,874.59 470,838.24 2.23 604.83 MWD+IFR2+MS+sag(2) 3,628.46 46.31 36.78 3,225.04 3,168.84 825.87 953.18 6,031,930.36 470,880.36 0.08 652.90 MWD+IFR2+MS+sag(2) 3,721.08 49.15 38.54 3,287.33 3,231.13 880.10 995.06 6,031,984.42 470,922.46 3.37 699.27 MWD+IFR2+MS+sag(2) 3,815.98 52.06 38.95 3,347.55 3,291.35 937.29 1,040.96 6,032,041.42 470,968.59 3.08 747.88 MWD+IFR2+MS+sag(2) 3,913.69 53.35 38.96 3,406.76 3,350.56 997.74 1,089.83 6,032,101.66 471,017.70 1.32 799.20 MWD+IFR2+MS+sag(2) 4,007.06 52.27 39.23 3,463.20 3,407.00 1,055.47 1,136.73 6,032,159.19 471,064.83 1.18 848.17 MWD+IFR2+MS+sag(2) 4,093.51 53.19 39.45 3,515.55 3,459.35 1,108.67 1,180.34 6,032,212.22 471,108.65 1.08 893.24 MWD+IFR2+MS+sag(2) 4,193.35 50.77 38.33 3,577.04 3,520.84 1,169.88 1,229.73 6,032,273.22 471,158.28 2.58 945.22 MWD+IFR2+MS+sag(3) 4,235.17 50.22 38.20 3,603.64 3,547.44 1,195.21 1,249.71 6,032,298.47 471,178.36 1.34 966.81 MWD+IFR2+MS+sag(3) 4,329.62 50.67 36.91 3,663.79 3,607.59 1,252.94 1,294.10 6,032,356.01 471,222.97 1.16 1,016.21 MWD+IFR2+MS+sag(3) 4,424.83 50.66 37.77 3,724.14 3,667.94 1,311.49 1,338.76 6,032,414.37 471,267.87 0.70 1,066.37 MWD+IFR2+MS+sag(3) 4,520.03 51.23 38.51 3,784.12 3,727.92 1,369.63 1,384.42 6,032,472.32 471,313.76 0.85 1,115.96 MWD+IFR2+MS+sag(3) 12/14/2012 1:08:21PM Page 3 COMPASS 2003.16 Build 42 • S Pioneer Natural Resources Definitive Survey Report SII Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB2 Database: EDM Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°/100) (ft) Survey Tool Name 4,614.29 51.72 40.80 3,842.84 3,786.64 1,426.40 1,431.48 6,032,528.89 471,361.04 1.97 1,163.95 MWD+IFR2+MS+sag(3) 4,710.58 51.23 38.43 3,902.82 3,846.62 1,484.42 1,479.51 6,032,586.71 471,409.30 1.99 1,213.02 MWD+IFR2+MS+sag(3) 4,805.30 49.64 37.91 3,963.15 3,906.95 1,541.82 1,524.63 6,032,643.92 471,454.66 1.73 1,261.97 MWD+IFR2+MS+sag(3) 4,899.73 49.48 38.02 4,024.40 3,968.20 1,598.48 1,568.85 6,032,700.40 471,499.09 0.19 1,310.34 MWD+IFR2+MS+sag(3) 4,992.80 50.29 38.34 4,084.37 4,028.17 1,654.43 1,612.84 6,032,756.16 471,543.31 0.91 1,358.05 MWD+IFR2+MS+sag(3) 5,090.15 50.44 39.45 4,146.47 4,090.27 1,712.78 1,659.92 6,032,814.31 471,590.61 0.89 1,407.60 MWD+IFR2+MS+sag(3) 5,185.51 51.01 37.43 4,206.84 4,150.64 1,770.59 1,705.80 6,032,871.94 471,636.73 1.75 1,456.83 MWD+IFR2+MS+sag(3) 5,280.47 50.10 37.49 4,267.17 4,210.97 1,828.80 1,750.40 6,032,929.96 471,681.56 0.96 1,506.67 MWD+IFR2+MS+sag(3) 5,375.64 49.67 38.02 4,328.49 4,272.29 1,886.35 1,794.96 6,032,987.32 471,726.35 0.62 1,555.85 MWD+IFR2+MS+sag(3) 5,471.03 51.32 37.62 4,389.17 4,332.97 1,944.48 1,840.09 6,033,045.27 471,771.70 1.76 1,605.53 MWD+IFR2+MS+sag(3) 5,565.75 51.40 38.05 4,448.32 4,392.12 2,002.92 1,885.47 6,033,103.51 471,817.32 0.36 1,655.45 MWD+IFR2+MS+sag(3) 5,661.24 51.07 37.96 4,508.10 4,451.90 2,061.58 1,931.31 6,033,161.98 471,863.39 0.35 1,705.52 MWD+IFR2+MS+sag(3) 5,755.74 50.60 37.62 4,567.79 4,511.59 2,119.48 1,976.21 6,033,219.70 471,908.52 0.57 1,755.00 MWD+IFR2+MS+sag(3) 5,852.58 50.84 37.86 4,629.10 4,572.90 2,178.76 2,022.09 6,033,278.78 471,954.64 0.31 1,805.68 MWD+IFR2+MS+sag(3) 5,948.17 51.25 37.06 4,689.20 4,633.00 2,237.77 2,067.30 6,033,337.60 472,000.08 0.78 1,856.19 MWD+IFR2+MS+sag(3) 6,041.98 50.15 37.38 4,748.61 4,692.41 2,295.57 2,111.21 6,033,395.22 472,044.22 1.20 1,905.75 MWD+IFR2+MS+sag(3) 6,136.90 49.57 37.71 4,809.80 4,753.60 2,353.11 2,155.43 6,033,452.57 472,088.66 0.67 1,954.98 MWD+IFR2+MS+sag(3) 6,233.24 49.87 39.47 4,872.09 4,815.89 2,410.55 2,201.27 6,033,509.82 472,134.73 1.43 2,003.85 MWD+IFR2+MS+sag(3) 6,327.80 50.83 38.16 4,932.43 4,876.23 2,467.28 2,246.90 6,033,566.36 472,180.59 1.47 2,052.05 MWD+IFR2+MS+sag(3) 6,422.21 50.76 37.12 4,992.11 4,935.91 2,525.21 2,291.58 6,033,624.10 472,225.49 0.86 2,101.60 MWD+IFR2+MS+sag(3) 6,517.54 51.12 37.06 5,052.18 4,995.98 2,584.26 2,336.22 6,033,682.96 472,270.37 0.38 2,152.25 MWD+IFR2+MS+sag(3) 6,612.58 50.97 38.58 5,111.93 5,055.73 2,642.64 2,381.53 6,033,741.15 472,315.91 1.25 2,202.13 MWD+IFR2+MS+sag(3) 6,708.03 50.51 38.55 5,172.34 5,116.14 2,700.42 2,427.60 6,033,798.75 472,362.21 0.48 2,251.30 MWD+IFR2+MS+sag(3) 6,803.17 50.84 38.39 5,232.63 5,176.43 2,758.04 2,473.39 6,033,856.18 472,408.23 0.37 2,300.35 MWD+IFR2+MS+sag(3) 6,898.93 51.00 39.16 5,293.00 5,236.80 2,816.00 2,519.94 6,033,913.93 472,455.01 0.65 2,349.60 MWD+IFR2+MS+sag(3) 6,994.31 51.17 38.97 5,352.91 5,296.71 2,873.62 2,566.71 6,033,971.36 472,502.01 0.24 2,398.49 MWD+IFR2+MS+sag(3) 7,089.04 51.17 37.23 5,412.31 5,356.11 2,931.69 2,612.24 6,034,029.24 472,547.77 1.43 2,448.03 MWD+IFR2+MS+sag(3) 7,186.05 50.62 36.84 5,473.50 5,417.30 2,991.78 2,657.58 6,034,089.14 472,593.35 0.65 2,499.59 MWD+IFR2+MS+sag(3) 7,239.97 51.01 37.04 5,507.57 5,451.37 3,025.18 2,682.70 6,034,122.44 472,618.60 0.78 2,528.27 MWD+IFR2+MS+sag(4) 7,253.31 51.20 37.06 5,515.94 5,459.74 3,033.47 2,688.96 6,034,130.70 472,624.89 1.43 2,535.38 MWD+IFR2+MS+sag(4) 7,347.99 51.20 38.68 5,575.27 5,519.07 3,091.71 2,734.25 6,034,188.75 472,670.41 1.33 2,585.14 MWD+IFR2+MS+sag(4) 7,443.25 50.19 38.10 5,635.62 5,579.42 3,149.48 2,780.03 6,034,246.33 472,716.42 1.16 2,634.34 MWD+IFR2+MS+sag(4) 7,538.01 49.51 37.02 5,696.72 5,640.52 3,206.90 2,824.18 6,034,303.56 472,760.80 1.13 2,683.46 MWD+IFR2+MS+sag(4) 7,633.13 50.49 34.29 5,757.86 5,701.66 3,266.10 2,866.64 6,034,362.59 472,803.49 2.43 2,734.64 MWD+IFR2+MS+sag(4) 7,728.76 51.43 30.23 5,818.11 5,761.91 3,328.90 2,906.25 6,034,425.22 472,843.35 3.44 2,789.84 MWD+IFR2+MS+sag(4) 7,822.71 52.22 26.12 5,876.20 5,820.00 3,393.98 2,941.10 6,034,490.15 472,878.46 3.54 2,848.10 MWD+IFR2+MS+sag(4) 7,919.13 51.97 19.97 5,935.47 5,879.27 3,463.93 2,970.86 6,034,559.97 472,908.50 5.04 2,912.01 MWD+IFR2+MS+sag(4) 8,014.10 52.00 15.77 5,993.97 5,937.77 3,535.11 2,993.81 6,034,631.06 472,931.74 3.48 2,978.29 MWD+IFR2+MS+sag(4) 8,109.08 54.08 9.02 6,051.12 5,994.92 3,609.17 3,010.03 6,034,705.04 472,948.25 6.08 3,048.54 MWD+IFR2+MS+sag(4) 8,204.65 55.50 4.49 6,106.24 6,050.04 3,686.68 3,019.18 6,034,782.51 472,957.72 4.15 3,123.39 MWD+IFR2+MS+sag(4) 12/14/2012 1:08:21PM Page 4 COMPASS 2003.16 Build 42 • S Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB2 Database: EDM Alaska Survey Map Map Vertical MD Inc Az! ND TVDSS +NI-S +Et-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°!100') (ft) Survey Tool Name 8,299.52 56.76 357.64 6,159.15 6,102.95 3,765.36 3,020.61 6,034,861.17 472,959.46 6.14 3,200.70 MWD+IFR2+MS+sag(4) 8,395.04 59.96 354.49 6,209.26 6,153.06 3,846.47 3,014.99 6,034,942.29 472,954.17 4.37 3,281.58 MWD+IFR2+MS+sag(4) 8,490.01 63.54 352.73 6,254.21 6,198.01 3,929.58 3,005.66 6,035,025.43 472,945.18 4.11 3,365.08 MWD+IFR2+MS+sag(4) 8,585.18 68.13 351.60 6,293.16 6,236.96 4,015.58 2,993.81 6,035,111.47 472,933.68 4.94 3,451.84 MWD+IFR2+MS+sag(4) 8,680.70 72.73 351.59 6,325.15 6,268.95 4,104.59 2,980.66 6,035,200.52 472,920.89 4.82 3,541.80 MWD+IFR2+MS+sag(4) 8,775.68 77.59 351.73 6,349.47 6,293.27 4,195.40 2,967.35 6,035,291.38 472,907.95 5.12 3,633.55 MWD+IFR2+MS+sag(4) 8,871.40 81.78 350.38 6,366.60 6,310.40 4,288.40 2,952.70 6,035,384.43 472,893.68 4.59 3,727.69 MWD+IFR2+MS+sag(4) 8,966.20 85.58 350.25 6,377.04 6,320.84 4,381.27 2,936.85 6,035,477.35 472,878.21 4.01 3,821.90 MWD+IFR2+MS+sag(4) 9,017.12 87.31 349.59 6,380.19 6,323.99 4,431.30 2,927.96 6,035,527.41 472,869.52 3.64 3,872.72 MWD+IFR2+MS+sag(4) 9,060.56 87.43 349.78 6,382.19 6,325.99 4,474.00 2,920.19 6,035,570.13 472,861.92 0.52 3,916.11 MWD+IFR2+MS+sag(4) 9,112.53 87.43 349.67 6,384.52 6,328.32 4,525.08 2,910.93 6,035,621.25 472,852.87 0.21 3,968.03 MWD+IFR2+MS+sag(4) 9,156.56 87.01 349.26 6,386.65 6,330.45 4,568.32 2,902.89 6,035,664.52 472,845.00 1.33 4,012.00 MWD+IFR2+MS+sag(4) 9,252.44 87.06 344.00 6,391.62 6,335.42 4,661.44 2,880.75 6,035,757.72 472,823.25 5.48 4,107.53 MWD+IFR2+MS+sag(4) 9,346.04 85.39 339.79 6,397.78 6,341.58 4,750.19 2,851.74 6,035,846.58 472,794.60 4.83 4,199.90 MWD+IFR2+MS+sag(4) 9,442.51 84.96 334.69 6,405.90 6,349.70 4,838.81 2,814.56 6,035,935.33 472,757.78 5.29 4,293.52 MWD+IFR2+MS+sag(4) 9,537.10 85.58 330.13 6,413.70 6,357.50 4,922.33 2,770.91 6,036,019.02 472,714.48 4.85 4,383.22 MWD+IFR2+MS+sag(4) 9,632.57 85.64 324.03 6,421.02 6,364.82 5,002.20 2,719.21 6,036,099.09 472,663.10 6.37 4,470.68 MWD+IFR2+MS+sag(4) 9,663.68 85.70 322.57 6,423.37 6,367.17 5,027.07 2,700.67 6,036,124.03 472,644.66 4.68 4,498.33 MWD+IFR2+MS+sag(4) 9,697.60 85.58 320.58 6,425.95 6,369.75 5,053.56 2,679.65 6,036,150.61 472,623.75 5.86 4,527.99 MWD+IFR2+MS+sag(4) 9,776.75 87.78 318.00 6,430.53 6,374.33 5,113.45 2,628.12 6,036,210.70 472,572.47 4.28 4,595.73 MWD+IFR2+MS+sag(5) 9,862.68 88.58 317.11 6,433.26 6,377.06 5,176.83 2,570.16 6,036,274.30 472,514.77 1.39 4,667.99 MWD+IFR2+MS+sag(5) 9,959.37 88.46 317.67 6,435.76 6,379.56 5,247.97 2,504.72 6,036,345.70 472,449.63 0.59 4,749.16 MWD+IFR2+MS+sag(5) 10,055.30 86.60 317.60 6,439.89 6,383.69 5,318.78 2,440.14 6,036,416.76 472,385.34 1.94 4,829.87 MWD+IFR2+MS+sag(5) 10,152.06 88.21 316.05 6,444.27 6,388.07 5,389.26 2,374.00 6,036,487.51 472,319.50 2.31 4,910.52 MWD+IFR2+MS+sag(5) 10,248.25 90.74 313.95 6,445.15 6,388.95 5,457.27 2,306.00 6,036,555.78 472,251.78 3.42 4,989.04 MWD+IFR2+MS+sag(5) 10,344.58 90.99 313.70 6,443.70 6,387.50 5,523.96 2,236.51 6,036,622.75 472,182.56 0.37 5,066.52 MWD+IFR2+MS+sag(5) 10,441.15 91.67 313.39 6,441.46 6,385.26 5,590.47 2,166.53 6,036,689.54 472,112.86 0.77 5,143.90 MWD+IFR2+MS+sag(5) 10,536.95 92.22 312.87 6,438.21 6,382.01 5,655.93 2,096.66 6,036,755.27 472,043.26 0.79 5,220.22 MWD+IFR2+MS+sag(5) 10,633.35 91.85 314.43 6,434.78 6,378.58 5,722.43 2,026.95 6,036,822.04 471,973.83 1.66 5,297.54 MWD+IFR2+MS+sag(5) 10,729.68 90.56 314.67 6,432.76 6,376.56 5,789.99 1,958.32 6,036,889.87 471,905.48 1.36 5,375.73 MWD+IFR2+MS+sag(5) 10,825.68 91.30 314.76 6,431.20 6,375.00 5,857.52 1,890.11 6,036,957.68 471,837.55 0.78 5,453.82 MWD+IFR2+MS+sag(5) 10,922.06 90.37 313.66 6,429.80 6,373.60 5,924.72 1,821.03 6,037,025.15 471,768.76 1.49 5,531.73 MWD+IFR2+MS+sag(5) 11,018.42 91.17 310.85 6,428.50 6,372.30 5,989.50 1,749.73 6,037,090.21 471,697.72 3.03 5,607.63 MWD+IFR2+MS+sag(5) 11,115.04 92.47 310.17 6,425.43 6,369.23 6,052.23 1,676.31 6,037,153.23 471,624.56 1.52 5,681.87 MWD+IFR2+MS+sag(5) 11,210.97 92.59 309.82 6,421.20 6,365.00 6,113.83 1,602.89 6,037,215.12 471,551.40 0.39 5,754.98 MWD+IFR2+MS+sag(5) 11,307.49 92.29 311.57 6,417.09 6,360.89 6,176.70 1,529.78 6,037,278.28 471,478.55 1.84 5,829.31 MWD+IFR2+MS+sag(5) 11,403.74 91.54 313.13 6,413.87 6,357.67 6,241.50 1,458.69 6,037,343.36 471,407.73 1.80 5,905.19 MWD+IFR2+MS+sag(5) 11,500.65 91.61 314.11 6,411.21 6,355.01 6,308.33 1,388.56 6,037,410.47 471,337.88 1.01 5,982.91 MWD+IFR2+MS+sag(5) 11,595.80 92.16 315.42 6,408.08 6,351.88 6,375.30 1,321.04 6,037,477.70 471,270.64 1.49 6,060.33 MWD+IFR2+MS+sag(5) 11,692.96 89.82 317.05 6,406.40 6,350.20 6,445.45 1,253.85 6,037,548.11 471,203.74 2.93 6,140.82 MWD+IFR2+MS+sag(5) 12/14/2012 1:08:21PM Page 5 COMPASS 2003.16 Build 42 • • Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-000guruk Local Co-ordinate Reference: Well ODSN-29 Project: 000guruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: 000guruk Drill Site MD Reference: 42.7'+13.5 @ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB2 Database: EDM Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) 0100) (ft) Survey Tool Name 11,787.10 89.75 316.37 6,406.75 6,350.55 6,513.97 1,189.30 6,037,616.89 471,139.47 0.73 6,219.27 MWD+IFR2+MS+sag(5) 11,885.85 90.06 316.41 6,406.92 6,350.72 6,585.47 1,121.19 6,037,688.66 471,071.66 0.32 6,301.25 MWD+IFR2+MS+sag(5) 11,930.00 91.64 315.62 6,406.26 6,350.06 6,617.23 1,090.53 6,037,720.54 471,041.13 4.00 6,337.74 MWD+IFR2+MS+sag(6) 11,982.38 88.70 316.59 6,406.11 6,349.91 6,654.98 1,054.22 6,037,758.42 471,004.98 5.91 6,381.08 MWD+IFR2+MS+sag(6) 12,078.63 90.49 317.22 6,406.79 6,350.59 6,725.25 988.46 6,037,828.96 470,939.51 1.97 6,461.46 MWD+IFR2+MS+sag(6) 12,173.76 89.69 319.77 6,406.64 6,350.44 6,796.49 925.43 6,037,900.44 470,876.77 2.81 6,542.32 MWD+IFR2+MS+sag(6) 12,270.70 88.95 319.99 6,407.79 6,351.59 6,870.61 862.97 6,037,974.81 470,814.62 0.80 6,625.94 MWD+IFR2+MS+sag(6) 12,367.70 90.00 322.34 6,408.68 6,352.48 6,946.16 802.15 6,038,050.60 470,754.11 2.65 6,710.68 MWD+IFR2+MS+sag(6) 12,463.93 90.37 324.79 6,408.36 6,352.16 7,023.58 745.00 6,038,128.24 470,697.28 2.57 6,796.63 MWD+IFR2+MS+sag(6) 12,560.38 87.10 323.14 6,410.49 6,354.29 7,101.54 688.28 6,038,206.42 470,640.89 3.80 6,883.06 MWD+IFR2+MS+sag(6) 12,656.14 88.21 318.40 6,414.41 6,358.21 7,175.63 627.79 6,038,280.75 470,580.70 5.08 6,966.31 MWD+IFR2+MS+sag(6) 12,753.18 88.46 312.81 6,417.24 6,361.04 7,244.91 559.96 6,038,350.30 470,513.16 5.76 7,046.06 MWD+IFR2+MS+sag(6) 12,849.23 92.10 310.33 6,416.77 6,360.57 7,308.63 488.12 6,038,414.30 470,441.58 4.59 7,121.00 MWD+IFR2+MS+sag(6) 12,945.70 91.91 311.58 6,413.39 6,357.19 7,371.82 415.31 6,038,477.78 470,369.03 1.31 7,195.59 MWD+IFR2+MS+sag(6) 13,041.26 92.60 311.23 6,409.63 6,353.43 7,434.97 343.69 6,038,541.21 470,297.68 0.81 7,269.94 MWD+IFR2+MS+sag(6) 13,138.40 92.78 310.74 6,405.07 6,348.87 7,498.61 270.44 6,038,605.14 470,224.70 0.54 7,345.04 MWD+IFR2+MS+sag(6) 13,235.25 92.72 311.27 6,400.43 6,344.23 7,562.09 197.44 6,038,668.90 470,151.96 0.55 7,419.94 MWD+IFR2+MS+sag(6) 13,330.33 92.59 312.55 6,396.02 6,339.82 7,625.53 126.75 6,038,732.62 470,081.54 1.35 7,494.41 MWD+IFR2+MS+sag(6) 13,427.17 92.59 312.94 6,391.65 6,335.45 7,691.19 55.71 6,038,798.56 470,010.77 0.40 7,571.14 MWD+IFR2+MS+sag(6) 13,524.23 91.79 313.29 6,387.94 6,331.74 7,757.48 -15.09 6,038,865.13 469,940.25 0.90 7,648.44 MWD+IFR2+MS+sag(6) 13,619.99 87.90 314.93 6,388.20 6,332.00 7,824.11 -83.83 6,038,932.04 469,871.78 4.41 7,725.73 MWD+IFR2+MS+sag(6) 13,716.44 87.41 312.76 6,392.14 6,335.94 7,890.87 -153.33 6,038,999.06 469,802.56 2.30 7,803.27 MWD+IFR2+MS+sag(6) 13,813.17 87.04 312.38 6,396.83 6,340.63 7,956.23 -224.48 6,039,064.71 469,731.68 0.55 7,879.71 MWD+IFR2+MS+sag(6) 13,908.90 87.22 309.71 6,401.62 6,345.42 8,019.00 -296.58 6,039,127.77 469,659.84 2.79 7,953.77 MWD+IFR2+MS+sag(6) 14,004.48 84.75 311.13 6,408.31 6,352.11 8,080.81 -369.17 6,039,189.87 469,587.52 2.98 8,026.96 MWD+IFR2+MS+sag(6) 14,101.20 86.05 309.21 6,416.07 6,359.87 8,143.00 -442.83 6,039,252.34 469,514.11 2.39 8,100.70 MWD+IFR2+MS+sag(6) 14,196.40 88.21 304.63 6,420.84 6,364.64 8,200.09 -518.82 6,039,309.74 469,438.36 5.31 8,169.82 MWD+IFR2+MS+sag(6) 14,292.19 89.32 305.22 6,422.90 6,366.70 8,254.92 -597.34 6,039,364.87 469,360.07 1.31 8,237.13 MWD+IFR2+MS+sag(6) 14,464.00 89.32 305.22 6,424.94 6,368.74 8,354.00 -737.69 6,039,464.51 469,220.14 0.00 8,358.50 PROJECTED to TD 12/14/2012 1:08:21PM Page 6 COMPASS 2003.16 Build 42 O 9 o a o ` w C aco ) C >. a) a) Co N co o Z C N N CO co > > 0 0 0 m 0 0 �' O N .N O O 0 a) C C CO CO CO Q co m c Cl) 0 U)I 2 I I 0 0 0 0 Q Q Q 0 p Q C d ). p m co m m CO m m 0 0 0 -J Q .J c d N a Q Q < < Q < Q Z Z Q N a) 0 0 N a) 0 0 0 0 J J Z Z Z Z c Z Q Q < Q < Z O O O CO a O c C F- j (/) Z Z Z Z - a O o N 0 Q c N U U U C) Ce ce W O W ,O W e W C W C W e v=Ni °) J o g � o Xo am am X001 � o � o CL0 d a) 0 Q J v o .- .- W W C7 c U' c U` p +a p U a o W W W - W a a) p a) pa 0a w 0 p o ccc ce ac xc 0 0 a2 aN aa) 0100 EL u0) aa) 0- Fo- E C1 r 0 0 e O c Cpm 0a) pc p c 00_ 00_ O m cK a) a a) 0 0 -0 0 CY• N CL Epo 02 0a) payi ao ao m m E ,-a )-a w Uo Fi Ea =° la- 76 ad as O:° O :9 c my m13 __E a p To rn oOc Oc O � py ac � c mo mo m_ ao a � m.w r as co o C) a' 0 a' 0 a' a' a) ma_ N a N a N 'C a_03 co O O F- W J p pm p pia pd p> po p `o paci pj > > > pc o a) 8 13 om it CC O a4 ' wC MI Cl)a 3 C.) oY W Z co N Et O N w V N W W W C C C C C C C C C C C C C C C Z a Ua J o m I I a 0 O 0 O nO nO a. a 0 0 aO CD aO CD aO aO a a Cl) 0 O O O Z0 Q co co o co v v v ,- v co o m 1.1 _ O N h N.co N Mco co Nr co V Od' O W .7 N N N 01 CO CD CO CO CN LC) CO LO Ja 7 a O 65o w 0. 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(i) I Q co J d 7 w I J c. m 1 o IL p U U 1 O N a I eo E Q o Z Vti 0 0 J aro Q N I C CD V V o CO d co co N O N — N Lo N V E 0 o 5� • N Id C cr, W Y c 1 H g F- E C V/ • fC fn U N C p C C O < p , m O 17.9 p N C a Q C at O E CI E U U o 2 o co 1 z m Mc z } r } z € W o o �� ) W E a m N N 0 o N rn rn o) Ui - c L. 0. m .E .0 .5 EE Z 0a N y 0 • `D co 1I 0 0 0 p a) Y 1 re CO Z m m CI • .- ` I Q o o 2 � m re 'y d V a a o E •a E o77). u_ E o o E E 0 Z U 0_ 0 0 0 �"�:'222.�u ,ya. ,to if M{Migi.,or._o-sarry; LIESIIN nw,..w.s r c,,,i 'i547Ee5' Ys,+ ..,s.. .y�'' w ..i.,�,...e:.'lr i� .,yl�°r �i: l�'.' -- �+„� x �i��v�. ::518'.��:,7^�.`y.4 �°:�•., �t"'Ym �r•�._.s.�....-�croLh,'"• - t ip \ \\I1/7 0, , M-THE S 4-,A E c.`ur �it''''L �t ___ ,--zz 7 ) 3' No SE Vf I1i1, AvE;r��,:C" l� w"" M -� .,:,\ t.R \`:)i !s;I:,-, .• ..L'.'`.r,l i A 1ChOIC�C)c., tIO5%C. �)>�`J�' -352 -� Jack Kralick �_ I/ D� Well Work Supervisor Pioneer Natural Resources Alaska, Inc. I .: 700 G Street, Suite 600 Anchorage AK 99501 Re: Oooguruk—Nuiqsut Oil Pool, ODSN-29 Sundry Number: 314-134 Dear Mr. Kralick: 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, U /---9_71,,e_A,14r.„____ Cathy P. Foerster Chair DATED this �1 day of March, 2014. Encl. r RECEIVED ' STATE OF ALASKA j, ALASKA OIL AND GAS CONSERVATION COMMISSION VAR 0 U LU APPLICATION FOR SUNDRY APPROVALS AQGCu 20 MC 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❑ fr Perforate 0 Pull Tubing 0 lime Extension ❑ Operations Shutdown 0 Re-enter Susp.Well 0 M xI Stimulate❑, Alter Casing 0 I Other. 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Pioneer Natural Resources Alaska, Inc. . Exploratory 0 Development 0. 212-106• 3.Address: 700 G Street, Suite 600 Stratigraphic 0 Service 0 6.API Number. Anchorage,AK 99501 50-703-20661-00-00• 7.If perforating: 8.Well Name end Number. What Regulation or Conservation Order governs well spacing in this pool? WA ODSN-29• Will planned perforations require a spacing exception? Yes 0 No ❑r • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036/ADL 389958 • Oooguruk-Nuiqsut Oil Pool- 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 15,716' . 6430' . 15,705' ‘ 6430' . N/A N/A Casing ' Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 4101' 11-3/4" 4140' 3544' 5830 psi 3180 psi Intermediate 1 3314' 9-5/8" 3924'-7238' 3413'-5506' 5750 psi 3090 psi Intermediate 2 9721' 7" 9759' 6430' 7240 psi 5410 psi Liner 6182' 4-1/2' 9524'-15,706' 6413'-6430' 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 4-1/2", 13.5# P-110, HYD 521 9540' 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: Detailed Operations Program Q. BOP Sketch 0 Exploratory 0 Stratigraphic❑ Development❑r ' Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/15/2014 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 best of my knowledge. Contact Jack Kralick 343-2185 Email jack.kralickcC,D.pxd.com Printed Name Jack Kralick Title Well Work Supervisor Signature Phone Date 343-2185 3/5/2014 __— COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3V-L- \3`{ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: it Fiac 6 1)..4i-.+ e..h Thi, RBDMSS.MAY 1 0 2014 Spacing Exception Required? Yes 0 No [ Subsequent Form Required: /0- 4-Any APPROVED BY Approved by: iv____ COMMISSIONER p THE COMMISSION Date: 3 1l(—/L '7 1/� Submit Form and Form 10-403( ed 1le-0/2012) ApUe iRpf li�a�ot NATI months from thef approval. Attachments in Duplicate �VRR V //d—,- /y Pioneer Natural Resources Alaska Inc. ODSN-29 Page 2 AOGCC Form 10-403, Application For Sundry Approvals Present Well Condition Summary, Box #11 Perforation Depth (MD/TVD) - Attachment 4-'/z", 13.5#, P-110 Hydril 521 Uncemented Liner MultiPoint Frac Sleeves w/ Segmented Seat: MD TVD 10,179' - 10,182' 6445' - 6445' 10,336' - 10,340' 6444' - 6444' 10,750' - 10,754' 6433' - 6433' 10,909' - 10,913' 6430' - 6430' 11,379' - 11,382' 6415' - 6414' 11,537' - 11,541' 6410' - 6410' 12,231' - 12,235' 6407' - 6407' 12,389' - 12,393' 6409' - 6409' 12,903' - 12,907' 6415' - 6415' 13,059' - 13,063' 6409' - 6409' 13,726' - 13,730' 6417' - 6417' 13,883' - 13,887' 6423' - 6423' 14,263' - 14,266' 6425' - 6425' 14,421' - 14,425' 6428' - 6428' 14,786' - 14,790' 6429' - 6429' 14,944' - 14,948' 6431' - 6431' MultiPoint Frac Sleeves w/ Solid Seat: MD TVD 10,410' - 10,413' 6442' - 6442' 11,067' - 11,070' 6427' - 6427' 11,612' - 11,614' 6408' - 6408' 12,506' - 12,509' 6409' - 6409' 13,217' - 13,220' 6402' - 6402' 13,957' - 13,960' 6423' - 6423' 14,495' - 14,498' 6428' - 6428' 15,102' - 15,105' 6432' - 6432' Pressure Activated Sleeves: MD TVD 15,644' - 15,647' 6429' - 6429' 15,698' - 15,700' 6430' - 6430' Pioneer Natural Resources Alaska Inc. ODSN-29 Page 3 AOGCC Form 10-403, Application For Sundry Approvals Present Well Condition Summary, Box #11 Packers and SSSV Type (MD/TVD) - Attachment `XXO' SVLN MD TVD 2082' 2020' ZXP 5" x 7" Hydril 521 Liner Top Packer MD TVD 9,523' — 9,549' 6413' — 6415' Slide-on Type Swell Packer MD TVD 11,770' 6407' ECP Packers MD TVD 9,949' — 9,972' 6436' — 6436' 10,647' — 10,670' 6434' — 6434' 11,178' — 11,201' 6423' — 6422' 12,017' — 12,040' 6407' — 6407' 12,701' — 12,724' 6416' — 6416' 13,370' — 13,394' 6401' — 6403' 13,508' — 13,531' 6408' — 6409' 14,110' — 14,133' 6424' — 6424' 14,648' — 14,671' 6427' — 6428' 15,249' — 15,273' 6431' — 6431' PIONEER NATURAL RESOURCES ALASKA ODSN-29 Refrac Ref: PTD 212-206 Ref: Sundry 313-033 Current Status: ODSN-29 was completed in 2013 and fracture stimulated via frac sleeves isolated ECP's across the Nuiqsut formation. The well has not performed as expected and will be refractured to increase production. Procedure: 1) Move in and berm 8 frac tanks with a minimum volume capacity of 10% greater than the largest tank. Load the tanks with seawater from the Conoco seawater injection system 2) Rig up Schlumberger equipment to goat head. ho-.X 3) Pressure test surface lines to 9000 psi st' 7 TeLu 36, 4) Tie in LRS pump to IA and maintain 3500 psi on'th�adjustingup or down as necessary during the treatment �uP -c 3 j 5f.�Q £ s -{a 37S-z.) p 5) Pump a 240 bbl breakdown with Schlumberger's WF130 fluid. Bring pumps up to maximum rate ASAP as pressure allows WF130 fluid consists of • Viscosifier @ 30 ppt • Surfactant @1 gpt • Scale Inhibitor @ 2 gpt • Breakers @ 1 -4 ppt • Biocide @ 0.25 gpt 6) Pump the following schedule at-30 BPM with a maximum expected pressure of-7500 psi, add breaker as per lab results. • 500 bbls YF130ST Pad • 240 bbls YF130ST w/2 ppa 16/20 Carbolite • 600 bbls YF130ST w/4 ppa 16/20 Carbolite • 400 bbls YF130ST w/6 ppa 16/20 Carbolite • 400 bbls YF130ST w/8 ppa 16/20 Carbolite • 200 bbls YF130ST w/10 ppa 16/20 Carbolite • 200 bbls YF130ST w/12 ppa 16/20 Carbolite • Flush with WF130 fluid and freeze protect well, well head and surface equipment PIONEER NATURAL RESOURCES ALASKA Total Prop: —410,000 lbs. YF130ST fluid consists of • Viscosifier @ 30 ppt • Surfactant @1 gpt • Scale Inhibitor @ 14 gpt during the pad stage • Scale Inhibitor @ 2 gpt during the prop stages • Breakers @ 1 —6 ppt • Crosslinker @ 6-7 gpt • Biocide @ 0.25 gpt 7) Monitor the surface pressure post frac for 30 minutes if the well has not screened out. 8) Rig down frac equipment. 9) Rig down frac equipment, move to next well 10) Flow back well thru Expro testing equipment until well has stabilized 11) MIRU as necessary to return well to production a) CT b) Slick Line General Well Info: MASP 9500 psi Reservoir Pressure/TVD 3200 psi/6,227' Wellhead Type/ Pressure Rating GE Vetco Gray MB-233 system/4-1/16" 5,000 psi Tree Configuration Dual valve tree 10K Frac Tree Comments: The 7" casing was cemented with 25 bbls of 12.5 ppg Class G + additives and 51 bbls of 15.8 ppg Class G + additives. Displace cement with 20 bbls of seawater and 352 bbls of 11.2 ppg mud. Bump plug to 3500 psi, hold for 10 minutes. Floats held and there were full returns throughout the entire pumping operation. Well Type Nuiqsut Producer Estimated Start Date April 15, 2014 Completion Engineer Rami Jasser Well Site Supervisor Jamey Bowman/Lou Lyles (907) 670-6602 OooqurukWellworkSupervisorpxd.com ODSN-29 Nuiqsut Production Well Completion Updated 12/20/2012 I i Upper Completion mQ ,e ]Y iii I 16"Conductor 1)Tubing Hanger 43' 43' 2)4-'/3"13.5#/ft Hydril 521 Tubing Packer Fluid mix: 3)4-%"Halliburton'XXO'SVLN w/3.813""X"profile RTS-8 2082' 2020' Inhibited Kill weight with singlel/4"x 0.049"s/s control line. " ` Cannon Cross-coupling clamps on every joint Din3 Brine 4)4-Y 13.5#/ft Hydril 521 Tubing p with 2000'ND 5)4-'/i'x 1"GLM,KBMG Hydril 521 w/SOV 2231' 2155' !i;,i'i i diesel can 6)4-%"13.5#/ft Hydril 521 Tubing 3'+,������• 7)HES X 3.813" 2299' 2208' l 8)4-'/:"13.5#/ft Hydril 521 Tubing 9)4'/d'x 1"GLM,KBMG Hydril 521 w/DV 4277' 3635' 10)4-'/:"1 3.5#/ft Hydril 521 Tubing 11)4-'14"x 1"GLM,KBMG Hydril 521 w/DV 6359' 4957' 11-3/4 60 ppf L-80 BTC 12)4-'1z"13.5#/ft Hydril 521 Tubing Surface Casing 13)4-'14"x 1"GLM,KBMG Hydril 521 w/DV 7856' 5900' GL I @ 4140' MD/3544'TVD 14)a'1"13.5#/ft Hydril 521 Tubing 0 15)HES XN 3.813"(3.725"NoGo)-with RHC Plug 8512' 6265' cemented to surface 16)4-'/"13.5#/ft Hydril 521 Tubing 0 x I 17)4-1/2"Halliburton'ROC'Gauge Carrier w/1/4"x 0.049"s/s control line 8617' 6306' ,. 18)4-'14"13.5#/ft Hydril 521 Tubing 19)Bullet Seal Assembly with Ratcheting Mule Shoe 9538' 6413' I Bottom of Shoe 9540' 6414' O GL ..... lir 9-5/8"40 ppf L-80 Hydril 521 Intermediate 1 Casing @ 7238'MD/5506'TVD GL 4-1/2" 13.5 ppf l P-110 Hydril 521 Tubing 013 GL . lInii 15) XN liiiii Go -Roc- __= TOC Estimated iiiiii 500'above top of `: Kuparuk IiiiT;1171, i . I 4 0 Fault @ 13,470'MD 32 44 54 56 78 80 90 �� O 66 n41/4/ O O O O 7 26 ppf L-80 BTC- , f4 "jpj r- _ _ip _ _ _ _ _ - _ ,1„1, 2 I - -W- - - - - - -I -_- - - Casing @ 9759'MD/6430' 1 TVD Fault @ I FAILED ECP 11,980 ft MD 6-1/8" Hole TD at at 15716' MD/ 4-'/z" Hydril 521 Liner with Baker Hughes Multi- 6430'TVD Point Frac Sleeves(3 per stage) isolated with ECP's+ Resman Carriers ODSN-29 Nuiqsut Production Well Completion Updated 12/20/2012 Lower Completion fila TVD Ai 20)Baker 5-%"X 7"ZXP Liner Top Packer with 15ft Tie Back 9524' 6413' III I 16"Conductor extension and Flex Lock Hanger I 21)4-%"13.5#/ft Hydril 521 Liner Packer Fluid mix: 22)Baker ECP Packer(4-%"Hydril 521) 9949' 6436' Inhibited Kill weight 23)4-%"13.5#/ft Hydril 521 Liner 9 24)Baker Multi-Point Frac Sleeve with segmented ball seat(3.000 ball/2.948 Seat) 10179' 6445' I Brine 25)4-'/"13.5#/ft Hydril 521 Liner 3 with 2000'TVD 26)4-/"Resman Tracer Carrier w/15 ft pups on each side 10253' 6445' C i € diesel cap Liner 28)Baker Multi-Pot int 521il FracSleeve with segmented ball seat(3.000 ball/2.948 Seat) 10336' 6444' 1.11 "Eil 29)4-/ 13.5#/ft Hydril 521 Liner iii''i 30)Baker Multi-Point Frac Sleeve with solid ball seat(3.000 ball/2.948 Seat) 10411' 6442' 31)4-%"13.5#/ft Hydril 521 Liner 32)Baker ECP Packer(4-1/2"Hydril 521) 10647' 6434' 11-3/4"60 ppf L-80 BTC 33)4-"A"13.5#/ft Hydril 521 Liner Surface Casing 34)Baker Multi-Point Frac Sleeve with segmented ball seat(2.938 ball/2.885 Seat) 10751' 6433' 35)4-14"13.5#/ft Hydril 521 Liner 4140' MD/3544'TVD 5 I @ 36)4-%"Resman Tracer Carrier w/15 ft pups on each side 10826' 6431' cemented to surface 37)4-14"13.5#/ft Hydril 521 Liner 38)Baker Multi-Point Frac Sleeve with segmented ball seat(2.938 ball/2.885 Seat) 10910' 6430' 7 I 39)4-1/"13.5#/ft Hydril 521 Liner 40)4-%"Resman Tracer Carrier w/15 ft pups on each side 10985' 6429' IIII 41)4-1/"13.5#/ft Hydril 521 Liner 42)Baker Multi-Point Frac Sleeve with solid ball seat(2.938 ball/2.885 Seat) 11068' 6427' 43)4-%"13.5#/ft Hydril 521 Liner � I `': 44)Baker ECP Packer(4-%"Hydril 521) 11178' 6423' 1'6;1Ifil 9-5/8"40 ppf L-80 Hydril 521 45)4-%"13.5#/ft Hydril 521 Liner 46)Baker Multi-Point Frac Sleeve with segmented ball seat(2.875 ball/2.823 Seat) 11379' 6415' Intermediate 1 Casing 47)4-%"13.5#/ft Hydril 521 Liner @ 7238' MD/5506'TVD 48)4-%'Resman Tracer Carrier w/15 ft pups on each side 11454' 6413' 49)4-1/"13.5#/ft Hydril 521 Liner 50)Baker Multi-Point Frac Sleeve with segmented ball seat(2.875 ball/2.823 Seat) 11538' 6410' 51)4-%"13.5#/ft Hydril 521 Liner 1i 4-1/2" 13.5 ppf 52)Baker Multi-Point Frac Sleeve with solid ball seat(2.875 ball/2.823 Seat) 11612' 6408' P-110 Hydril 53)4-1/"13.5#/ft Hydril 521 Liner 54)4-V 13.5#/ft Hydril 521 Liner with 2 HLB slide on centralizers 11756' 6407' 521 55)4-14"13.5#/ft Hydril 521 Liner Tubing 56)Baker ECP Packer(4-4"Hydril 521) 12017' 6407' i I;, 57)4-1/"13.5#/ft Hydril 521 Liner 58)Baker Multi-Point Frac Sleeve with segmented ball seat(2.813 ball/2.760 Seat) 12231' 6407' I 'ii 59)4-%"13.5#/ft Hydril 521 Liner ® i 60)4-1/"Resman Tracer Carrier w/15 ft pups on each side 12306' 6408' iiiii61)4-14"13.5#/ft Hydril 521 Liner Mil 62)Baker Multi-Point Frac Sleeve with segmented ball seat(2.813 ball/2.760 Seat) 12389' 6409' 0 63)4-1/"13.5#/ft Hydril 521 Liner TOC Estimated 64)Baker Multi-Point Frac Sleeve with solid ball seat(2.813 ball/2.760 Seat) 12506' 6409' i!i ii 500'above top of 65)4-1/"13.5#/ft Hydril 521 Liner il iii 66)Baker ECP Packer(4-/ Hydril 521) 12701' 6416' Iiii, Kuparuk 67)4-1/"13.5#/ft Hydril 521 Liner 68)Baker Multi-Point Frac Sleeve with segmented ball seat(2.750 ball/2.698 Seat) 12903' 6415' 69)4-%"13.5#/ft Hydril 521 Liner 70)4-%"Resman Tracer Carrier w/15 ft pups on each side 12977' 6412' 0 71)4-14"13.5#/ft Hydril 521 Liner 72)Baker Multi-Point Frac Sleeve with segmented ball seat(2.750 ball/2.698 Seat) 13060' 6409' \ `i i: 73)4-%"13.5#/ft Hydril 521 Liner 74)4-/"Resman Tracer Carrier w/15 ft pups on each side 13134' 6405' »I:: :. ,`0 75)4-%"13.5#/ft Hydril 521 Liner 0 Fault @ 13,470' MD Ii![ 32 �� ® 54 56 66 78 l 90 90 �� 411) 7"26 ppf L-80 BTC 4 ' so -- Mod + Hydril 521 2a * IIELIE _ =I' — - _ -. _ _ -I- — -1 - — _ . -I=I� Intermediate 2 _ Casing Ell �___ @ 9759' MD/6430' 0 TVD Fault @ I FAILED ECP 11,980 ft MD 6-1/8" Hole TD at 4-'/2" Hydril 521 Liner with Baker Hughes Multi-Point at 15716' MD/ Frac Sleeves(3 per stage) isolated with ECP's+ 6430'TVD Resman Carriers ODSN-29 Nuiqsut Production Well Completion Updated 12/20/2012 I Lower Completion 112 UR /11111111 D::1,1,'iii, 16"Conductor 76)Baker Multi-Point Frac Sleeve with solid ball seat(2.750 ball/2.698 Seat) 13218' 6402' 77)4-'h"13.5#/ft Hydril 521 Liner Packer Fluid mix 78)Baker ECP Packer(4-/"Hydril 521) 13370' 6402' Inhibited Kill weight 79)4-'/z"13.5#/ft Hydril 521 Liner 9 80)Baker ECP Packer(4-%"Hydril 521) 13508' 6408' IC) • Brine 81)4-'/:"13.5#/ft Hydril 521 Liner iii with 2000'TVD 82)Baker Multi-Point Frac Sleeve with segmented ball seat(2.688 ball/2.635 Seat) 13727' 6417' ,eu.i diesel cao 83)4-'/:"13.5#/ft Hydril 521 Liner iiiiiii ;•1„�u / 84)4-'/:”Resman Tracer Carrier w/15 ft pups on each side 13801' 6420' • 11111111 85)4-'/:"13.5#/ft Hydril 521 Liner iliiiiii 86)Baker Multi-Point Frac Sleeve with segmented ball seat(2.688 ball/2.635 Seat) 13884' 6423' jiil87)4-'/"13.5#/ft Hydril 521 Liner 88)Baker Multi-Point Frac Sleeve with solid ball seat(2.688 ball/2.635 Seat) 13958' 6423' 11-3/4"60 ppf L-80 BTC 89)4-y2"13.5#/ft Hydril 521 Liner Surface Casing 90)Baker ECP Packer(4-W Hydril 521) 14110' 6424' 4140' MD/3544'ND 91)4-1%"13.5#/ft Hydril 521 Liner GL I @ 92)Baker Multi-Point Frac Sleeve with segmented ball seat(2.625 ball/2.573 Seat) 14263' 6425' cemented to surface 93)4-'4"13.5#/ft Hydril 521 Liner 94)4-%"Resman Tracer Carrier w/15 ft pups on each side 14339' 6426' 7 X 95)4-'/="13.5#/ft Hydril 521 Liner I 96)Baker Multi-Point Frac Sleeve with segmented ball seat(2.625 ball/2.573 Seat) 14422' 6428' 97)4-'/:"13.5#/ft Hydril 521 Liner 98)Baker Multi-Point Frac Sleeve with solid ball seat(2.625 ball/2.573 Seat) 14496' 6428' ilill 99)4-'/:"13.5#/ft Hydril 521 Liner � GL 100)Baker ECP Packer(4-1/"Hydril 521) 14648' 6427' (ID iii, 9-5/8"40 ppf L-80 Hydril 521 101)4-1%"13.5#/ft Hydril 521 Liner Intermediate 1 Casing102)Baker Multi-Point Frac Sleeve with segmented ball seat(2.563 ball/2.510 Seat) 14787' 6429' 103)4-W 13.5#/ft Hydril 521 Liner @ 7238' MD/5506'TVD 104)4-'/2"Resman Tracer Carrier w/15 ft pups on each side 14862' 6430' 105)4-'/2 13.5#/ft Hydril 521 Liner 106)Baker Multi-Point Frac Sleeve with segmented ball seat(2.563 ball/2.510 Seat) 14945' 6431' 107)4-'16"13.5#/ft Hydril 521 Liner 0 GL 4-1/2" 13.5 ppf 108)4-14"Resman Tracer Carrier w/15 ft pups on each side 15020' 6431' P-110 Hydril 109)4-'/4"13.5#/ft Hydril 521 Liner 521 110)Baker Multi-Point Frac Sleeve with solid ball seat(2.563 ball/2.510 Seat) 15102' 6432' 111)4-%"13.5#/ft Hydril 521 Liner • Tubing 112)Baker ECP Packer(4-Y:"Hydril 521) 15249' 6432' 113)4-'14"13.5#/ft Hydril 521 Liner grh GL i!,!!! 114)4-'14"13.5#/ft Hydril 521—10 ft Pup _ 115)4-14"Resman Tracer Carrier w/15 ft pups on each side 15469' 6431' iiiiii ® xN I i€ 116)Pressure Activated Sleeve"B"5,800 psi 15644' 6430' 11110 gli 117)Pressure Activated Sleeve"A"5,600 psi 15698' 6430' 118)Wellbore Isolation Valve"WIV" 15700' 6430' 0 NI 119)Eccentric Shoe 15705' 6430' Tiii: linTOC Estimated Bottom of Shoe 15706' 6430' I 500'above top of iqiii Kuparuk iiiiiiii 0 -iiii!,. lop .:iiiiii:, . \, 10 78 0 Fault 13,470' MD ®. 32 O O 56 66 80 90 �� 7 26 ppf L-80 BTC- 4ppb I' 0- Mod 26 =11 - - - -I- - -I -III- -I- -IEIE - -I-I- 2 Intermediate 2 - Casing @ 9759'MD/6430' T 1111) TVD Fault @ 1 FAILED ECP 11,980 ft MD 6-1/8" Hole TD at at 15716'MD/ 4-W Hydril 521 Liner with Baker Hughes Multi-Point 6430'TVD Frac Sleeves(3 per stage) isolated with ECP's+ Resman Carriers N N M Lo E CU Ul Q O 03 Cf) W U L- ai Z — V CC0 U) w CZ _ cc in <- o _ - IJ C.).4Z _ in 0 - in 0 o — o mr N N `\ -N- ,- N \ , N N A'. N N , V '4� r N O Z ' :'D 1 .7) ‘ \ \ ;/1 al O N fn�. N Zrc'� c0 /, 0 ��- N Z N co N O ( o O vZ O O P] ' / ~ W ;'O et _ / 0 1 �o z / O O CO CO / 0 O z N N u) N O Z / .� - V1 Cil (0 • N • LLi O O N. Z q N N M , OD N N Z Z • N CI O v = Q o N_ .. Q CO M rn o cv) M UJ d m LL C I m W E a o Z Z - >- cn H co N N � - co TM Attachment A WES Completion Design Analysis Operator Name: Pioneer Field Name: Oooguruk Well Name: ODSN-29 Rig Name: Wellbore Name: 1 Run*or Condition: Frac Top MD Bottom MD Length Tool Name OD Weight ID 0.00 9,500.00 9,500.00—Surface Casing 7.000 26.00 6.276 F __ Tubing Intonnation Top MD(ft) Bottom MD(ft) Length(ft) Type 00(In) Weight(Ibelt) ID(In) Material Type Yield Strength(pel) 0.00 9,500.00 9,500.00 Tubing 4.500 12.60 3.968 STEEL 110,000.00 • Packei?ype Depth MD(ft) Pressure(psi) High Span Out Mor Noch. ~ TensionSlack )(lbf) Plug MD(ft)+) 'EffectiveDie. Seal ) ELlne 9,600.00 0.00 0.00 No 40,000.00 0.00 5.260 I Ininnn ation 1/1 Maximum 01): 0.000 In [ Initial Conditions Bottom MD Fluid Weight 9,600.00 10.00 tri:: ,.id ,' Bottom MD iFluid Weight 9,500.00 10.00 Bottom MD Temperature 0.00 40.00 9,500.00 170.00 Annulus: 0 pal Tubing 0 psi MD(ft) Packer to Tubing Force(Ibf) 9,500.00 40,000 Packer Type MD(ft) Total(In) ELine 9,500.00 41.60 Packer Type MD(ft) Pbten•Tenslen/ Buckling(In) Ballooning(hi) Temperature(In) Total(In) Compression(In) ELIne 9,600.00 41.62 0.08 0.00 0.00 41.60 Safety _ Force Tubing Annulus DLS Max Length of (StmsFays. Tubing Section MD(ft) (lht) Stress(psi) Pressure Pressure (dega1100ft) WL Tool(ft) Yield Strength (Pen (pen %) Well head 0.00 -22,403 6,222 0 0 0.00 Infinity 17.88(5.7%) Ennio Packer _ 9,500.00 51,950 16,054 3,319 3,310 0.00 Infinity 6.85(14.6%) 1211912012 6:06:12 PM Baker 011 Tools InQurast"1t]9E MOVE'v2A.10100.p 1112312012) Page, t:opplaM 0 2001-2m1 Bala Bagkaa,IAA All Malta Raprvsd. Witte 1 TUB TM Completionins D.sIgn Design Analysis Operator Name: Pioneer Field Name: Oooguruk W.11 Name: OD8N-29 Rig Name: Wellbore Name: 1 Run 8 or Condition: Frac 1 Bottom MD Fluid Weight 2,000.00 8.90 9,600.00 10.00+ _ �VGr. Bottom MD Fluid Weight 9,600.00 12.80, Bottom MD Temperature 0.00 70.00 9,600.00 100.00 `Mr _ _ __ _ 1.111111115aljace Pressure Annulus: 3000 psi Tubing9600 pal a_. Fin. •Packer Analysis MD(ft) ' Packer to Tubing Force(Ibi) Differential Pressure(psi) Torque(Ibf-ft) 9,600.00 0 7,749 0 Final Actual Tubing Movement at Packer (Negative movement is up) Packer Type MD(ft) Total(In) ELine , 9,900.00 -117.34 -_— _� tea` final Theoretical Tubing Movement(if permitter()at Parker (Negative movement i; up) - Packer Type MD(ft) (F1tn Buckling(In) Ballooning(In) Temperature(In) Total(In) ELina 9,600.00 -85.18 -7.85 40.14 -15.73 -158.91 •1111 11111111r A4uebd Inkhl Actual High Space Out(In) Final Theoretical Final Position(In) Movement(In) Movement(In) 41.60 0.00 -158.91 -117.31 °: Final Landed.Condrtions(Negative force is tensile) Tubing Annulus Safety Factor Tubing Section MD(ft) Force(Ibf) Stress Pressure Pressure W DLS Mex Length of (Stress vs. (psq (psi) Pressure (dog00ft) WL Tool(ft) Yield Strength %) Weil head 0.00 19,652 60,440 9,600 3,000 11 37.01 1.82(54.9%) Ellne Packer 9,600.00 94,006 97,813 13,748 6,999 21 26.96 AMMIASSII Note:There are stresses that exceed maximum tubing yield strength.Please check your Input and result carefully. 12119/2012 5:08:13 PM Baker oil Tool.Inp,eM' 1UBEMOVE"d2A.10000M(6/22/N 12) Pegs 2 Copyrtgld 02001-201 elm Hughes,Inc.Al Run.R sued Attachment B Pioneer Natural Resources Inc.Alaska Asset Fracture Modeling Study-Nulqsut Background The Alaska Oil and Gas Conservation Commission (AOGCC) has requested that fracture modeling is conducted on the Nuiqsut reservoir to determine height growth. Height growth of the induced hydraulic fracture is an important parameter to determine whether the fracture grows beyond the defined oil pool confining sedimentary rock layers violating pool rules (Oooguruk-Nuiqsut Pool)or Area Injection Order 034 in order to ensure protection of surrounding reserves. Pioneer has contracted a third party, Barree and Associates, LLC to conduct the fracture modeling study using the software program GOHFER. A meeting was held on December 17, 2012 at the AOGCC office in Anchorage, Alaska with AOGCC representatives, Chris Wallace, Guy Schwartz, Patricia Bettis, and Steve Davies, and Pioneer representatives Tim Crumrine, Andy Bond, Pat Foley, and Vern Johnson. The meeting discussion centered on conducting a fracture study that would be inclusive of all potential fracture stimulation rates and pressures,so that each individual well would not be modeled,but Instead one model could be built In which the rates and pressures would exceed the capabilities of fracturing equipment hydraulic horsepower on location at the time of the fracture stimulation. This study Is Intended to cover all hydraulic fracture stimulations In the Nuiqsut oil pool, propped and unpropped(often referred to as high pressure breakdowns)in either producing or water injection wells. The following sections discuss the model input assumptions and the results from the induced hydraulic fracture study. Model Inputs and Assumptions Nuiqsut producing wells will be stimulated with two-million lbs of 16/20 mesh Carbolite ceramic proppant with approximately 200,000 lbs per stage for a total of 10 stages. Each producer well completion is set up to be mechanically or dynamically diverted,with some wells having a combination design. The greatest likelihood for a fracture to grow out of its confining intervals comes from a well with a vertical wellbore and a limited entry single perforation near the top or bottom of the interval being stimulated. Pioneer Alaska's wells are horizontal wells with multiple entry points that are landed in the middle of the zone. Essentially fractures in this type of wellbore are much less prone to fracturing out of zone. Each stage will contain approximately 200,000 lbs of 16/20 mesh Carbolite ramped from 0.5—10 ppa concentration with a 25 ppt cross-linked borate gel. The hydraulic horsepower on location during a fracture stimulation is approximately 12,000 HHP—based on anticipated pressures and rates. This equates to a rate limit of 60 barrels per minute based on expected pressures. Rates for the fracture modeling study were set at a limit of 80 barrels per minute: well above the available hydraulic horsepower on location. High pressure breakdown/scour treatments will be performed on Injector wells with no more than 20,000- 50,000 lbs of 20/40 mesh Carbolate proppant per stage. The Injector well completions have smaller upper completions that limit the rate to 25 barrels per minute and are dynamically diverted. The fracture model geological Input parameters were based on the Kalubik-1 well log data. Log data from the Kalubik-1 well were processed to derive rock mechanical properties and a stress profile for the fracture growth modeling. Based on previous MDT/RFT measurements, the pore pressure In the Nuiqsut was assumed to be on an effective 0.51 psi/ft gradient. No tectonic boundary conditions were applied to the stress profile. The Nuiqsut zone is shown in the figure below by the blue box.The two arrows indicate the upper and lower landing positions assumed for the modeling. These two fracture initiation sites are expected to represent any landing point in the zone. Kalubik 1 Processed Log Summary ., ,,,,, .t.• .. ., V .•.. - .•... . LmioNIP .o.., N.:..a - .4./. /.M., 8$25 00 _ * ��'+ -- _ p.4....: -i.'..--_-..t--.-•1-.. _. 8$50 00 : .1 iiilialrE�EiMiIEi_ :,. 837500 — E wm . -- :::. :. q8400.00 - � �''"'�:��':�.� Z JNuuqsut .ti•i7 8450 00 ♦ ..t 8475.00 or IMIMMIIIIIIIIIA —'. ti all : --t__. 8600 OD r+ •z :;, 0525 00 Nechelik i�� � 665000 � �•'•'•'• _ Mil 8676 00 !° tea` t t it • 8600.00 — «=—� — at_._ 8826 00 r •-•.----- 0 2012 i i, 8850.00 Figure 1. Kalubik-1 Processed Log Summary Modeling Results The proppant profile(side view)of the created vertical fracture in the upper part of the Nuiqsut is shown in the color-filled plot below. See Figure 2. The scale is 0-3 lb/ft2,shown at right.The fracture stays contained in the Nuiqsut at a maximum 80 bpm pump rate. A near-well concentration of 2-3 lb/ft2 is established,with a propped half-length of 300 feet.Vertical node resolution is 5 feet in the grid. F�i�iiiiFiiii�iaiii� c""'2.I I "-` :Cu:na:SC[tails:ttlaaE6tii::a=9E:CL:CgEElCt:3li: Etta::Cia:Ct::::EILCCr1Y::CCa:LIZHIIYE:cu:::: ii ii ii �iie i ::: iii • -... :;:: ::; ; :. ;� .eiai�ai era aai zi:al ia' '�. .tl. .. .# ie�'saiiie:ss:aiaii::»..._...w::::w:ea:::i..--------------:w:::.w. ;�;; '. •• ..... . ..a:LCL3:E:: : ..sa::C[CE:qE:Lltta:9a .:stet^•• --•::::::E9::::::t:: C::E::CC•:::9E:000:a:E:E::C " .tN:LYS:::LL:::::::C939::iii@Cii...wCCY3::C""--3:r'r9ra=::Q..C: C.i:.::::E::'r93:::C►YE:'r> ::n:[99I::C92Y1a9::C117:►@LCLCS:E:CCft69E:CC[a:S3EE:CCt:Eai::CCZaLLCt:Cr7SC:CC3'.r]Ea:Lglli::•.i "w ��+ tLa:a::l::C97l6:aat !•"t:a:a:itt[t:EES:[::EiEEC:C:3S::6:::LEES::::u:::Lt"»S:E:::La:::E:J- ..' CE'• Y•• '.� .H.. ._._ :[.::99E:99LYYa7C::CiE:.:@::n9.:..,3Ct ' 's.:u:- ?-S L[[E:n9E::[tSa7iiCtta::LE:tti9 L[ni:t9[ra9ia::CLga9CiaC[:EEL[CLC[Y9aL6Ci9ttEELCtt9E�0ih -+ ......2=t1" .. :;:..... :c _11 �? . . ' : ....... :;171.."'"" ... ... ....... �. .. ;3•01110114411. ~S::....fl5: .....Et:::....... .ia..a..CC. ......... Cdfl9>.::-:>MW.'y.�.Y ansmsa_ _........ . .. : - t-. Ma[t9imustnurztatinanatt!^.TemmtnnuttnisasumrstECr3aC![CC[97EECi'3:g9iimih C 2012 Figure 2.Proppant profile in the upper Nuiqsut Figure 3 Is the proppant profile of an additional modeling run with the fracture initiated In the lower part of the Nuiqsut. As in Figure 2,the scale is 0-3 lb/ft2 with a vertical node resolution of 5 feet.The fracture stays contained in the Nuiqsut at a maximum 80 bpm pump rate. ....... .......!., P0300110 Cencwaroa leek a KO am !:.,, ry: � t z.: .. z=t, i tib: M t..rr= ' ',,= C:G:C..." 1'377 C L.••:.. Mf - ::' h „ Cif :• ::: :.•..a•,a C0 ..ti ..:::CC::::: :: ' a ....::aaa:.. ..0::::::: a•: : : G. . : C : e7::G::::C-- CLCCC3as+ .a.... . a:00C:a :3: : : t :L:C:CGC ..:7:Z :::: 0 :a:::::::C:::G::::: 3::3:::C:CGCG:C: ::::: :: i:::::: : : : : : ::::::::::i :::::7:: : : : r::: ... +''• :CCC:3 7 CC::::0:3::::::73::::L 1 CL-•"'-•---'C::::G:::G:737 ::::: :: ::: te�o LCCCCC:G::::T:3 '" 441:71:::'': :.:: ::::: :: :::::: :::::::::::...::.1:: „ :::C: : 7 C 7 4,,M1S C 7 C L : C C .tea M.. w ..., MX 10 02012 ' 1 A Figure 3. Proppant profile in the lower Nuiqsut Conclusion Kalubik-1 well log data were processed to derive rock mechanical properties and a stress profile for the fracture growth modeling in the Nuiqsut reservoir. Two fracture initiation points were examined:one in the upper and one in lower sections of the Nuiqsut formation. A schedule placing 200,000 lbs of 16/20 CarboLite was run at the "worst-case" for height growth of 80 bpm. The current limitation for the maximum rate is based on the available horsepower on location. In either initiation point the fracture height is contained to the Nuiqsut at the maximum specified rate of 80 bpm. The most likely avenue for height growth is downward to the Nechelik, and this is not predicted to occur under any planned treating conditions. All treatments conducted below the maximum specified rates, pressures, and proppant concentrations are considered a subset of the models presented here in the study. 4 &Wag 1 ft 616198 , .•••"•.•• ' e • •••••••• MOUS MOUS ------••••••• — 0 `,' 0 ,i4-.. , C.i ............ .'.".*;.*.*.*.V...*; '1.‘ 1.41:3HIF INIIIM" 8 0 Ø •••••"••••• _I_H_I_J__ , 1 _, i _I _, 1_ I ., O 0 fisi6:1:0 _ ., ,_ 0 • • • • 0_ ._ • O 0 .,_ 0_ D, •_ •_ • •_ •_ _ • u=i 1-1-111-11 I : 11k11:- _--11-= . . . it...._„........... -sigillititil= I III II II II •''''''''"' CL '----•'-•'••• - 1 Stall/ft co O 0 0 cc. •••••••••••• to *44 '1 I I I 1111 III I 111 II 11111 I 1 I I.I I I iiiih E •---•••---•• a ,su 1.- c 0 0 ,. 0 •••'•''''''' ••••• ............ 0.) . o 0 ••---•------ t.) 0 ........................- 0 0 ."•""•"• •••••••••••• . 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I 11; --.2 0 I LL- re 1 'ot Tr Tt •t— a•-• S— CO e CO C•1 C•1 Cs1 0 0 0 II a) "ra V co .• RECEIVED STATE OF ALASKA ALA:' "IL AND GAS CONSERVATION COMMIS: DEC . 7 2013 REPOri i" OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well Plug Perforations U Perforl f Other U Performed: Alter Casing ❑ Pull TubiC Stimulate-Frac ❑✓ wain Time Extension❑ Change Approved Program ❑ Operat.Shutdov❑ Stimulate-Other 0 Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Pioneer Natural Resources Alaska, Inc Development ❑ Explorat1 212-106 3.Address: 700 G Street,Suite 600 Stratigraphic❑ Serv❑ 6.API Number: Anchorage,AK 99501 50-703-20661-00-00 . 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 355036/ADL 389958 ODSN-29 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Oooguruk-Nuiqsut Oil Pool 11.Present Well Condition Summary: Total Depth measured 15,716 feet Plugs measured N/A feet true vertical 6430 feet Junk measured N/A feet Effective Depth measured 15,706 feet Packer measured See Attach.,pg 3 feet true vertical 6430 feet true vertical See Attach.,pg 3 feet Casing Length Size MD ND Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 4101' 11-3/4" 4140' 3544' 5830 psi 3180 psi Intermediate) 3314' 9-5/8" 3924'-7238' 3413'-5506' 5750 psi 3090 psi Intermediate2 9721' 7" 9759' 6430' 7240 psi 5410 psi Liner 6182' 4-1/2" 9524'-15,706' 6413'-6430' 8430 psi 7500 psi Perforation depth Measured depth See Attach.,pg 2 feet True Vertical depth See Attach.,pg 2 feet Tubing(size,grade,measured and true vertical depth) 4-1/2", 13.5# P-110, Hyd 521 9540'MD 6414'TVD Packers and SSSV(type,measured and true vertical depth) 9,524'MD/6,413"ND 5-1/2"x7"Lnr Tp Pkr SVLN 2,082'MD/2,020'ND 12.Stimulation or cement squeeze summary: See attached vendor documentation Intervals treated(measured):Into Perforation Depths(see Attachment, pg. 3) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 2856 bopd " 1395 mscfpd 522 bwpd 1852 psi 408 psi 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory 0 Developn ✓ • Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil Q , Gas 0 WDSPL❑ GSTOR 0 WI N,0 WAG❑ GINJ 0 SUSP 0 SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-033 Contact Jack Kralick Email Jack.Kralickta�.pxd.com Printed Name Jack Kralick Title Well Work Supervisor Signature Phone 343-2185 Date l Lli Z Jia 1 / ^ �i3 RBDMS DEC 2 0 2 Form 10404 Revised 10/2012 .# 4 1,/,L,' (A1i I Submit Original Only Pioneer Na, Resources Alaska Inc. ODSN-29 Page 2 AOGCC Form 10-404 Report of Sundry Operations Open to Production or Injection Attachment Open to production or injection 4-'/2", 13.5#, P-110 Hydril 521 Uncemented Liner MultiPoint Frac Sleeves w/ Segmented Seat: MD TVD 10,179' - 10,182' 6445' - 6445' 10,336' - 10,340' 6444' - 6444' 10,750' - 10,754' 6433' - 6433' 10,909' - 10,913' 6430' - 6430' 11,379' - 11,382' 6415' - 6414' 11,537' - 11,541' 6410' - 6410' 12,231' - 12,235' 6407' - 6407' 12,389' - 12,393' 6409' - 6409' 12,903' - 12,907' 6415' - 6415' 13,059' - 13,063' 6409' - 6409' 13,726' - 13,730' 6417' - 6417' 13,883' - 13,887' 6423' - 6423' 14,263' - 14,266' 6425' - 6425' 14,421' - 14,425' 6428' - 6428' 14,786' - 14,790' 6429' - 6429' 14,944' - 14,948' 6431' - 6431' MultiPoint Frac Sleeves w/ Solid Seat: MD TVD 10,410' - 10,413' 6442' - 6442' 11,067' - 11,070' 6427' - 6427' 11,612' - 11,614' 6408' - 6408' 12,506' - 12,509' 6409' - 6409' 13,217' - 13,220' 6402' - 6402' 13,957' - 13,960' 6423' - 6423' 14,495' - 14,498' 6428' - 6428' 15,102' - 15,105' 6432' - 6432' Pressure Activated Sleeves: MD TVD 15,644' - 15,647' 6429' - 6429' 15,698' - 15,700' 6430' - 6430' Pioneer Natural Resources Alaska Inc. ODSN-29 Page 3 AOGCC Form 10-404 Report of Sundry Operations Packer Set - Attachment ZXP 5" x 7" Hydril 521 Liner Top Packer MD ND 9,523' — 9,549' 6413' — 6415' Slide-on Type Swell Packer MD ND 11,770' 6407' ECP Packers MD ND 9,949' — 9,972' 6436' — 6436' 10,647' — 10,670' 6434' — 6434' 11,178' — 11,201' 6423' — 6422' 12,017' — 12,040' 6407' — 6407' 12,701' — 12,724' 6416' — 6416' 13,370' — 13,394' 6401' — 6403' 13,508' — 13,531' 6408' — 6409' 14,110' — 14,133' 6424' — 6424' 14,648' — 14,671' 6427' — 6428' 15,249' — 15,273' 6431' — 6431' Pioneer Natural Resources Treatment Summary ODSN-29 - Part 1 - Zones 1-2 Alaska Section 11 Township 13N Range 7E API #: 50-703-20642 Nuiqsut 25# Hybor-G February 27, 2013 SO# 900249706 HALLIBURTON HALLIBURTONI Enhancement Table of Contents Section Page(s) Cover Sheet 1 TOC 2 Wellbore Information 3 Executive Summary 4-6 Stage Summary 7 Design Worksheet 8 Fann 35 QC 9 Lab QC 10 Sand QC 11 Treatment Plots 12-13 Chemical Plots 14 Net Pressure Plots 15 TOC Page 2 m a) no m a m C 1D<M CO FIN N W 10 A, n'w OOa 8 O co n oo d co e-.-O) O. O) CO —CO el N CO U) Y m a) a V 7 V N I- U) U)r) 10 N CO CO7 d a y m m m m m m m a. OA C) O) W 0 O) O) 0 co LO O O O o o U) CO A =m d O GI O `. a a v E )o ri o to Ill ` ' Z. > r) o d I UO) O d > � H d y d rn to a F- co o ELo N A co > m )n c 0 co co O d E N 03 N m R P 2 N O O O N F x 2 c H c 2 m I m m 7 C .0 ao H d L 21 E yv io o a F" N p N N C 2 2N5 a an an i O 21 2 a) 0 •. LL U O O - ^r m C r E OS # N ` d O co Q d . N C fn =n o Aad ac u 1 N ODN O 2 E U) l0 10 a v v m t m U- aCL d Li_ O d r-- 0. a0 A d a) 7 aa)) o In a N F c 0 u U U N ' N N 132 O K y O 7 LI- E U N J co N co a. O p m N N V N N - d O = N o U+ m U) O N C p) V O o d V y t O) O CD To o) CO r) m a N N U d Z N > C 0-fn l-- N_ d o 5 D O N 0 CO azOv)N # N I- 0 C C 0 d O N E ', O W d a €0 a a R O U J Q 0 E F HALLIBURTON Engineering Executive Summary On 02/27/13 a stimulation treatment was performed in the Nuiqsut formation on the ODSN-29- Part 1 -Zones 1-2 well. The following information was gathered during the treatment. Sales Order#: 900249706 API#: 50-703-20642 25#Hybor G Volume: 110,964 gal 2642 bbls 25#Water Frac G Volume: 2,472 gal 59 bbls Freeze Protect Volume: 400 gal 10 bbls End Hydro Strap Volume: 25,200 gal 600 bbls Total Fluid (Used): 113,836 gal 2710 bbls Clean Fluid Downhole (No Hydro or LVT): 88,236 gal 2101 bbls Carbolite 16/20 Pumped: 296,900 lbs Formation: Nuiqsut Total Stim-Sleeve Zones: 9 Total Zones: 9 Net Pay Interval: 5519 ft Average Rate: 45.2 bpm Average Pressure: 5805 psi Maximum Rate: 57.9 bpm Maximum Pressure: 8534 psi Maximum Horsepower: 9309 HHP Average Visc: 22.5 cp Average pH: 9.9 Average Temp: 62 deg F BE-6 Pre-treated in tanks: 60 lbs (0.15 ppt) Prior to pumping the job, Quality Control tests were conducted on location to determine hydration time, crosslink time, and gel viscosity. Chemical concentrations were adjusted, as needed, according to test results, pump times, and onsite water. We appreciate the opportunity to service your well. If you have any questions about the job, or anything else, please call me at(435) 621-2192. Thank you, Johann Baltrusch Caitlin McCarthy Technical Professional Technical Professional Halliburton Energy Services Halliburton Energy Services Executive Summary Page 4 Treatment Information Zone 1 Zone Summary Initial Rate (Breakdown): 29.7 bpm Initial Pressure (Breakdown): 7251 psi Max Rate: 54 bpm Max Pressure: 7,231 psi Average Rate: 46 bpm Average Pressure: 6,136 psi Max Horsepower: 9309 hhp Average Visc: 21 cp Average pH: 10 Average Temp: 60 F Carbolite 16/20: 169,500 lbs Total Proppant Pumped: 169,500 lbs Proppant in Formation: 169,500 lbs 25#Hybor G Volume: 60,795 gal 1448 bbls 25#Water Frac G Volume: 0 gal 0 bbls Freeze Protect Volume: 400 gal 10 bbls Comments: Found that sand screws were not keeping up and adjusted them. Extended the sand stage due to getting the proper amount of proppant in formation. Scalesorb locked up in the Dry Additive hopper; none was ran on this zone Executive Summary Page 5 Zone 2 Zone Summary Initial Rate (Breakdown): 42.4 bpm Initial Pressure (Breakdown): 5356 psi Max Rate: 58 bpm Max Pressure: 8,534 psi Average Rate: 45 bpm Average Pressure: 5,474 psi Max Horsepower: 8570 hhp Average Visc: 24 cp Average pH: 10 Average Temp: 64 F Carbolite 16/20: 127,400 lbs Total Proppant Pumped: 127,400 lbs Proppant in Formation: 90,100 lbs 25# Hybor G Volume: 50,169 gal 1195 bbls 25#Water Frac G Volume: 2,472 gal 59 bbls Freeze Protect Volume: 0 gal 0 bbls End Hydro Strap Volume: 25,200 gal 600 bbls Comments: As 4 ppg hit formation; pressure increased and kicked the trucks out. Proppant concentration was reading off the inline densometer and was reading incorrectly, even though no sand was being ran. This was confirmed by going bypass on the blender. Did not get much fluid cleaned out of the lines. Placed 90,100 lbs in formation, leaving 37,300 lbs in the wellbore, which settles out to 4,500 ft. Placed 42% of designed sand in formation. Executive Summary Page 6 ® \\ \� \\ f! f5 |-18#\ ,c°, , J 1,,741 {®°) \!° ) {2e. ;l : : ) -!! § oloS :6. ) ! _ — ;| , \) w®\} w! \\ 2 _ _ 0 SF ■ ] \ . \ 4 I � .g !\_ _ �y `\, \� ® / `4 ;; ; | !.� )!f ! ssssaaeaassasss 1,411g 3—" ssssss8saaeae �� 88888868888888 ya4ig a00000000aa00000 m_aaa� doodddddododd g= '!R!RR!!!!!$RR msaeld $$33$$$000000 o m£R0l d d d d d d d d d d d d d f— d" -0000000000000 =:xf 9ddddddddd000a tll zg AR n m F E E 3 8 0 tl "m � rv: >>d> a ' a 22g,et ME � 2:4, rvm 2iiii oo! _qA aa'" r, '1 E .. . �i u RR.^ :..$gpnnrvnnR NSPssssssgr.sssss a dot 4mem F. 9 1111 BSBs sss c a c c 3888 8 8 E" � 1111 g 11)1 11 t� :113313 .1x 14 ••ry a n .. . o Z,;„ doz L P �O" ct. 000OOOOM ^ s , ,11-4 mi-Eff-t-ExI LLB�'nnn�aa��aaa39 v@ W rvme�enm "aaa" HALLIBURTON I Enhnncelmenc WI11/Ion Ica OI1MnlI1)5 Fluid System: 25#Hybor-G I Testing done by: Caitlin McCarthy Customer:i Pioneer Natural Resources Date: 2/25/2012 Well Name ... Well Number:;_ 005N-29-Part 1-Zones 1-2 Well Location" Nuiqsut ND(ft)1_ ' MST(F) _..... Water Used; 11511)1)1 Si65 Test# 1 2 3 4 5 Water Analysis: Chemical units Chemical Concentrations Temp(F) -® gpt 0.6 0.6 --- 0.8 0.8 0.8 pH- CL-22 gpt Ir 1.80 1.80 0.90 __ 0.9 0.9 Chlorides(mg/L)- SP ppt 12.00 2.00 2.00 0 0 Carbonates(mg/L)NIIIIIIIIIIIII O•tiflo II ppt i--- 2.00 4.00 2.00 2 2 Bicarbonates(mg/L)- • gpt 0.50 0.50 0.50 0.5 0.5 Iron(mg/L)- BE-7 gpt 0.25 0.25 0.25 0.25 0.25 Sulfates(mg/L)- Losurf gpt 1.00 1.00 1.00 1 i 1 Calcium(mg/L)- MO-67 gpt 0.60 0.60 0.70 0.8 0.8 Magnesium(mg/L) WG-36 ppt 25.00 25.00 25.00 25 25 Potassium(mg/L), ScaleSorb ppt ti_ 100 100_ Conductivity(p5/cm)MMIIIIIIIIIIIM . TDS(mg/L)1. _. -- Specific Gravity: 1.1.111111111111111M1 -- Sodium(mg/L)_... .. Reshivity(Om)I _� I LUID PROPER I IES Test# 1 2 3 4 5 Gel Hydration Water pH 7.84 7.84 7.84 7.84 7.84 Min Visc(cP) Temp(F) ---ttt Base Gel(#). 25 25 25 ... 27 25 __. 1 ! 9 65 Base Gel Visc(cP) 23 23 19 23 21 6 I 20 65 _.'JJiI Base Gel pH 8.07 8.07 _ _ , 7.79 _ 7.64 7.64 12 i 23 l 65 Base Gel Temp(F) 65 59 I 60 65 65 _ _ _ __ _ Gel Hydration Crosslink pH 10.01 10.2 10.15 9.2 9.8 Min Visc(cP) Temp(F) Final pH 1 5 60 Test Temp(F) 150 150 150 150 150 _ 5 11 60 Break Time(hr:min) 0:30 0:25 0:20 0:55 1:15 10 19 60 Fann 35 Break Chart 4250 160 4000 I I 1 3750 140 I 3500 3250 -120 3000 2750 , I -100 I -0811 2500 �Vim2 E -0103 2250 r ! a Vkc0 80 C 12000 r 1 VI.5 1 r -re„1 1 1750 1 ---Temp ���Temp 3 1 -60 1500 Tempa 1 1 Temp 1250 1 i 140 1000 , a 1 1 1 750 1 1 500 1 -20 `®1 1 1 250 - 1 1 1 0 00 0 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100 105 110 115 120 125 130 135 140 145 150 155 160 165 170 175 180 185 190 195 200 lime(min) Fann 35 QC Page 9 .1011 I\FORMATION AND TESTING('ONDITIONS Customer: Poineer Fluid System: Hybor G Bob Type: BSX Well Name: C'onocco Shear Rate(1/sec): 40 Date: 9;21;12 Lab Project ID: S0178 Test No: 1 2 3 5 - ') 10 Water Analysts Chemical Units Chemical Concentrations Sample ID:W0136 WG-36 ppt 25.00 25.00 25.00 25.00 Bicarbonate(m¢2.) 152.5 LoSurf 300D rpt 1-00 1.00 1.00 1.00 Calcium(1ng/L) 308.80 MS S-2510T gpt 0.50 0.50 0.50 0.50 Carbonate(m¢'L) 0.00 MC B-8625 gpt 0.25 0_25 0.25 0.25 Chloride(mgt) 13054.00 Cla-Web gpt 0.50 0.50 0.50 0.50 Conductivity(it S cm) 35000.00 Iron(mg%L) 0.70 CL-22CC gpt 0.90 0.90 0.90 0.90 Magnesium(m¢21) 933.10 CL-31 gpt 0.30 0.30 0.30 0.30 pH 7.27 MO-67 gpt 1 50 1.50 1.50 1.50 Potassium(mg:L) 370.00 Opti-11 ppt 2.00 3.00 4.00 4.00 Resistivity(S2-m) 0.00 SP Breaker ppt --- - •- 2.00 Sodium(nig.-1_14- 7097.00 Specific Gravity 1.021 Sulfate(mg,L) 1900.00 TDS(ma/Lr 23100.00 Temperature(SF) 71 •ca)rulared values FIA ID PROPERTIES Test No: 2 3 5 Gel Hydration(Sills) Water pH 7.27 7.27 7.27 7.27 Mm. V scosity(cP) Temp.(oF). Base Gel(e) 25 25 25 25 1 _ 10.0 71 Base Gel Vise(cP) 20.0 20.0 20.0 20.0 3 15.0 71 Base Gel pH 7.40 7.20 7.20 7.40 6 19.0 71 Base Gel Temp.(°F) 70 71 71 70 9 19.0 71 12 19.0 71 Crosslink pH 10.15 10.18 10.70 10.19 Final pH 9.42 9.71 9.68 8.98 Test Temp.(°F) 160 160 160 140 Break Time(hr:min) 105 0:25 0:20 Test Notes. BREAK TEST CHART Vac 1 Vic 2 -Mae3 Vee4 ________ -------------- �� p•••Ta1........Terap 2.. ....... 200 Temp 4 LAW \.....:31;\\)1,s.--........4esc.••• � 1100 1000 •+--------. 1^5 900 •+� - .-- 152°5 50 i' 800 +• - • . *4 i� 12s 600 h t 500 /047,0 � ,, \,.... 100 400 it .s......: 300 ! 200 -- 100 ------- ___ _- _-________- 50 0:00 0:10 0:20 0:30 0:40 0:50 1:00 1:10 FLpmd Tru.hr:min Lab QC Page 10 Customer: Pioneer Natural Resources Well: ODSN-29-Part 1-Zones 1-2 HALLIBUATON Date: 2/27/2013 E do �m. Formation: Nuiasut Ticket#: 900249706 Sand Type Carbolite 16/20 Pan Size 6641 Bin 2 6641 Bin 1 3838 Bin 1 _ 3838 Bin 2 3838 Bin 3 Wt. % Wt. % Wt. % Wt. % Wt. / % Pan#12 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan#16 3.5 3.5% 2.4 2.4% 5.2 5.3% 6.5 6.6% 3.1 3.0% Pan#18 67.2 67.6% 56.4 56.5% 59.9 61.5% 68.0 68.5% 71.2 68.9% Pan#20 28.6 28.8% 40.8 40.9% 28.3 29.1% 24.6 24.8% 28.8 27.9% Pan#25 0.1 0.1% 0.2 0.2% 0.2 0.2% 0.1 0.1% 0.2 0.2% Pan#30 0.0 0.0% 0.0 0.0% 0.1 0.1% 0.0 0.0% 0.1 0.1% Pan 0.0 0.0% 0.0 0.0% 3.7 3.8% 0.0 0.0% 0.0 0.0% Total 99.4 100.0% 99.8 100.0% 97.4 100.0% 99.2 100.0% 103.4 100.0% Retained 96.5% 97.6% 90.8% 93.4% 96.9% Sand Type Carbolite 16/20 Pan Size 3838 Bin 4 Comp 2 Comp 3 Comp 4 Comp 5 Wt. % Wt. % Wt. 1 % Wt. % Wt. % Pan#12 0.0 0.0% #DIV/01 #DIV/01 #DIV/0! #DIV/01 Pan#16 6.1 6.1% #DIV/01 , #DIV/01 #DIV/01 #DIV/0l Pan#18 74.0 74.4% #DIV/01 #DIV/01 #DIV/01 #DIV/0l Pan#20 19.4 19.5% #DIV/01 #DIV/01 #DIV/0l #DIV/0l Pan#25 0.0 0.0% #DIV/01 #DIV/01 #DIV/01 #DIV/0l Pan#30 0.0 0.0% #DIV/01 #DIV/01 #DIV/01 #DIV/0l Pan - 0.0 0.0% #DIV/01 #DIV/01 #DIV/01 #DIV/0l Total _ 99.5 100.0% 0.0 #DIV/01 0.0 #DIV/01 0.0 #DIV/01 0.0 #DIV/0l Retained 93.9% #DIV/0l #DIV/01 #DIV/01 #DIV/01 Sand Type Ottawa 20/40 Pan Size Com 3 1 Comp 2 Comp 3 Comp 4 Comp 5 Wt. % Wt. % Wt. % Wt. % 4 Wt. % Pan#16 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan#20 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan#30 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan#35 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan#40 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan#50 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan 0.0 100.0% 0.0 100.0% 0.0 100.0% 0.0 100.0% 0.0 100.0% Total 0.0 100.0%_ 0.0 100.0% 0.0 100.0%_ 0.0 100.0% 0.0 100.0% Retained 0.0% 0.0% 0.0% 0.0% 0.0% Sand QC Page 11 Treating Chart-Zone 1 Treating Pressure(psi) A Slurry Rate(bpm) B A BH Proppant Conc(lb/gal) C Slurry Proppant Conc(lb/gal) C B C 8000 80 -16 700041 -70 -14 6000- -60 -12 ill - 5000- 1 -50 -10 4000- -40 -8 • I 3000 4,_30 -6 t 2000 I -Iff► 4-20 -4 1000- 10 =2 411‘ ® 0 E$ el ® 1920 1930 19:40 19:50 20:00 20:10 2020 2030 20:40 2050 2/27/2013 2/27/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 26-Feb-2013 Sales Order#: 900248831 INSITE for Stirnletian v4.4.0 Well Description: ODSN 29 UWI: 50-703-20642 10-Jun-1314:17 Treating Chart-Zone 2 Ball Drop Treating Pressure(psi) A Slurry Rate(bpm) B A BH Proppant Conc(lb/gal) – C Slurry Proppant Conc(lb/gal) C B C 8000 80 –16 7000– –70 –14 6000- -60 -12 5000- 50 -10 • 4000- -40 -8 41 3000- -30 -6 / _ _ 2000- 4 +\ -20 74 l000 –10 –2 0 — __ _ — 0 –0 20:45 20:50 20:55 21:00 2/27/2013 2/27/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 26-Feb-2013 Sales Order#: 900248831 INSITE for Stirr laban v4.4.0 Well Description: ODSN 29 UWI: 50-703-20642 10-Jur-131520 Treatment Plots Page 12 Treating Chart-Zone 2 Treating Pressure(psi) A Slurry Rate(bpm) B BH Proppant Conc(lb/gal) C Slurry Proppant Conc(lb/gal) C A B Actual BH Temp(°F) D Gauge BH Pres(psi) A C D 12000- 80 1 16 160 • 10500- 70- 14 140 9000- 60- -12 120 7500- 50- -10 100 I 6000- 40- -8 80 :°: : - - 1 -6 60 - 1 JA01 , -4 0 1500- 10- -2 20 0- 0 , , , , , , , , , , , — - �1 "� 0 0 2050 21:00 21:10 2120 2130 21:40 21:50 22:00 2/27/2013 2/27/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 26-Feb-2013 Sales Order#: 900248831 Well Description: ODSN 29 UWI: 50-703-20642 Ns� imro o€ t Treatment Plots Page 13 I Chemicals -Zone 1 WG-36 Conc(Ib/Mgal) A Losurf-300D Conc(gaVMgal) B CLA-Web Conc(gaVMgal) B MO-67 Conc(gal/Mgal) B CL-22 UC Conc(gaVMgal) B CL-31 Conc(gal/Mgal) B ScaleSorb 3 Conc(Ib/Mgal) C Optiflo-II Conc(Ib/Mgal) A A SP Breaker Conc(Ib/Mgal) A BE-7 Conc(gaVMgal) B B C 30 1 4 10 -9 fIsrr ' "r 11111 8 _ �� 3 20- -7 -6 cr) , 15- __ -2 -5 .R Q -4 >- 10- __ - -3 1 5- rl i 00 tiP11111041111MNiimio 1 0• r il1 , , r , i t r ,-" r ti F-, -� 0 -0 19:30 19:40 19:50 20:00 20:10 20:20 20:30 20:40 2/27/2013 Time z/z7/2oi 3 Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 26-Feb-2013 Sales Order#: 900248831 Well Description: ODSN 29 UWI: 50-703-20642 I Chemicals -Zone 2 1 WG-36 Conc(Ib/Mgal) A Losurf-300D Conc(gaVMgal) B CLA-Web Conc(gal/Mgal) B MO-67 Conc(gaVMgal) B CL-22 UC Conc(gaVMgal) B CL-31 Conc(gaVMgal) B ScaleSorb 3 Conc(Ib/Mgal) C Optiflo-Il Cone(Ib/Mgal) A A 1 SP Breaker Conc(Ib/Mgal) A BE-7 Conc(gaVMgal) B B C 30r A�, f 4 -10 ::1 6 7 co 15- -2 -5 .N Q - -4 >- 10- I3 ^w •III.w�w wIII ww'nww r+.. imy,11*lam 1 - I 1 gA..' I' fi -2 5 itI1 . - ,, 1 ��Q 11,IMAM � 1 -1 0 1i - MI I 0 -0 20:50 21:00 21:10 21:20 21:30 21:40 21:50 2/27/2013 2/27/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 26-Feb-2013 Sales Order# 900248831 Well Description: ODSN 29 UWI: 50-703-20642 1 Chemical Plots Page 14 Net Pressure Plot -Zone 1 -Net Calc'd BH Pres(psi) A Time NetPr BPC Slope -BH Proppant Conc(lb/gal) B 0 682.51 0.000 5.435 0.000 A Slope of Net Pressure(psvmin) C B 100008- 20 Closure Pressure=2800 psi 7 e_ -18 5- 4 -16 3- 14 2- 12 10008 -10 8 7 6_ -8 5_ • 4 -6 3- -4 2- -2 0 Time=02/27/13 20:12:38 1001 2 3 4 5 6 4 0 7 8 9 10 2 3 Time(min)(0= 1212.633333) Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 26-Feb-2013 Sales Order#: 900248831 Well Description: ODSN 29 UWI: 50-703-20642 Net Pressure Plot-Zone 2 -Net Calc'd BH Pres(psi) A Time NetPr BPC Slope -BH Proppant Conc(lb/gal) B CD 682.51 0.000 5.435 0.000 A Slope of Net Pressure(psi/min) C B 100008 20 Closure Pressure=3800 psi 7 6 18 5 4 16 3 14 2 12 10009 10 8 7 6 8 5 4 6 3 4 2 2 ! Time=02/27/13 20:12:3: 100 4 0 5 6 7 8 4 100 Time(min)(0= 1212.633333) Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 26-Feb-2013 Sales Order#: 900248831 Well Description: ODSN 29 UWI: 50-703-20642 Net Pressure Plots Page 15 Job Log 1:30 AM 3:30 AM Crew perform post frac cleanup 4:00 AM 12:00 Crew off for rest 12:30 PM Post job safety meeting 1:00 PM 4:30 PM Crew perform post frac cleanup Meeting with Pioneer regarding Post-Frac analysis. Went over lessons learned and what to work on 1:15 PM 4:45 PM before the next frac. 6:00 PM 9:00 PM Crew working on getting ready for next frac. February 25,2013 9:00 PM 5:00 AM Crew off for rest;Wakeup and eat Breakfast 5:00 AM 6:00 AM Wake up and eat Breakfast 6:00 AM 6:30 AM Morning Safety Meeting 6:30 AM 11:00 AM Entire Crew worked on wet side to set up from 20 bpm to 60 bpm 11:00 AM 11:30 AM Lunch 11:30 AM 6:00 PM Finish rigging up blender,hydro,and ADP 5:00 PM 2 pumps that had been in town getting fixed arrived at location. 6:00 PM 7:00 PM Dinner 7:00 PM Pump arrived back from OTP from being repacked. 7:00 PM 8:30 PM Meeting with Pioneer regarding crew and morale over last 2 weeks. 10:00 PM 11:00 PM Cleanup 1 cup spill of Glycol from Webasto Cleaned and reported. February 26,2013 5:00 AM 5:45 AM Wakeup and eat Breakfast 6:00 AM 6:30 AM Morning Safety Meeting 6:30 AM 11:00 AM Split into groups to tackle the remaining items for the day 11:00 AM 12:00 PM Lunch 12:00 PM 4:30 PM Finish working on the following: check primeup hook up 3 pumps hook up second 4 inch line connect to wellhead 4:00 PM 4:30 PM Spot Peak LVT Transport 5:00 PM 5:10 PM Flood lines with LVT for pressure test 5:00 PM 6:00 PM Break for dinner ODSN-29 6:00 PM 6:30 PM Pre Job Safety Meeting. SO# 6:30 PM 8:30 PM Bucket Test 900249706 8:30 PM 9:10 PM Prime up with LVT Zones 1-2 9:10 PM 9:25 PM Had pressure build on the primeup line;shut down to trace. 9:25 PM 9:55 PM Replace primeup line Try again;still caught pressue on the lines. Crew found ice in the missile from the previous job that 9:57 PM 10:27 PM hadnt been entirely sucked out due to flushing at a lower rate. 10:30 PM 10:45 PM LVT strap came in at 35 bbls left;shut down to figure out where the fluid went. 10:45 PM 11:15 PM Found out that the Hydro had LVT in it;shut down for the night to figure it out. February 27,2013 11:15 PM 3:30 AM Clean out the missile and suck ALL of the LVT back into the transport 3:30 AM 11:00 AM Crew off for sleep 11:00 AM 12:00 PM Wake up and Lunch 12:30 PM 1:15 PM Crew Safety Meeting 1:15 PM 3:00 PM get ready for crew change and get as much done before as possible 3:00 PM 4:00 PM Crew changeover meeting 4:00 PM 4:30 PM Pre Job Safety Meeting. 6:25 PM 7:00 PM Pressure test to 9000 psi 7:15 PM Open wellhead 7:23 PM Start Job 7:26 PM Open Sleeve 1 Max 5898 psi;differential: 3804 psi 7:28 PM shut down to fill Hydro 8:04 PM Resume Pumping after visc was building and everyone was ready to ga. 8:15 PM 8:40 PM Could not get DA3 running(ScaleSorb).It plugged off midway up the screw. 8:20 PM Lost a discharge hose on the 3843 pump 8:43 PM Drop Zone 2 Ball 8:52 PM Zone 2 ball hit 3 sleeve shifts 1656 psi;964 psi;and 963 psi 9:10 PM Scalesorb started running;got a Rate increase but no pressure;no info why 9:15 PM Scalesorb hit bottom;pressure turned up and went towards a screenout 9:20 PM 10:00 PM Well Screened out;could not get back into it. Left 37300 lbs in the wellbore;placed 90100 lbs in formation. Plan is to rig over to the 47 well and try to pump it 3/2/13 Job was tracking off the inline;blender denso was not reading properly. Tub was in bypass;still saw 9:20 PM 9:30 PM proppant concentration;do not know why 10:00 PM 10:00 PM End ODSN 29;SO#900249706;Start ODSN 47;SO# 900262042 Pioneer Natural Resources Treatment Summary ODSN-29 Part 2 - Zones 3-5 Alaska Section 11 Township 13N Range 7E API #: 50-703-20642 Nuigsut 30# Hybor-G March 9, 2013 SO# 900248783 HALLIBURTON HALLIBURTON Production ment Table of Contents Section Page(s) Cover Sheet 1 TOC 2 Wellbore Information 3 Executive Summary 4-8 Stage Summary 9 Design Worksheet 10 Fann 35 QC 11 Lab QC 12 Sand QC 13 Treatment Plots 14- 17 Chemical Plots 18- 19 Net Pressure Plots 20 TOC Page 2 m a 00 )a o_ = V CO N C) ooi6 U •._-, N OCC 0) te A cc A Crc 1-O) 'To �Np t v N N N Q ^ N CO 0 N tl) CO O co I� G CO N .-p a, ,-,- 6: ala u'1 co M N- O CD 0 Cn. r M D) `O 0 10 0 t0 0 0 t0 R 0) 01 CO 0) 0) 0) 0) 0) CO CO 0 0 0 0 0 CO • LO T—, V tT N O D) O R ZOO ei v E tD c•-; O Li' M N _ N O W > d o co y • u) O) M N to I M N CO N 0 N. V F CO n V Lo C')N to a a) o0Ov O n no Q E N CO co u) Cr) 7 N. N 0 M el N C 2 t0 R in 7 o E y N N O N 1- 1-1- £ O. 7 O 43N 2 a O H O a ~ c 2 C O To = co m E _ j —. — M CO N M y O Ch O F E iii r �Or; v x N F N r.uio 2NO)° " a o A T o g MM a) = LT0 0 A x LL 2 m 0) E I-- at tD N'Q M N O O a 2 st D C ~ y` #IN m * 7 (0te 1 CD CO COC 0 oi T NA F - = corl 1x E to n A 0 v v a .0 m LL 6 7 O) LL Q _ d M 0 N CD N CO N.N 713 N ci r O ,-- N N O N ci ~ OC J 7 . r. C ~ t0 .a fA D C 7 O t) a, V d 2 0 to in V CO r O a R O O m:: Q O JO N N d 00 co C.I, m 0 8 a m 0 c o a o C N O -- ao co .a.r•- N N V- r N- N )+ 01 CO N n CONI. m co CO O m d o E m Z N 0 N M v 0 t6 C0 at Q'in O O J O O, 01r N _!_d dZ0)nm � � ik co N 7 M N C C 0 O 0 N t 2 w, d • ma m O LL J Q 0 HALLIBURTON Engineering Executive Summary On 03/09/13 a stimulation treatment was performed in the Nuiqsut formation on the ODSN-29 Part 2 - Zones 3-5 well. The following information was gathered during the treatment. Sales Order#: 900248783 API#: 50-703-20642 30# Hybor G Volume: 246,544 gal 5870 bbls 30#Water Frac G Volume: 42,761 gal 1018 bbls Freeze Protect Volume: 2,763 gal 66 bbls End Hydro Strap Volume: 10,000 gal 238 bbls Total Fluid (Used): 302,068 gal 7192 bbls Clean Fluid Downhole (No Hydro or LVT): 289,305 gal 6888 bbls Carbolite 16/20 Pumped: 445,000 lbs Formation: Nuiqsut Total Stim-Sleeve Zones: 9 Total Zones: 9 Net Pay Interval: 5339 ft Average Rate: 37.2 bpm Average Pressure: 5651 psi Maximum Rate: 51.1 bpm Maximum Pressure: 8914 psi Maximum Horsepower: 9636 HHP Average Visc: 27.7 cp Average pH: 10.1 Average Temp: 70 deg F BE-6 Pre-treated in tanks: 36 lbs (0.15 ppt) LO-65 Pre-treated in tanks: 480 gal (2 gpt) Prior to pumping the job, Quality Control tests were conducted on location to determine hydration time, crosslink time, and gel viscosity. Chemical concentrations were adjusted, as needed, according to test results, pump times, and onsite water. We appreciate the opportunity to service your well. If you have any questions about the job, or anything else, please call me at(970) 773-0592. Thank you, Drew Mogck Caitlin McCarthy Technical Professional Technical Professional Halliburton Energy Services Halliburton Energy Services Executive Summary Page 4 Zone 3 Zone Summary Initial Rate (Breakdown): 16.53 bpm Initial Pressure (Breakdown): 3949 psi Max Rate: 45 bpm Max Pressure: 8,914 psi Average Rate: 26 bpm Average Pressure: 5,260 psi Max Horsepower: 9636 hhp Average Visc: 29 cp Average pH: 9.94 Average Temp: 65 F Carbolite 16/20: 0 lbs Total Proppant Pumped: 0 lbs Proppant in Formation: 0 lbs 30# Hybor G Volume: 20,638 gal 491 bbls 30#Water Frac G Volume: 36,471 gal 868 bbls Freeze Protect Volume: 2,763 gal 66 bbls Comments: Got injection up to 5 bpm and dropped ball for zone 3. Pumping ball down at just 5 bpm due to pressure. Pressure broke over around 12:19 it dropped about 4000 psi.After confirming there were no leaks anywhere we brought up rate to 15 bpm to seat the ball. Saw pressure response from the ball 4 bbls before it was expected to seat. Pressure increased from 2854 to 7872 and pumps kicked out. Got back in at 10 bpm, could not get sleeve to shift below 8000 psi. Shut in the well to reset our popoff to 9000 psi and tried to get back in and see if going to a higher pressure would help. Could not shift sleeve at 8913 psi. Made decision to shut down and freeze protect equipment at 13:20. Had a conference call with Pioneer and Baker Hughes reps to discuss what the plan would be on the sleeve. Decision was made to try to bleed off pressure from well to try to unseat ball and then try and get going and reseat it a couple of times to see if we couldn't shear the pins. We had already freeze protected with LVT at this point so we were going to pump in with that just to try this step. Started bringing up rate with LVT expecting to encounter pressure immediately, but only got to 5500 lbs at 7 bpm. Came back on at 5 bpm, pressure came up to 7000 and then broke over to around 3000 psi as if something had shifted. We continued bringing rate up and managed to get 45 bpm injection rate but were seeing about 7900 psi with the linear gel which was much higher than we should have been seeing for that rate. We shut down to have another conference call. On the call the decision was made to try to pump about 250 bbls crosslinked gel followed by linear to see if the crosslink would create any more geometry for us and give some pressure relief on formation. Pumping at 40 bpm with the xlink gel we did not see a significant difference from the linear gel and they determined that there was probably some sort of mechanical restriction causing the pressure. Ultimate decision was made to drop the next ball and shift the sleeve for zone 4 and finish the last two zones planned for today. Executive Summary Page 5 Zone 4 Zone Summary Initial Rate (Breakdown): 7.88 bpm Initial Pressure (Breakdown): 6251 psi Max Rate: 51 bpm Max Pressure: 7,720 psi Average Rate: 41 bpm Average Pressure: 6,368 psi Max Horsepower: 8358 hhp Average Visc: 27 cp Average pH: 10.17 Average Temp: 70 F Carbolite 16/20: 208,905 lbs Total Proppant Pumped: 208,905 lbs Proppant in Formation: 208,905 lbs 30# Hybor G Volume: 96,481 gal 2297 bbls 30#Water Frac G Volume: 4,248 gal 101 bbls Comments: Dropped ball at 20 bpm and brought up rate to 40 bpm, planning to drop rate 50 bbl before ball would hit. Ball hit 60 bbls early and kicked the pumps out. After the ball hit only got rate to 10-15 bpm for about 20 minutes due to significantly increases pressure. Around 18:30 the pressure dropped from 7500 at 17 bpm to around 2800 psi. At this point we began grabbing rate and the formation seemed to be acting more normal. Customer made call to extend pad another 400 bbls from this point and then pump job as designed. From this point on the zone pumped to completion with minimal issues. Executive Summary Page 6 Zone 5 Zone Summary Initial Rate (Breakdown): 19.82 bpm Initial Pressure (Breakdown): 2864 psi Max Rate: 46 bpm Max Pressure: 7,465 psi Average Rate: 44 bpm Average Pressure: 5,325 psi Max Horsepower: 8246 hhp Average Viso: 27 cp Average pH: 10.23 Average Temp: 75 F Carbolite 16/20: 236,095 lbs Total Proppant Pumped: 236,095 lbs Proppant in Formation: 236,095 lbs 30# Hybor G Volume: 129,425 gal 3082 bbls 30#Water Frac G Volume: 2,042 gal 49 bbls End Hydro Strap Volume: 10,000 gal 238 bbls Comments: Did not see pressure response from the ball. After pumping -200 bbls past where the ball should have hit decision was made to shut down and drop the backup ball. Dropped the backup ball and after 300 bbls saw no response. Went back and looked closer at graphs and found a minimal increase around the time the first ball should have hit and decision was made to pump the zone assuming the sleeve had shifted. Pumped to completion. Some snow/ice that was compacted in bottom of hopper caused some issues getting the blender up to 6 lb sand until it was pushed past the grates. Executive Summary Page 7 Zone 6 Zone Summary Initial Rate (Breakdown): 20.4 bpm Initial Pressure (Breakdown): 6382 psi ISI P: 2683 psi Initial Fracture Gradient: 0.86 psi/ft Comments: Dropped and seated ball for zone 6 before shutting down. Volumes accounted for in zone 5 Executive Summary Page 8 ! 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Do O 0000 000000 000000 0 d ^'"' , H TAFa' n n < a . a - S am Q Z w $ E E v 0 + man .. tuna , » 23 ? c - - I ' AtgEnn ^� aNB � rigr em ry oc d Ilk y r a - a d S a s l a3 aVg a w . o d� 0 ;8� e § A 8 , 8 O:I „ § § 4 ry L o EilEsssssse `323 $ 8Q8e ,S ,S $ s8 $ 8 $ R - 1 r8 08F8 088 .1222 2222 v o 68 ,: c CCCC CCCC t, E eH a N E 77, O t O O O d> _ c c = c = c d>7. . E E E y E L z N H o a u a n n u _ a n a _" ELA - yZ ry LL n ry n C z o. 45. 0= s c.oz E o x ossa � 3a3aossAAAAAs AAAAAA ra y E - A $ $ w 0 tm a 0 HALLIBURTON I Produionct snont WI II/105 INFORMATION Fluid System: 308 Hybor-G Testing done by: Caitlin McCarthy. Customer:' Pioneer Natural Resources Date: 3/8/2013 1 Well Name, Well Number:: ODSN-29 Part 2-Zones 3-5 Well Location: Nuigsut TVD(ft) BHST(F) 175 _ Water Used Water Sample from 3/8/13 II Ull DI SIGN '.s. 4 5 Water Analysis: Chemical units Chemical Concentrations Temp(F) 851 CL-31 gpt 0.5 0.5pH 8.28: CL-22 gpt 0.90 0.90 Chlorides(mg/L) _ 15,120, SPppt 2.00 Carbonates(mg/L) 0 Optiflo II _ ppt 2.00 4.00 _ ) Bicarbonates(mg/L) 166', Claweb gpt 0.50 0.50 1 Iron(mg/L) 0 BE-7 gpt 0.25 0.25 Sulfates(mg/L) 1,200 Losurf gpt 1.00 1.00 Hardness(mg/L) 4,800 MO-67 gpt 0.40 0.40 _ Potassium(mg/L) 16,000 WG-36 ppt 30.00 30.00_ TDS(mg/L) 43,000 L065 gpt 2 2 Specific Gravity: 1.022 • FLUID PROPERTIES Test# 1 2 3 4 5 Gel Hydration Water pH. 8.09 8.09 _ _ - Min Visc(cP) Tern. F Base Gel(#) 30 30 1 1.11111111111111111EMI Base Gel Visc(cP), 27 27. 3 -- Base Gel pH! 8.32 0.32IIIIIINIIIIIII 111111111111111111111 6 ®_�_ �, Base Gel Temp(F)' 72 ._. 72 _ _ . 1111111111111111.1111 9_ — 12 Miligill.11111111.3.11111 Crosslink pH 9.77 _ 9.91 _.. Final pH 9.2 4 8.92 _ • Test Temp(F) 150 150 Break Time(hr:min) 1:45 :35 Fann 35 Break Chart 4750 160 4500—- -_ - 1 4250 140 4000 - 3750 -120 3500 _ 3250 3000 100 I —Sac 1 2750 Visc 2 s —01,03 2500 t Visc 4 4p -80 a .$2250 —VIsc5 > H ---Temp 1 2000 1 ---Temp 2 I ---Temp 3 1750 -.. I -60 Temp 4 1500 oioio,Temps 1250 I I -40 1 1000 I 1 750 I I -20 500 1 1 I 250 I 1 I 1 0 0 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100 105 110 115 120 125 130 135 140 145 150 155 160 165 170 175 180 185 190 195 200 Time(min) Fann 35 QC Page 11 .IOR 1\FOR\TITION AND TESTING CONDITIONS Customer: Poineer Fluid System: Hybor G Bob Type: B5X Well Name: C'onocco Shear Rate(I/sec). 40 Date: 9/21:'12 Lab Pro ect ID: S0178 Test No: - 5 0 10 Water Analyst Chemical tnits Chemical Concentrations Sample ID:W0136 WG-36 ppt 25.00 25.00 25.00 25.00 I Bicarbonate(nlg'L) 152.5 LoSurf 300D rpt 1.00 1.00 1.00 1.00 Calcium(mitt) 308.80 MS S-2510T 1pt 0.50 0.50 0.50 0.50 Carbonate Ong/L) 0.00 MC B-8625 gpt 0.25 0.25 0.25 0.25 Chloride(ma!L) 13054.00 Cle-Web gpt 0.50 0.50 0.50 0.50 Conductivity()aSian) 35000.00 Iron(mg/L) 0.70 CL-221.7C: gpt 0.90 0.90 0.90 0.90 'Magnesium(maiL) 933.10 CL-31 gpt 0.30 0.30 0.30 0.30 pH 7.27 MO-67 gpt 1.50 1.50 1.50 1.50 Potassium(mita-) 370.00 Opn-II ppt 2.00 3.00 4.00 4.00 Resistivity(S2-in) 000 SP Breaker ppt --- - -- 2.00 Sodium(mg./1.)," 7097.00 Specific Gravity 1.021 Sulfate(mgt) 1900.00 TDS(m2'L)1 23100.00 Temperature(°F) 71 'rafulated values FLAIID PROPERTIES Test No: 2 3 5 . Gel Hydration(511/s) Water pH 7.27 7.27 7.27 7.27 MM. Viscossty(cP) Temp.(oF), Base Gel(#) 25 25 25 25 1 10.0 71 Base Gel Vise(cP) 20.0 20.0 20.0 20.0 3 15.0 71 Base Gel pH 7.40 7.20 7.20 7.40 6 19.0 71 Base Gel Temp.(°F) 70 71 71 70 9 19.0 71 12 19.0 71 Ci-osslink pH 10.15 10.18 1020 10.19 Final pH 9.42 9.71 9.68 8.98 Test Temp.(°F) 160 160 160 140 Break Time(hr:min) 0.25 020 Test Notes. BREAK TEST CHART -vac 1- ---V -V c2 -Vise 3 1 Vise 4 _-_ +2c Temp 1 ----Tempt, ...---Temp 3` Temp 4 1 '00 ILW t . 1100 __�--____--_ ___ r5 1000 900 �. ���. -_ __-____-_ - z 800 I , _ 156 700 i 600 1 4y 500 i ', • I • i siie 100 1:;' 1 _ 100 i -. , 200 f ` - "- 100 0 -_--_.____----_-__� "�_� _- ---------- - 50 0:00 0:10 0:20 0:30 0:40 0:50 1:00 1:10 Elapsed Time.br:min Lab QC Page 12 Customer: Pioneer Natural Resources Well: ODSN-29 Part 2-Zones 3-5 WALLIBURTON 1 E ;:..r Date: 3/9/2013 ����d4`: Formation: Nuiqsut Ticket#: 900248783 Sand Type Carbolite 16/20 Pan Size Comp 1 Comp 2 Comp 3 Comp 4 Comp 5 Wt. % Wt. % Wt. % Wt. % Wt. Pan#12 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan#16 3.5 3.5% 2.4 2.4% 5.2 5.3% 6.5 6.6% 3.1 3.0% Pan#18 67.2 67.6% 56.4 56.5% 59.9 61.5% 68.0 68.5% 71.2 68.9% Pan#20 28.6 28.8% 40.8 40.9% 28.3 29.1% 24.6 24.8% 28.8 27.9% Pan#25 0.1_ 0.1% 0.2 0.2% 0.2 0.2% 0.1 0.1% 0.2 0.2% Pan#30 0.0 0.0% 0.0 0.0% 0.1 0.1% 0.0 0.0% 0.1 0.1% Pan 0.0 0.0% 0.0 0.0% 3.7 3.8% 0.0 0.0% 0.0 0.0% Total 99.4 100.0% 99.8 100.0% 97.4 100.0% 99.2 100.0% 103.4 100.0% Retained 96.4% 97.4% 90.6% 93.3% 96.7% Sand Type Carbolite 16/20 Pan Size Comp 1 Comp 2 Comp 3 Comp 4 Comp 5 Wt. % Wt. % Wt. % Wt. % Wt. % Pan#12 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% #DIV/0! Pan#16 6.1 6.1% 7.6 7.5% 8.6 8.3% 9.3 9.1% #DIV/0! Pan#18 74.0 74.4% 67.1 66.9% 78.3 75.8% 70.7_ 69.4% #DIV/0! Pan#20 19.4 19.5% 25.5 25.4% 16.4 15.8% 21.8 21.4% #DIV/0! Pan#25 0.0 0.0% 0.2 0.1% 0.0 0.0% 0.0 0.0% #DIV/0! Pan#30 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% #DIV/0! Pan 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% #DIV/0! Total 99.5 100.0% 100.3 100.0% 103.2 100.0% 101.8 100.0% 0.0 #DIV/0! Retained 93.9% 92.3% 91.7% 90.9% #DIV/01 Sand Type Carbolite 16/20 Pan Size Comp 1 Comp 2 Comp 3 Comp 4 Comp 5 Wt. % Wt. % Wt. % Wt. % Wt. Pan#12 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% #DIV/01 Pan#16 4.5 4.5% 4.4 4.3% 4.8 4.8% 6.3 6.1% #DIV/0! Pan#18 63.3 63.3% 63.9 63.5% 58.7 59.0% 74.4 72.8% #DIV/0! Pan#20 31.9 31.9% 32.1 31.9% 35.6 35.7% 21.4 20.9% #DIV/0! Pan#25 0.3 0.3% 0.3 0.3% 0.5 0.5% 0.1 0.1% #DIV/0! Pan#30 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% #DIV/0! Pan 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% #DIV/0! Total 100.0 100.0% 100.6 100.0% 99.5 100.0% 102.1 100.0% 0.0 #DIV/0! - Retained 95.2% 95.4% 94.8% 93.8% #DIV/0! Sand QC Page 13 Treating Chart -Zone 3 Ball Drop Attempt Treating Pressure(psi) A Slurry Rate(bpm) B BH Proppant Conc(lb/gal) C Slurry Proppant Conc(lb/gal) C A B Actual BH Temp(°F) D Gauge BH Pres(psi) A C D 12000— 80 16 —160 10500— 70— 1 —14 —140 9000— 60— di \/',C T —12 —120 7500— 50— —10 —100 ' ,..fik 6000— 40— l -8 —80 4500— 30 ��V// —6 —60 r 3000— 20- 1 —4 —40 srit 1500— 10—____40: 1 ' ,_2 —20 0— 0 , I 1 T T ? —0 —0 11:40 12:00 1220 12:40 13:00 1320 3/9/2013 3/9/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 09-Mar-2013 Sales Order#: 900248783 INSITE far Stirr latien 4.4.0 Well Description: ODSN 29 UWI: 50-703-20642 10-An-13 20:08 Treating Chart-Zone 3 Injection Attempts Treating Pressure(psi)- A Slurry Rate(bpm) B BH Proppant Conc(lb/gal) C Slurry Proppant Conc(lb/gal) C A B Actual BH Temp(°F) - D Gauge BH Pres(psi) A C D 12000- 80- -16 -160 10500- 70- I -14 -140 9000- 60- -12 -120 111 7500- 50- Al -10 -100 i 6000- 40- -8 -80 4500- 30- 1 -6 -60 3000- 20- II -4 -40 1500- 10- -2 -20 0- 071 , i r , 1- 0 0 15:00 1520 15:40 16:00 1620 16:40 17:00 3/9/2013 3/9/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 09-Mar-2013 Sales Order#: 900248783 INSITE for Stimulation s.4.4.0 Well Description: ODSN 29 UWI: 50-703-20642 10-Juo-1320.09 Treatment Plots Page 14 Treating Chart-Zone 4 Ball Drop Treating Pressure(psi) A Slurry Rate(bpm) B BH Proppant Conc(lb/gal) - — C Slurry Proppant Conc(lb/gal) C A B Actual BH Temp('F) D Gauge BH Pies(psi) A C D 12000— 80 1 16 160 10500— 70— —14 140 9000— 60— —12 120 7500— 50— I 10 100 6000— 40— I —8 80 1 4500— 30— —6 60 3000— 20— —4 '0 1500— 10J II 2 20 0— 0— , , i , , , , r--, , , , , , I , , , , 1 , , 1 r0 0 17:50 17:55 18:00 1805 18:10 18:15 3/9/2013 ,I, 3/9/2013 int Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 09-Mar-2013 Sales Order#: 900248783 INSITEfar Sna ill Ulatlon .4.0 Well Description: ODSN 29 UWI: 50-703-20642 f0 Jv f 320 f f 4k Treating Chart-Zone 4 Treating Pressure(psi) A Slurry Rate(bpm) B BH Proppant Cone(lb/gal) C Slurry Proppant Conc(lb/gal) C A B Actual BH Temp CO D Gauge BH Pres(psi) A C D 12000— 80 1 16 —160 10500— 70 1 —14 —140 - - —INr i 9000— 60— —12 —120 III 7500— 50 1 MIS op -10 —100 \ pp liellima .,,,,...taVek... 6000— 40 II —8 —80 4500— 30 '1 —6 —60 3000— 20 I —4 —40 f—.171(37114\141t I 1500— 10 ® ' r . —2 —20 0- 0 -, T . C7-7 1 4 ' I ---7""'''—" "r---- 0 —0 18:00 1820 18:40 19:00 19:20 3/9/2013 3/9/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 09-Mar-2013 Sales Order#: 900248783 INSITE for S Sbrrulabon s.4 4.0 Well Description: ODSN 29 UWI: 50-703-20642 10,11r1-13 20-12 Treatment Plots Page 15 Treating Chart- Zone 5 Ball Drop Treating Pressure(psi) A Slurry Rate(bpm) B BH Proppant Conc(lb/gal) C Slurry Proppant Conc(lb/gal) C A B Actual BH Temp(°F) D Gauge BH Pres(psi) A C D 8000- 80 16 -160 7000- 70- -14 -140 6000- 60-"''r � =12 =120 11- 5000- 50- -10 -100 4000- 40- 8 -80 3000- 30T-f -6 -60 2000- 20- rf l -4 -40 1000- 10- • r -2 -20 ,.., 0- 0 l 0 0 1920 19:30 19:40 19:50 20:00 20:10 2020 3/9/2013 3/9/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 09-Mar-2013 Sales Order#: 900248783 INSITE f°r Stmlatim W.4.0 Well Description: ODSN 29 UWI: 50-703-20642 10-Jin1315:02 Treating Chart-Zone 5 Treating Pressure(psi) A Slurry Rate(bpm) B BH Proppant Conc(lb/gal) C Slurry Proppant Conc(lb/gal) C A B Actual BH Temp(°F) D Gauge BH Pres(psi) A C D 12000- 80 16 -160 10500- 70- -14 -140 9000- 60- -12 -120 7500- 50- -10 -100 OW 6000- 40- 111111111i11111 1111 -8 -80 4500- 30 -6 -60 ii-j.\, i - - 3000- 20- ow I. 1 ~ I4 -40 t 1500- 10 • -2 -20 • • • • - 2020 20:30 20:40 20:50 21:00 21:10 2120 3/9/2013 3/9/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 09-Mar-2013 Sales Order#: 900248783 INSITE for Stimulation,A,4.0 Well Description: ODSN 29 UWI: 50-703-20642 10-Jvr1320:14 Treatment Plots Page 16 Treating Chart-Zone 6 Ball Drop Treating Pressure(psi) A Slurry Rate(bpm) B BH Proppant Conc(lb/gal) C Slurry Proppant Conc(lb/gal) C A B Actual BH Temp(°F) D Gauge BH Pres(psi) A C D 8000— 80 16 —160 7000— 70— —14 —140 6000— 60— \1/4---11"--1/ —12 —120 5000— 50— —10 —100 •, 4000— 40 —8 —80 3000— 30 n —6 —60 - - tr, �J - 2000— 20— —4 —40 1000— 10— —2 —20 411 • 0- 0 0 -0 21:15 21:20 2125 2130 3/9/2013 3/9/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 09-M ar-2013 Sales Order#: 900248783 INSITE for Stir,.l cn vt.4.0 Well Description: ODSN 29 UWI: 50-703-20642 10-An-13 15:05 Treatment Plots Page 17 Chemical Chart - Zone 3 Ball Drop MO-67 Cone(gal/Mgal) A Losurf--300D Conc(gal/Mgal) A CL-31 Cone(gal/Mgal) A CIA-Web Conc(gal/Mgal) A BB-7 Conc(gal/Mgal) B A Optifi one(lb/1M,, SP BreakerConc(Ib/Mgal) A WG-36 Conc(Ib/Mgal) B B 4 I i 50 !II°rj 1 4300 3— T 2— 1 1 1 '11 + (9. it —20 _.. I Il li' - 1 • ,', II , r,,1 ; ' -10 ,,,,Li, , hilili 11 �' f r 4 ���lil� 1 1111.111.I I , !IIIIIIFflii 1,1 II I ti� 0 r —tir +WL . ' , � I , , 0 11:40 11:50 12:00 12:10 12:20 12:30 3/9/2013 3/9/2013 Tim Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 09-Mar-2013 Sales Order#: 900248783 INSITE for Simulation 0120 Well Description: ODSN 29 UWI: 50-703-20642 10-Mar-1314:34 Chemical Chart-Zone 3 Injection Attempts MO-67 Conc(gal/Mgal) A Losurf-300D Cone(gal/Mgal) A CL-31 Conc(gal/Mgal) A CIA-Web Cone(gal/Mgal) A BE-7 Conc(gal/Mgal) B A ,,.,.;g1,. SP Breaker Conc(lb/Mgal) A WG-36 Conc(Ib/Mgai) B B 4 50 I MO 1 —40 3-- I�- i 0 —30 2_ ill - —20 —10 0 -, . ? „ „ 0 1530 15:40 15:50 16:00 16:10 1620 1630 16:40 16:50 3/9/2013 3/9/2013 Time 1 Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 09-Mar-2013 Sales Order#: 900248783 INSITE 1a Simulation 012.0 Well Description: ODSN 29 UWI: 50-703-20642 10-Mar-131437 Chemical Plots Page 18 I Chemical Chart-Zone 4 MO-67 Conc(gal/Mgal) A Los urf-300D Conc(gal/Mgal) A CL-31 Conc(gal/Mgal) A CLA-Web Conc(gal/Mgal) A BE-7 Conc(gaVMgal) B A s;; one SP Breaker Conc(lb/Mgal) A WG-36 Conc(lb/Mgal) B B 4 50 . 11 -40 3- I fel. I $044416"44441444.141/46Wilir kt4 -30 2- r -20 i 1 Awe,0.111 1 .---&—L--%.1,4.4.... ..-1411.0010...1.,y.....v.- 1 'OIL , -10 �, I I t1 a) L• 1 • l I I 0 A. , �L, ., jay .1,Y,,,,,.1 _i,I)lltll0., 0 18:00 18:20 18:40 19:00 19:20 19:40 3/9/2013 3/9/2013 I si Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 09-Mar-2013 Sales Order#: 900248783 Well Description: ODSN 29 UWI: 50-703-20642 I Chemical Chart-Zone 5 MO-67 Conc(gal/Mgal) A Losurf-300D Conc(gal/Mgal) A CL-31 Conc(gal/Mgal) A CIA-Web Conc(gal/Mgal) A BE-7 Conc(gal/Mgal) B A Opti' onc(Ib/Mgal) b SP Breaker Cone(Ib/Mgal) A WG-36 Conc(lb/Mgal) B B 4 - 50 -40 3- il v.„,,c. -30 2- _ -20 I I .., ""fl" Ir--A-4- ail -10 r..q.N.111.40 40/044.11100111/1011.41.11,111 ri/PY..f,.l 1 A l , r • I , 20:00 2020 20:40 21:00 2120 3/9/2013 3/9/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 09-Mar-2013 Sales Order#: 900248783 Well Description: ODSN 29 UWI: 50-703-20642 Chemical Plots Page 19 Net Pressure Plot-Zone 4 —Net Gauge BH Pres(psi) A Time NetPr BPC Slope —BH Proppant Conc(Ib/gal) B 0 50.95 4309 0.223 -0.210 A Slope of Net Pressure(psi/min) CB 10000 —6 Closure Pressure=5000 psi 6 5- -5 4_ • 3- 2_ -4 10009_ -3 8_ 7 6 5- -2 4- 3- 2_ -1 � r 0 Time 13/09/ 17:27: • • • - 100 e 3 0 100 Time(min)(0= 1047.166667) Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 09-Mar-2013 Sales Order#. 900248783 Wel Description: ODSN 29 LW: 50-703-20642 Net Pressure Plot-Zone 5 —Net Gauge BH Pres (psi) A Time NetPr BPC Slope —BH Proppant Conc(lb/gal) B 0 50.95 4309 0.223 -0.210 A Slope of Net Pressure(psi/min) CB 100008_ Closure Pressure=5000 psi 10 7- 5 -9 4- -8 2- -6 41* 10009_ rfl -5 6- -4 5- 4_ , 3 3- •� -2 2 ® -1 Arne=03/0P3 17:27:10 • ® • - 100 `0 Time(min)(0= 1047.166667) Custormr: PIONEER NATURAL RESOURCES-EBUS Job Date: 09-M3r-2013 Sales Order#: 900248783 Ad Description: ODSN 29 LIWi: 50-703-20642 Net Pressure Plots Page 20 7:00 PM 8:00 PM Break for dinner March 8,2013 8:00 PM 5:00 AM Crew off for rest 5:00 AM 6:00 AM Wake up and eat Breakfast 6:00 AM 6:30 AM Morning Safety Meeting 6:30 AM 12:00 PM Took chemicals to town to get reloaded. Pickup followed since it was Phase 2 conditions 6:30 AM 11:00 AM Delayed rigging up the wellhead since winds were too high to operate crane Pre job maintenance including setting up CL-22 injection points,adding heaters to the missile,and 11:00 AM 9:00 PM blowing air through the lines 12:00 PM 5:00 PM Perform Sand settling tests using 25,30,and 35#crosslinked samples with 8 ppg sand for Pioneer March 9,2013 5:00 PM 5:00 AM Crew off for rest 6:00 AM 6:30 AM Morning Safety Meeting 6:30 AM 10:00 AM Rig in Chemicals,blow air,rig up LVT and Cement,and get prepare for the job. 8:30 AM 9:30 AM Pre-Job meeting to discuss plan for the job with Crew Supervisors,Account Rep,and Pioneer 10:15 AM 10:45 AM Pre-Job Safety Meeting with all of location 10:45 AM 10:55 AM Pull on LVT and flood surface lines 10:55 AM 11:10 AM Prime Pumps 11:10 AM 11:20 AM Pressure test 1 truck,cement,and pop-off 11:20 AM 11:41 AM Prime remaining trucks,hydrate gel,and flood chemicals ODSN-29 11:41 AM Started pumping 50# 11:42 AM Drop Zone 3 Ball;pumped it down at 5 bpm due to pressure. 900269614 Pressure dropped to 4000 psi;after checking for leaks on surface(none)rate was brought up to 15 Zones 3-5 12:19 PM 12:25 PM bpm Ball seated 4 bbls early;trucks kicked out. Reset Max pressure to 9000 psi. Did not get sleeve to shift 12:25 PM 1:20 PM (8913 psi) 1:20 PM 2:30 PM Shut down to freeze protect Conference call with Pioneer and Baker Hughes. Decision was made to bleed down pressure and try 1:30 PM 2:30 PM to pump again. 3:00 PM 3:15 PM Pumped until all LVT was gone;got up to 7 bpm and 5500 psi. 3:15 PM 3:25 PM Swapped over to linear gel. Pressure broke over and established injection rate Established 45 bpm at 7900 psi;pressure should have been lower than observed. Shut down for conf. 3:25 PM 3:45 PM call 3:45 PM 4:30 PM shut down for conference call. Decided to pump 250 bbls of crosslinked fluid followed by linear fluid. 4:30 PM 4:45 PM Still no injectivity;Shut down for conference call 4:45 PM 5:55 PM Decided to continue and drop the ball for zone 4. 5:55 PM 6:05 PM Pump Zone 4;ball hit 60 bbls early,kicked trucks out 6:05 PM 6:30 PM Pump at 10-15 bpm until pressure broke over and designed rate was able to be obtained. 6:30 PM 7:16 PM Finish pumping zone 4 7:16 PM 9:20 PM Pump zone 5 9:20 PM 9:30 PM Try to get Zone 6 Ball to seat;did not see any ball response;shut down to freeze protect. 9:30 PM 11:30 PM Post Frac Cleanup 20 gallons of frac fluid was spilled last night while cleaning out lines after the job. Spill was reported to March 10,2013 10:30 PM 1:00 AM ACS and Pioneer and Cleaned up. Pioneer Natural Resources Treatment Summary ODSN-29 Part 3 Zones 6-9 Alaska Section 11 Township 13N Range 7E API #: 50-703-20642 Nuiqsut 30# Hybor-G March 11, 2013 SO# 900248783 HALLIBURTON HALLIBURTON I ProduEnhonct+o,, nt Table of Contents Section Page(s) Cover Sheet 1 TOC 2 Wellbore Information 3 Executive Summary 4-8 Stage Summary 9 Design Worksheet 10 Fann 35 QC 11 Lab QC 12 Sand QC 13 Treatment Plots 14- 16 Chemical Plots 17- 18 Net Pressure Plots 19-20 TOC Page 2 rn a) no ro \ E—cocri c; P.J 75 |%f=- f,,r4; in COCO 0. §k 0000000) 0 ,_ §co S g \ E '<D jel > LO NI . gg « « « « g_ (0 CO tO R =$&, E _ 2 rn c § N. )§O\( E ;Tcci t2a,.- 8 . ±, - / 37 \ °C \ .! §_;\§ qE \ bp • =\a # , ,, !! »;a,- 7 , — 70D00 03 22 co o o § cops 22 - 2 0 N cL ti_ tii it, \ 322 '- - E§ * £ Eyf£ _ � tO /° t 55 LL §—LI 2�� L. o ti) 0 CO NI U.0 / 4 ] G } 2 GQ 03 ,,, C) , Q?ap \&//\ 21°„ j}\/\ O.�\ 0k CO CO is |] N ! § 2E! 3U.R<3 HALLIBURTON Engineering Executive Summary On 03/11/13 a stimulation treatment was performed in the Nuiqsut formation on the ODSN-29 Part 3 Zones 6-9 well. The following information was gathered during the treatment. Sales Order#: 900248783 API#: 50-703-20642 30# Hybor G Volume: 264,845 gal 6306 bbls 30#Water Frac G Volume: 19,651 gal 468 bbls Freeze Protect Volume: 1,890 gal 45 bbls Total Fluid (Used): 286,386 gal 6819 bbls Clean Fluid Downhole (No Hydro or LVT): 284,496 gal 6774 bbls Carbolite 16/20 Pumped: 843,400 lbs Formation: Nuiqsut Total Stim-Sleeve Zones: 9 Total Zones: 9 Net Pay Interval: 5519 ft Average Rate: 45.8 bpm Average Pressure: 5666 psi Maximum Rate: 51.9 bpm Maximum Pressure: 7064 psi Maximum Horsepower: 8700 HHP Average Visc: 25.5 cp Average pH: 10.2 Average Temp: 72 deg F BE-6 Pre-treated in tanks: 60 lbs LO-65 Pre-treated in tanks: 800 gal Prior to pumping the job, Quality Control tests were conducted on location to determine hydration time, crosslink time, and gel viscosity. Chemical concentrations were adjusted, as needed, according to test results, pump times, and onsite water. We appreciate the opportunity to service your well. If you have any questions about the job, or anything else, please call me at(970) 773-0592. Thank you, Drew Mogck Andrew West Technical Professional Technical Professional Halliburton Energy Services Halliburton Energy Services Executive Summary Page 4 Treatment Information Zone 6 Zone Summary Initial Rate (Breakdown): 35.85 bpm Initial Pressure (Breakdown): 6122 psi Max Rate: 51 bpm Max Pressure: 7,064 psi Average Rate: 50 bpm Average Pressure: 5,816 psi Max Horsepower: 8700 hhp Average Visc: 25 cp Average pH: 10.2 Average Temp: 68 F Carbolite 16/20: 259,843 lbs Total Proppant Pumped: 259,843 lbs Proppant in Formation: 259,843 lbs 30# Hybor G Volume: 80,938 gal 1927 bbls 30#Water Frac G Volume: 2,320 gal 55 bbls Freeze Protect Volume: 0 gal 0 bbls Comments: Zone pumped to completion with no issues. Went to 6 ppg max. Executive Summary Page 5 Zone 7 Zone Summary Initial Rate (Breakdown): 20.37 bpm Initial Pressure (Breakdown): 3772 psi Max Rate: 40 bpm Max Pressure: 5,623 psi Average Rate: 34 bpm Average Pressure: 5,244 psi Max Horsepower: 5703 hhp Average Visc: 25 cp Average pH: 10.2 Average Temp: 68 F Carbolite 16/20: 0 lbs Total Proppant Pumped: 0 lbs Proppant in Formation: 0 lbs 30# Hybor G Volume: 0 gal 0 bbls 30#Water Frac G Volume: 8,929 gal 213 bbls Freeze Protect Volume: 0 gal 0 bbls Comments: Dropped ball to see sleeve shift then dropped ball for zone 8. Executive Summary Page 6 Zone 8 Zone Summary Initial Rate (Breakdown): 19.82 bpm Initial Pressure (Breakdown): 3653 psi Max Rate: 52 bpm Max Pressure: 6,918 psi Average Rate: 49 bpm Average Pressure: 6,237 psi Max Horsepower: 8312 hhp Average Visc: 26 cp Average pH: 10.2 Average Temp: 71 F Carbolite 16/20: 374,820 lbs Total Proppant Pumped: 374,820 lbs Proppant in Formation: 374,820 lbs 30# Hybor G Volume: 110,090 gal 2621 bbls 30#Water Frac G Volume: 1,934 gal 46 bbls Freeze Protect Volume: 0 gal 0 bbls Comments: Zone pumped to completion with no issues. Went to 7.5 ppg max Executive Summary Page 7 Zone 9 Zone Summary Initial Rate (Breakdown): 20.28 bpm Initial Pressure (Breakdown): 3675 psi Max Rate: 51 bpm Max Pressure: 5,982 psi Average Rate: 50 bpm Average Pressure: 5,367 psi Max Horsepower: 7413 hhp Average Visc: 26 cp Average pH: 10.2 Average Temp: 82 F ISDP: 2133 psi Final Fracture Gradient: 0.775 psi/ft Carbolite 16/20: 208,738 lbs Total Proppant Pumped: 208,738 lbs Proppant in Formation: 208,738 lbs 30#Hybor G Volume: 73,817 gal 1758 bbls 30#Water Frac G Volume: 6,468 gal 154 bbls Freeze Protect Volume: 1,890 gal 45 bbls Comments: Sand ran out about 100000 lbs earlier than expected based on eyeball estimates due to splitting loads between bins etc over the past few weeks. 6 lb stage was pumped to completion and proppant ran out shortly after switch to 7.5 lb stage. Screws were running fast since they had been calibrated with ice in the screws. When ice was knocked out at the end of last job the screws could run more sand at same set point, and this led to running out early on this job. Proppant volumes were recalculated based on this knowledge and updated in the actuals pumped. Executive Summary Page 8 a , _ !k E !q ) 5 § / 218 __ $ & „ / „ t2000'4 ;! ; & _ : m„ 7 „ § :\ _2\ƒ ; `}\ || 0 uu ( a } , ,� 8 { 2 k k ° 0 t}{w ` ■ ] ■ ;/` ®§ ] . 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'Hi 2 Ec a m .. .. g,' 444 ;4 "m ry ., ., . .. ' '-' 1 oe'.� mmmm8 n,T 4§� ' rvrrv � 88 :g ..ry .. m u m m .. m 0 Eo§ m 80, g § � 8m88 , § gam $ 8220, bo-0 71 ., .. .. ., ,.� ., .. ., ., a e , R8 $ 8 R8R82 88R8R8 ., m . m < . n m e ,a n m 0 0 0 0 0 0, 4444 444444 A Vj P� 0 ,122 V V U V V U U U O O R rr, A O O O m. Z ? n n a a n s a m u n u n u 1 O § u u %,1, O. N N aO O Oz 0 V,9 0 0 . u u u u u o u u u o u p u o ,90 0 e - 'x x x x " x x a 1 a a` n 1 a 1 a 1 1 LL c g o A P 3 3 3 A $ $ $3 $ A $ 3 a Uzi. mE ., ry m a ,e n m 2 ., ,y ,y ry ry ry ry ry ry n Et- m n m m HALLIBURTON Pnoduu,t,on Enh.sncelmasnc. WI I I/IOR INFORMATION Fluid System:( 301$Hybor-G Testing done by: Caitlin McCarthy Customer:; Pioneer Natural Resources Date:; 3/10/2013 ! Well Name: ODSN Well Number:1 29 Well Location:: Nuigsut ' TVD(ft)._ BHST(F),_.__. 175 I Water Used Frac Tanks 1-20 from 3/10/13 I LVID DE11(ON Test*, 1 2 3 4 5 Water Analysis: Chemical units _. Chemical Concentrations Temp(F),! 64'x. _ CL-31 BP?_... 0.50 __.. 0.50 pH,_._. 7.971 CL 22 1_ gpt 0.90 0.90 • Specific Gravity, 1.0261 gpt 0.50 0.50 Bicarbonates( Claweb _. (mg/L)! m8/L)1 172 BE-7 gpt 0.25 0.25 Carbonates mg/L)[ 04 Losurf _gpt 1.00 1.00 ___� Chlorides(mg/L) 21,5401 MO-67 gpt 0.40 0.40 Conductivity(pS/cm)• 69,6971 WG-36 ppt 30.00 30.00 Hardness(mg/L) 4,8001 L065 gpt 2.00 2.00 _. Iron(mg/L) .....01 SP ppt 2.00 Potassium(mg/L) 12,000 OptMoll ppt 4.00. 2.00 Sodium(mg/L)• 305 Sulfates(mg/L) 1,200 TDS(mg/L) 46,000 IIIIIUI'lnl! 1pl Test*, 1 2 3 4 s _ Gel Hydration Water pH 7.71 7.71 Min _ Vlsc(cP) Temp(F) Base Gel(1$) 30 30 1 2 12 80 Base Gel Visc(cP) 28 28 6 24 80 Base Gel pH 7.91 8.2212 28 80 Base Gel Temp(F) 60 78 __....__ Crosslink pH 10.18 10.07 Final pH 9.39 9.17 Test Temp(F) 150 150 Break lime(hr:min) 0:30 1:10 1 Fann 35 Break Chart 4500 160 4250 I 1 4000 I 1 -140 3750 3500 • -120 3250 I 3000 1 2750 is -100 -VIu 1 -VIsc2 S 2500 r—` —Visc3 C a Vise 2250 • 80 Lr R a -VIsc5 2000 F ---Temp 1 --Temp 2 1750 ---Tempa -60 Temp 4 1500 ---Temp 5 1250 _40 1000 750 - 500 • 20 250 0 0 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 5 80 85 90 95 100 105 110 115 120 125 130 135 140 145 150 155 160 165 170 175 180 185 190 195 200 Time(min) Fann 35 OC Page 11 JOB INFORMATION AND TESTING CONDITIONS Customer: Poineer Fluid System: Hybor G Bob Type: B5X Well Name: Conocco Shear Rate(1/sec): 40 Date: 9/21/12 Lab Project ID: S0178 Test No: 2 5 Water Analyst Chemical Units Chemical Concentrations Sample ID:W0136 WG-36 ppt 25.00 25-00 25 00 25.00 Bicarbonate(mg/L_) 152.5 LoSurf300D gpt 1.00 1.00 1.00 1.00 Calcium(mg(L) 308.80 MS S-2510T gpt 0.50 0.50 0.50 0.50 Carbonate(m/L) 0.00 MC 13-8625 gpt 0.25 0.25 0.25 0.25 Chloride Ong/L) 1305400 C16-Web gpt 0.50 0.50 0.50 0.50 Conductivity(pS/cm) 35000.00 Iron(mg:L) 0.70 CL-221_7C gpt 0.90 0.90 0.90 0.90 Magnesium(mg.t) 933.10 CL-31 gpt 0.30 0.30 0.30 0.30 pH 7.27 MO-67 gpt 1.50 1.50 1.50 1.50 Potassium(mg:L) 370.00 Opti-II ppt 2.00 3.00 4.00 4.00 Resistivity(S2-m) 0.00 SP Breaker ppt --- - -- 2.00 Sodium Ong/11' 7097.00 Specific Gravity 1.021 Sulfate(mgL) 1900.00 TDS(mg2)" 23100.00 Temperature(°F) 71 'calcalarsd values FLUID PROPERTIES Test No: 2 3 5 a Gel H3dratioa(SILs) Water pH 7.27 7.27 7.27 7.27 Mm Viscosity(cP) Temp.(oF).. Base Gel(#) 25 25 25 25 1 10.0 71 Base Gel Vise(cP) 20.0 20.0 20.0 20.0 3 15.0 71 Base Gel pH 7.40 7.20 7.20 7.40 6 19.0 71 Base Gel Temp-(°F) 70 71 71 70 9 19.0 71 12 19.0 71 Crossllnnk pH 1015 10.18 10.20 1019 Final pH 9.42 9.71 9.68 8.98 Test Temp.(°F) 160 160 160 140 Break Time(hr:minn) 1:05 0:25 0:20 0 Test Notes: BREAK TEST CHART -viae 1 -vac2 �Vise3 Vise 4 ....--Tit _____ ,.5 ........Temp 2 _- ----Temp 3i Temp 4 200 uw ` . 1,5 1\-\ 1000 __ - 900 ` •.••" ----------------------------------------..---..--- 150 600 I h ie ..' \\,.....\."\T".7....."--....\".. 506 I ���' 400 e�e .. 100 300 _.. _ 200 _...._. .. .. ._ _ ` ,5 100 0 • 50 0:00 0:10 0:20 0:30 0:40 0:50 1:00 1:10 Elapsed Time.hr:min Lab QC Page 12 Customer: Pioneer Natural Resources Well: ODSN-29 Part 3 Zones 6-9 HALLIBURTON Date: 3/11/2013 Formation: Nuiqsut Ticket#: 900248783 Sand Type Carbolite 16/20 Pan Size 6641 Bin 2 6641 Bin 1 3838 Bin 1 3838 Bin 2 3838 Bin 3 M. % Wt. % Wt. % Wt. % Wt. % Pan#12 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan#16 3.5 3.5% 2.4 2.4% 5.2 5.3% 6.5 6.6% 3.1 3.0% Pan#18 67.2 67.6% 56.4 56.5% 59.9 61.5% 68.0 68.5% 71.2 68.9% Pan#20 28.6 28.8%_ 40.8 40.9% 28.3 29.1% 24.6 24.8%_ 28.8 27.9% Pan#25 0.1 0.1% 0.2 0.2% 0.2 0.2%_ 0.1 0.1% 0.2 0.2% Pan#30 0.0 0.0%� 0.0 0.0% 0.1 0.1% 0.0 0.0% 0.1 0.1% Pan 0.0 0.0% 0.0 0.0% 3.7 3.8%_ 0.0 0.0% 0.0 0.0% Total 99.4 100.0% 99.8 100.0% 97.4 100.0% 99.2 100.0% 103.4 100.0% Retained 96.4% 97.4% 90.6% 93.3% 96.7% Sand Type Carbolite 16/20 Pan Size 3838 Bin 4 Comp 2 Comp 3 Comp 4 Comp 5 Wt. % Wt. % Wt. % Wt. % Wt. Pan#12 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan#16 6.1 6.1% 7.6 7.5% 8.6 8.3% 9.3 9.1% 6.9 6.8% Pan#18 74.0 74.4% 67.1 66.9% 78.3 75.8% 70.7 69.4% 68.5 67.9% Pan#20 19.4 19.5% 25.5 25.4% 16.4 15.8% 21.8_ 21.4% 25.5 25.3% Pan#25 0.0 0.0% 0.2 0.1% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan#30 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Total 99.5 100.0% 100.3 100.0% 103.2 100.0% 101.8 100.0% 100.9 100.0% Retained 93.9% 92.3% 91.7% 90.9% 93.2% Sand Type Carbolite 16/20 Pan Size Comp 1 Comp 2 Comp 3 Camp 4 Comp 5 Wt. % Wt. % Wt. _ % Wt. % Wt. % Pan#12 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan#16 4.5 4.5% 4.4 4.3% 4.8 4.8% 6.3 6.1% 7.1 7.1% Pan#18 63.3 63.3% 63.9 63.5% 58.7_ 59.0% 74.4 72.8% 69.1 69.0% Pan#20 31.9 31.9% 32.1 31.9% 35.6_ 35.7% 21.4 20.9% 23.8 23.8% Pan#25 0.3 0.3% 0.3 0.3% 0.5 0.5% 0.1 0.1% 0.2 0.2% Pan#30 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Pan 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% 0.0 0.0% Total 100.0 100.0% 100.6 100.0% 99.5 100.0% 102.1 100.0% 100.2 100.0% Retained 95.2% 95.4% 94.8% 93.8% 92.7% Sand Type Carbolite 16/20 Pan Size Comp 1 Comp 2 Comp 3 Comp 4 Wt. % Wt. % Wt. % Wt. % Pan#12 0.0 0.0% 0.0 0.0% 0.0 0.0% #DIV/0! Pan#16 7.5 7.5% 7.2 7.2% 5.3 5.3% #DIV/0! Pan#18 67.3 67.7% 71.2 70.9% 68.7 68.2% #DIV/0! Pan#20 24.3 24.5% 21.6 21.5% 26.8 26.6% #DIV/01 Pan#25 0.3 0.3% 0.4 0.4% 0.0 0.0% #DIV/0! Pan#30 0.0 0.0% 0.0 0.0% 0.0 0.0% #DlV/0! Pan 0.0 0.0% 0.0 0.0% 0.0 0.0% #DIV/0! Total 99.4 100.0% 100.4 100.0% 100.8 100.0% 0.0 #DlV/0! _Retained 92.1% 92.4% 94.7% #DIV/0! Sand QC Page 13 Treating Chart-Zone 6 Treating Pressure(psi) A Slurry Rate(bpm) B BH Proppant Conc(lb/gal) C Slurry Proppant Conc(lb/gal) C A B Actual BH Temp(°F) D Gauge BH Pres(psi) A C D 8000- 80 16 -160 7000- E- 4000- 000gliiiill .100040- rir 1_8 -80 3000- 30- al --, ..._ Ai 1-6 -60 2000- 20- -4 -40 IIII1000- 10 • -2 -20 lilt n n 0 0 i 0 0 18:20 1830 18:40 18:50 19:00 19:10 3/11/2013 3/11/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 11-M ar-2013 Sales Order#: 900248783 INSITE for Stimlatlm i.4.4.0 Well Description: ODSN 29 UWI: 50-703-20642 10-Ju-1316:33 Treating Chart-Zone 7 Ball Drop Treating Pressure(psi) A Slurry Rate(bpm) B BH Propp ant Conc(lb/gal) C Slurry Proppant Conc(lb/gal) C A B Actual BH Temp(°F) D Gauge BH Pres(psi) A C D 8000- 80 16 -160 0 Cl 7000- 70 \tv........__:rTh..._rfe.e.....___ -14 -140 6000- 60 Mvp.,,..._ -12 -120 5000- 50 -10 -100 4000- 40 7---8 -80 3000 30 ��' 6 -60 2000 20 -4 -40 1000- 10 -2 -20 4 0 -0 19:01 19:02 19:03 19:04 19:05 19:06 19:07 19:08 19:09 3/11/2013 3/11/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 11-M ar-2013 Sales Order#: 900248783 INSITE kr Stimulation v4.4.0 Well Description: ODSN 29 UWI: 50-703-20642 10-Ju-1316:34 Treatment Plots Page 14 Treating Chart-Zone 8 Ball Drop Treating Pressure(psi) A Slurry Rate(bpm) B BH Proppant Conc(Ib/gal) C Slurry Proppant Conc(lb/gal) C A B Actual BH Temp(°F) D Gauge BH Pres(psi) A C D 12000— 80 16 160 ® ® _ 10500— 70— —14 140 I 9000— 60— —12 120 • 7500— 50— —10 100 6000— 40 I;' —8 80 4500— 30 (---\--ir —6 60 3000— 20—' M —4 0 1500— 10— —2 20 TT 0— 0 ' 0 0 19:08 19:10 19:12 19:14 19:16 3/11/2013 3/11/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 11-Mar-2013 Sales Order#: 900248783 u1srtE for s6rulelai vt4 0 Well Description: ODSN 29 UWI: 50-703-20642 10 46431635 Treating Chart-Zone 8 Treating Pressure(psi) A Slurry Rate(bpm) B BH Proppant Conc(lb/gal) C Slurry Proppant Conc(lb/gal) C A B Actual BH Temp(°F) D Gauge BH Pres(psi) A C D 8000— 80 16 —160 7000— 70 —14 —140 6000— 60 '--� i -12 —120 5000— 50 10 —100 4000— 40 J"'V `ll —8 —80 3000— 30 ��� —6 —60 ,A.T.khr 2000— 20 —4 —40 1000 10 ® —2 —20 0- 0 , , , , i , , , f . . , , , , , , , , , , , , j 0 -0 19:20 19:30 19:40 19:50 20:00 20:10 20:20 3/11/2013 3/11/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 11-Mar-2013 Sales Order#: 900248783 rlarrefa:asndatiaiv4A0 Well Description: ODSN 29 UWI: 50-703-20642 1044.1316:37 Treatment Plots Page 15 Treating Chart-Zone 9 Ball Drop Treating Pressure(psi) A Slurry Rate(bpm) B BH Proppant Conc(lb/gal) C Slurry Proppant Conc(lb/gal) C A B Actual BH Temp(°F) D Gauge BH Pres(psi) A C D 12000— 80 16 —160 CA I 10500— 70— —14 —140 9000— 60— —12 —120 / _ 7500— 50 —10 —100 6000— 40— .� rwI i —8 —80 -Ilk I1 4500— 30— 6 —60 3000— 20 4 40 1500— 10— —2 —20 - - IC-7® 0— 0 ,-0 —0 20:15 20:16 20:17 20:18 20:19 3/11/2013 3/11/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 11-Mar-2013 Sales Order#: 900248783 INSITEfax StinvIalion v6.4.0 Well Description: ODSN 29 UWI: 50-703-20642 10-J.-131a38 Treating Chart-Zone 9 Treating Pressure(psi) A Slurry Rate(bpm) B BH Proppant Conc(lb/gal) C Slurry Proppant Conc(lb/gal) C A B Actual BH Temp(°F) D Gauge BH Pres(psi) A C D 8000— 80 16 160 7000— 70— —14 140 6000— 60— —12 120 1 5000— 50 ' `"r —10 100 r --' b - 4000— 40— —8 80 3000— 30 '�"' "'J"' —6 60 2000— 20 —4 '0 1000— 10- j , -2 20 r I f 1 , . . . , . , aaa a . . — o- o 20:20 2030 20:40 2050 21:00 3/11/2013 3/11/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 11-Mar-2013 Sales Order#: 900248783 INSITE fa Stimulation v4.4.0 Well Description: ODSN 29 UWI: 50-703-20642 10-Jm-1316:40 Treatment Plots Page 16 Chemical Chart-Zone 6 MO-67 Conc(gaVMgal) A Los urf-300D Conc(gaVMgal) A CL-31 Conc(gal/Mgal) A CIA-Web Conc(gal/Mgal) A BE-7 Conc(gaVMgal) B A is-II co,_ SP Breaker Conc(Ib/Mgal) A WG-36 Conc(lb/Mgal) B B 41150 3- 40 -30 2- rj _ -20 1 r- F A -10 `_ Iay.� ....,-,s rM I rr10 (POW, ' , ,, 40 ® OO �� LiL k . . l0 18:10 18:20 1830 18:40 18:50 19:00 3/11/2013 3/11/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 11-Mar-2013 Sales Order#: 900248783 IN$ITE for atlns4a0on N20 Well Description: ODSN 29 UWI: 50-703-20642 1e-Mar-1302:8 11111111111111111111111 Chemical Chart-Zone 7 MO-67 Conc(gaVMgal) A Losurf-300D Conc(gaVMgal) A CL-31 Conc(gaVMgal) A CLA-Web Conc(gaVMgal) A BE-7 Conc(gaVMgal) B A SP Breaker Conc(lb/Mgal) A WG-36 Conc(lb/Mgal) B B 4 I 50 -40 3- 1 -30 2- - -20 1 /44\-- _ __, 10 OO ® • ._ 0 0 19:02 19:04 19:06 19:08 19:10 19:12 19:14 1 3/11/2013 3/11/2013 Tine Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 11-Mar-2013 Sales Order#: 900248783 NSrrE for Stin latim.1.2.0 Well Description: ODSN 29 UWI: 50-703-20642 16-Ma-1302:50 Chemical Plots Page 17 Chemical Chart-Zone 8 MO-67 Conc(gaVMgal) A Losurf-300D Conc(gaVMgal) A CL-31 Conc(gaVMgal) A CLA-Web Conc(gaVMgal) A BE-7 Conc(gal/Mgal) B A Optiflo-II Conc(lb/M4— SP Breaker Conc(1b/Mgal) A WG-36 Conc(lb/Mgal) B B 4 50 - I —40 3— .1,1-- w Isk-30 30 2— , - 1' —20 klk 1 - - , - 1 I Yh .. 10 MgM wrw�Mwlsirsom a•pmowwlHp1111M+M+rw Mph.mosso", 41“ir.+r.r.www WIpew.ti..1.My.? ,t + • © i •u ii, coi o l 1930 19:40 19:50 20:00 20:10 2020 3/11/2013 3/11/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 11-Mar-2013 Sales Order#: 900248783 INSITE kr Sfinlgion v0.20 Well Description: ODSN 29 UWI: 50-703-20642 16.Mar-130251 Chemical Chart-Zone 9 MO-67 Conc(gaVMgal) A Losurf--300D Conc(gal/Mgal) A CL-31 Conc(gal/Mgal) A CIA-Web Conc(gaVMgal) A BE-7 Conc(gal/Mgal) — B „!;('Com-(PA/VIgat) A -r SP Breaker Conc(Ib/Mgal) A WG-36 Conc(lb/Mgal) B B 4 50 10-4 3— 1 JrAl w 1 -30 2- 1 —20 It , 11_ - f''�ritI� -10 l • •• •• •• ' •• • 0 , , , , , , 0 2020 2030 20:40 20:50 21:00 21:10 3/11/2013 3/11/2013 Time Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 11-Mar-2013 Sales Order#: 900248783 INSITE tar Stinldim v6.20 Well Description: ODSN 29 UWI: 50-703-20642 16-Ma,-130253 Chemical Plots Page 18 Net Pressure Plot-Zone 6 -Net Gauge BH Pres(psi) A Time NetPr BPC Slope -BH Proppant Conc(lb/gal) B 01 50.95 2176 6.050 -11.07 A Slope of Net Pressure(psi/min) C B 100008- 7 Closure Pressure=5000 psi 7- - 6_ 5_ -6 4_ 3 -5 2-,._-._______, ,-------..-eN '.( oArlifr F 4 10009_ - 8_ 7- -3 6- 5- 4_ -2 3- 2 —1 • • 0 Time=/11/13 18:10: 0 • • •• •• O• \ 1r 100 3 4 5 6 0 Time(min)(0= 1090) Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 11-Mar-2013 Sales Order#: 900248783 INSITE far Slip lalim v420 Well Description: ODSN 29 UM 50-703-20642 16-Mar-130255 Net Pressure Plot-Zone 8 -Net Gauge BH Pres (psi) A Time NetPr BPC Slope -BH Proppant Conc(lb/gal) B c1 50.95 2176 6.050 -11.07 A Slope of Net Pressure(psi/min) C B 100008= 8 Closure Pressure=5000 psi �vrh_ 7_ J V' 6_ -7 5- 4- - 3_ I w -6 2_ -5 10009_ ! -4 e_ 7 IS 6_ 3 5_ 4_ 3_ -2 2 • - • —1 0oe=0 11/1318 :00 • • • • 100- e9 0 100 Time(min)(0= 1090) Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 11-Mar-2013 Sales Order#: 900248783 INSITE for Stinalatian v420 Well Description: ODSN 29 UVN: 50-703-20642 16_Mar_130256 Net Pressure Plots Page 19 Net Pressure Plot-Zone 9 -Net Gauge BH Pres (psi) A Time NetPr BPC Slope -BH Proppant Conc(lb/gal) B c 50.95 2176 6.050 -11.07 A Slope of Net Pressure(psi/min) C B 100007 8- Closure Pressure= 5000 psi 7- 6- 5- 4- 3- -5 2- -4 10009_ - 6 .-._..'- 7_ -3 6- 5- -2 3- 2- —1 100 0 TAP=03/11/13 18:10. • • • • 0 Time(min)(0= 1090) Customer: PIONEER NATURAL RESOURCES-EBUS Job Date: 11-Mar-2013 Sales Order#: 900248783 klion Well Description: ODSN 29 UVN: 50-703-20642 iNsrre 16Meter-13 13 557vi2.0 Net Pressure Plots Page 20 Job Log 1:00 AM 10:00 AM Crew off for sleep.(Daylight savings lost 1 hour) 10:00 AM 10:30 AM Morning safety meeting to discuss plan for the day. Crew took a pump to OTP to thaw out. Spotted a bleedoff tank for HES use.Cleaned out sand from around the movers. Performed pump maintenance. Took pump to DH to check the gearbox. Did 10:30 AM 8:00 PM housekeeping on pad and prepped for next job. March 11,2013 8:00 PM 6:00 AM Crew off for sleep 6:00 AM 6:30 AM Morning safety meeting Crew rigged in the pump from DH.They blew air through the lines,performed housekeeping,and 6:30 AM 11:00 AM offloaded gel. 11:00 AM 1:00 PM Crew waited for SLB to deliver Scale inhibitor to location. After it arrived,it was added to the tanks. 11:30 AM 12:30 PM Crew changeover meeting ODSN-29 1:00 PM 3:15 PM Prepare to start job. SO# 3:15 PM 4:00 PM Pre Job Safety Meeting. 900248783 4:00 PM 4:10 PM Started 1 pump truck and spotted LVT truck. Zones 6-9 4:10 PM 4:25 PM Flood lines with LVT for pressure test 4:25 PM 4:45 PM Pressure test;found a small leak on the CBS;it was in containment 4:45 PM 5:05 PM Fix Leak. 5:05 PM 5:10 PM Pressure test complete;no leaks 5:10 PM 5:30 PM Prime remaining trucks. 5:30 PM 5:50 PM Pressure test backside and pop offs. 5:56 PM 6:05 PM Frozen valve on the ADP got heat on it 6:05 PM 6:12 PM Pull on water and hydrate gel. 6:12 PM 7:02 PM Pump Zone 6;went to 6 ppg max. Ball 7 Ball hit 21 bbls early. 7:02 PM 7:09 PM Shift sleeve for zone 7,drop ball for zone 8. Zone 8 ball hit20 bbls early. 7:09 PM 8:14 PM Pump zone 8,went to 7.5 ppg max. Ball 9 hit 17 bbls early. 8:14 PM 8:56 PM Pump zone 9;sand ran out 1000 sacks early. ODSN-29 well complete. 8:56 PM 10:00 PM Freeze protect,clean up chemicals and lines. PI 0 N E E R Ooerations Summary Report - State Well Name: ODSN-29 NATURAL RESOURCES 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 12/15/2012 12/16/2012 0.0 Move from ODSN-36 to ODSN-29. PJSM.Perform inspection of well bay,Wireline unit and hot oil unit.PT lubricator to 1500 psi,PT control line for SSSV to 500 psi.MU gauge ring 3.84"OD, (BHA 2'stem and gauge ring).Tag up at 2,062'SLM at SSSV. POOH reconfigure tools with GS to retrieve dummy from SSSV.(BHA 2'stem and GS) Latch up at 2,062'SLM retrieved dummy from SSSV.POOH to reconfigure tools to pull ball and rod.(BHA 10'1.875"roller stem and RS pulling tool). RIH with 3.60"Bell guide&RS Pulling tool to pull ball and rod from RHC from XN. RIH latch up @ 8,502'SLM/8,511 MD. POOH. OOH with ball and rod. RIH with 4-1/2"OK-6 and 1/4"JDC pulling tool. Latch Shear Out Valve from station#4 @ 2,216' SLM/2,230'MD POOH. OOH with Shear Out Valve.MU running tools with Dummy Gas Lift valve.RIH set DGLV in#4 station @ 2,216'SLM/2,230'MD.POOH. OOH.Perform 3500 psi test on IA for 30 minutes.Pressure held with 20 psi drop after the 30 minute test. 12/16/2012 12/17/2012 0.0 RIH and latch RHMC body @ 8,507'SLM/8,511 MD.POOH. OOH with RHMC body.RIH with Frac Sleeve with 3.15"ID OAL 27".Perge control line with Hydraulic oil then set frac sleeve in X nipple.Attempt to gain integrity with pressure.After several attempts the pressure continues to fall off very slowly.POOH. OOH with tools secure well and LD lubricator and secure slickline unit and hot oil unit for the night.NU&secure well.Tubing psi 100 psi, IA 100 psi,OA 0 psi. Attempt to pressure up control lines in the morning and check for integrity on the frac sleeve. HES and LRS is timed out. RU hydraulic line to SSSV control line. Perge line,attempt to test isolation sleeve.Pressure up to 400 psi,bleed back to 200 psi(in 10-15 sec)pressure up to 400 psi,bleed back to 200 psi in the same time frame.Pressure up to 500 psi,bleed back to 200 psi in the same time frame. Pressure up to 500 psi,bleed back to 200 psi in the same time frame. RD and secure well,HES and LRS released from well.Performed handover to operations, inspect well bay and location of HES and LRS equipment.Work completed on well. 1/3/2013 1/4/2013 0.0 Cost Place holder For Expro Rental Split between N-25,N-24,T-47, N-29 1/11/2013 1/12/2013 0.0 RU on ODSN-29. PJSM. PU Tool String and Lubricator. Pressure test Lubricator at 1000 psi. Good. RIH with 4 1/2'GS to the Frac Sleeve at 2,062'slmd. POOH with same. RIH with new Frac Sleeve and set at 2,062'slmd.(Frac Sleeve:OAL=27", ID=3.125"). Pressure test Frac Sleeve at 1000 psi. Good. Increase pressure up to 2000 psi. Good. POOH and LD Tool String • and Lubricator. Secure Well. Complete RD.Crew released. Crew travel to Dead Horse. 1/31/2013 2/1/2013 0.0 Cost Placeholder for 1/4 of the Rental for Expro Equipment 2/6/2013 2/7/2013 0.0 Cost placeholder for spare 4"vetco valve. 2/14/2013 2/15/2013 0.0 cost placeholder for January frac tank rental for ODS 2/24/2013 2/25/2013 0.0 Previous operations-Phase 2 weather conditions. Reloading operations. Trucks sent to Deadhorse and Kuparuk in convoy only. Round trip water from RSC,CPF3,and bring additional trucks with 3%KCI at 140 degF from hot water plant in Deadhorse.Load 16/20 proppant. Replace butterfly valve on Frac Tank#14. LRS continue heating frac tanks. Vac Truck with 300 bbls of LVT on Location. 2/25/2013 2/26/2013 0.0 Continue to fill Frac Tanks. Continue to heat Frac Tanks. Continue to off-load 16/20 mesh Carbolite Hold PJSM.Continue to service frac equip&work on pumps.Continue to load tanks&heat fluids. RD frac equip&Stinger off ODSN-26i.Prep wellhead on ODSN-29.Load Carbolite. PJSM w/Well Works Supervisor,VG Serviceman,CH2 Crane Operator. PU and NU a second 5K Valve for space-out. PU Lubricator. Install a type"H"TWCV in the Tubing Hanger profile. Remove Greyloc Clamp.ND both 5K Tree Valves. PU and nipple up two 4 1/16"x 10 k Frac Valves. MU Greyloc Clamps. Install"H"VR Plug. Test void at 5000 psi x 10 minutes. Good. Fill Frac Tree with Diesel. Test Both Frac Valves against the VR Plug and the TWCV at 10,000 psi x 10 minutes. Good test. Bleed off pressures. Page 1/6 Report Printed: 12/11/2013 PI 0 N E E R Operations Summary Report - State Well Name: ODSN-29 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 2/26/2013 2/27/2013 0.0 Continue to Fill Frac Tanks. Continue to heat Frac Tanks. PU Lubricator to pull the TWCV. Having troubles pulling the TWCV(possible some ice around the TWCV profile). LD Lubricator. Tarp in wellhead and stage two heaters to warm up wellhead. MU lubricator&pull TWCV.Spot in HES cement pumper on island.RU frac lines to ODSN-29. Install spacer spool&goat head.Continue to heat tanks.Add in carbolite. Load small vac truck w/60 bbls LVT for ball dropper. Finish snow removal around equipment. Finish RU. PJSM with all. Review lessons learned from the N-26i Frac. Perform bucket test. Prime up with heated LVT. Circulate from Blender to wellhead back to the circulating tank. Prime up Pump Trucks to Blender and immediately caught pressure. Broke line from the manifold to the Blender and found an ice plug. Replace prime-up line. Prime up pump truck closest to the prime up line that was just replaced. Attempt prime up once again,but still caught pressure, Discovered that the drivers side manifold had an ice plug. Unable to prime up. 2/27/2013 2/28/2013 0.0 Continue to isolate the ice plug in the manifold. Put additional heat on manifold to thaw Ice plug. Also discovered that due to a leaking valve,LVT was circulated to the Hydration Tank. Vac out tank and lines to recovered LVT. Finish recovering LVT. Continue to thaw the manifold. Circulate manifold to verify that the ice plug is gone. Check valve alignment to prevent LVT from getting into the Hydration Tank. Re-heat LVT in the Vac Truck to 125 degs F. Crew houred out. LRS continue to heat the fluids in the Frac tanks to maintain temperature. Crew change today.Recycled 110 bbls of LVT&heated same.Held PJSM w/new crew @ 16:00 hrs.Primed pumps and test lines to 9000 psi.Pumped open P-Sleeve at 5600 psi and completed first stage of frac job.Dropped first frac ball 2.563",landed ball and opened all three sleeves.Begin pumping second stage and screened out with 4 ppa proppant on bottom.Shut down and clean out lines.Mobilized Coil Tubing crew from Nuna to operate CTU#6. 2/28/2013 3/1/2013 0.0 Continue to fill and heat all 20 frac tanks.Will release 325 bbl vac truck,and replace with 225 bbl vac truck.RD frac equipment from ODSN 29 and move to ODSN 47.Mobilize CTU#6 to clean out ODSN 29. 3/1/2013 3/2/2013 0.0 CTU#6 on the island,while spotting unit the power steering went out on tractor unit is spotted. Called mechanic. LRS still heating frac tanks,all frac tanks full. Pulled LRS crew from smaller unit on frac pad to support CTU#6 on island.With CTU#6 and , LRS rigged up proceed with freeze protecting ODSN-29.BHA(down jet nozzle-stinger-check valve-cold roll),pump 1.25"drift ball through coil,took 35.7 bbls(coil volume).Test BOP pressure 250 psi low/4000 psi high;push test 10k;pull test 18K. Drain coil,cut off nozzle recover 1.25"ball. Open well w/2608 psi on it;pressure dropped to 1000 psi.Start in the hole pumping at 1 bpm, 1710 psi,w/107 degree diesel.While going in the hole at 860'noticed a flat spot on coil,calls where made and decision to cut coil before reversing out.Continue in the hole to freeze protect. Coil will be cut in the AM hours. Once on depth of 2000'pooh while pumping 40 more bbls of 140 degree diesel.At surface,CTU #6 crew laid down injector head,cap BOP's and pressure test 350 psi low pressure,2200 psi high pressure.Well secure.Rig down LRS,they are back on frac pad heating frac tanks.CTU#6 released from ODS sent to Nuna to set WRP. 3/2/2013 3/3/2013 0.0 CTU#6 Back on ODS site.Slip and cut 948'of coil off reel,in 10'pieces.Stand by for clean out on ODSN-29.CTU#6 night crew released from ODS sent back to Nuna 3/3/2013 3/4/2013 0.0 CTU#6 back on ODS.Will start setting 3 up right tanks,and fill same with slick water.RU lines to reverse manifold to CTU and Expro.Take all old Expro equipment off island and replace with new unit. 3/4/2013 3/5/2013 0.0 Continue filling 3 up right tanks with 3%KCL slick water. Expro change out equipment. LRS notified once tanks are full they will start heating tanks.CTU#6 rigged up. Page 2/6 Report Printed: 12/11/2013 PI 0 N E E R Ooerations Summary Report - State Well Name: ODSN-29 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 3/5/2013 3/6/2013 0.0 Up right tanks are full,pulled LRS from frac pad to start heating up same.CTU and LRS are RU, Expro still RU. 19:24 Held Pre Job safety meeting in CTU ops cab with all crews involved in clean out.Fluid pack all lines, pressure test all lines and surface equipment 500 psi low/4000 psi high. Open swab valve 23.5 turns, IA 973 psi OA 560 psi,Start pumping down coil at 1 bpm 1260- 1380 psi.TIH at 24 FPM.Slack off WT 688 lbs to-5597 lbs.At 1,968'Tag up, PU wt 1509 lbs pumps off. 3/6/2013 3/7/2013 0.0 At midnight,PU t/1,900'. Go back down for dry tag.Tag up at 1,968'&PU t/1,930'. Start pumping down coil with diesel at 1 bpm 1125 psi at 13.5 fpm.Take samples from Expro every BTU.We starting getting back slush,(ice) Washed down t/2,012'. PU to clean annuals,PU wt 7200 lbs.With 119 bbls of diesel pumped switched over to 3%KCL slick water.Pumping at 1.5 bpm 1748 psi,8 fpm.monitoring returns with Expro,getting back gel and frac sand. At 6:00am at 4,100'reverse circulating well bore monitoring returns at Expro. Continue reverse circulating well bore clean at 1.5 bpm 1250 psi. Reverse circulated t/7,312' tagged hard. PU several times attempt to reverse through hard top.Clear tubing swap to circulate long way.Break through top 1'and continue to wash down t/7,321'. Pull back up swap back to reverse circulate. Continue to reverse down and clean well f/7,312'. At 18:00 at 11,220'. Continue reverse circulating and cleaning well bore till midnight at 14,382'. Monitoring returns and samples at Expro unit.Pumping at 1.5 bpm,85 psi max pressure seen,at 10-15'fpm. 3/7/2013 3/8/2013 0.0 00:45 hrs @ 14,611'starting getting back.25%scale sorb, .75%frac sand,2%formation fluid and 12%oil.Due to frac job on ODSN-25 this AM will start reverse circulating well at 1.6 bpm 75 psi 10-13 fpm, while POOH.At 11,220'started circulating long way down coil tubing at 1.8 bpm 1162 psi. At 2,500'swap fluid from 3%KCL to diesel and freeze protect well bore and surface equipment.At surface with BHA,get injection rate at 5 bpm 2740 psi.RD injector head and cap well,test same. 18:00 start blowing down BOP's and reverse manifold to move CTU#6 and Expro equipment to another well.Waiting on orders. 3/8/2013 3/9/2013 0.0 Continue rigging down SLB and Expro equipment,wait on orders. 06:00 HES frac crew rigging up on ODSN-29.RD frac pump and repair same.RU frac missile, RD chemical floats and send same to Deadhorse to be refilled.RU goat head and frac lines to well.Continue filling mountain movers with 60-20 carbolite.Fill and heat all frac tanks to 100 degrees.2 LVT trucks will be heated to 150 degrees. 3/9/2013 3/10/2013 0.0 Spot and RU chemical floats.Spot Cuzco and LVT transports. RU cement unit to ball drop trailer. Held PJSM with all involved personnel. Load lines with LVT and test same to 9000 psi.Set PRV at 8000 psi and apply 3500 psi to IA with LRS. Establish injectivity at 5 bpm with 2800 psi,drop 2.625"intallic ball,and attempt to pump down same at 10 bpm--treating pressure climbed up to 6000 psi.Slow rate to 5 bpm to attempt to seat ball--treating pressure broke back to 2000 psi, stage up rate to 15 bpm with 2800 psi. Ball seated and pressure spiked over to 8000 psi which kicked out the pumps.Work pressure up 3x to attempt to shear ball seat--unsuccessful.Consult BHI tech support and raise PRV at 9000 psi.Pressure up to 9000 psi with a maximum down hole pressure of 11,800 psi 2x to attempt to shear ball seat-no success. Held conference call with Anchorage team,decision made to attempt to fatigue shear pins with maximum 11,000 psi down hole pressure.Started pumping with LVT to shear pins and started pumping in at 1 bpm and pressure broke down at 5500 psi. Establish injection at 5 bpm with 3000 psi and stage rate up to 45 bpm with 7500 psi and pump 250 bbl cross linked pad followed by 250 bbl linear gel. Perform hard shut down for data frac and confer with Anchorage reservoir team.Decision was made to drop 2.688"ball and forego the zone f/14,110 t/14,648'.Drop 2.688"ball and pump down same, ball seated 60 bbls early at 40 bpm to shift open frac sleeves.When sleeve opened initial rate was 8 bpm with 6200 psi.Continue to stage rate up as treating pressure was dropping.Pressure broke back from 7500 psi to 3000 psi. Pump zone 4 as per frac design and drop 2.750"ball at 30 bpm with 100 bbl spacer in front of ball--never saw indication of ball seating and shearing ball seats.Stop job after pumping 200 bbls over calculated volume to the ball seat. Page 3/6 Report Printed: 12/11/2013 PI 0 N E E R Operations Summary Report - State Well Name: ODSN-29 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 3/10/2013 3/11/2013 0.0 Continue to load water in frac tanks and proppant in Mountain Movers.Continue to heat frac water with LRS.RD 2 pumps from missile repair same and RU both pumps back on missile. Blow air thru all lines to ensure that there are no ice plugs.RD frozen 2"bleed off line from CBS valves to the sparge tank. Build containment and spot sparge tank next to the ball drop trailer, and rig up 2"bleed off line. 3/11/2013 3/12/2013 0.0 Load dry gel into growler.Add liquid scale inhibitor to frac tanks.Finish rigging up frac pumps to missile.Spot Cusco and LVT truck.RU cement unit to ball drop trailer, Load lines with LVT and test same to 9000 psi,set pop offs at 8000 psi.Pump zone 6 as per frac design.Slow rate to 30 bpm and drop 2.875"intallic ball and pump down same--seen ball seats shear 20 bbls early. Drop 2.938"intallic ball and pump down same--saw ball seats shear.(Bypass zone 7 due to a failed ECP).Pump zone 8 as per frac design. Slow rate to 30 bpm and drop 3"intallic ball and pump down same--saw ball seats shear.Pump zone 9 as per frac design and flush with 157 bbls linear gel,swap over to LVT and freeze protect well with 32 bbls LVT down the tubing.Total propant pumped for job was 731,400#,and 7,157 bbls 3%KCL water. 3/12/2013 3/13/2013 0.0 Blow down all lines to make sure they are clear of LVT to avoid spills. Break all frac lines from ODSN-29 and remove goat head. Install night cap flange on frac tree and fasten tarp to well bay. 3/13/2013 3/14/2013 0.0 PJSM. ND 10K Frac Valves. NU 5K Production Valve. Test void at 5000 psi. Good. The VR Plug has been removed. The BPV is installed. Well is secured. 3/14/2013 3/15/2013 0.0 Cost placer holder 3/15/2013 3/16/2013 0.0 cost placeholder 3/31/2013 4/1/2013 0.0 Cost place holder 4/1/2013 4/2/2013 0.0 Cost place holder 4/9/2013 4/10/2013 0.0 MIRU SLB CTU#6. Spot LRS. WHP=500, IAP=103,OAP=459. Swab Valve leaking. VG grease Swab Valve. Install BOP Stack. MU BHA as follows: Roll-on Coil connector, X0,2.50" Jet/Swirl Nozzle(w/0.87"Ball in place). OAL=9.61-ft. Stab Injector on Well. Perform draw down test. Good. Perform function test. Good. Test BOP Rams at 250 psi low/4000 psi high. Good.Open well RIH and tag fill @ 9,885'.While RIH well pressured up and broke over several times,well appears to packoff from injection.PU to XN nipple @ 8,500'.Flush XN @ 1.5(bpm) @ 3200 psi.Continue PUH and flush GLMs at 7,853';6,345';4,279;2,235'. Flush X nipple @ 2,300'. Flush frac sleeve @ 2,100'@ 1.5(bpm)&3200 psi. Freeze protect f/2,200'U Surface. 4/10/2013 4/11/2013 0.0 Rig up HES slick line unit on well for GLM swap out.Stab on lubricator w/3.80"gauge ring,3'- 1.875"weight bar and quick connect.Test same to 1000 psi,Open well w/29.5 turns. IA 23 psi, OA 400 psi,TBG 800 psi.TIH to 2058'slick line measurement(2082'MD)to SVLN.POOH,lay down gauge ring,pick up 4.5"GS and quick connect to retrieve frac sleeve from SVLN profile. TIH tagged up at 2058'slick line measurement(2082'MD)latch into frac sleeve and pull same. While POOH,the BHA was hanging up on connections.Once out of the hole and inspections of frac sleeve,there was an o-ring missing. It was the big flat o-ring on the top set of o-ring stacks. The next run will be a bristle brush-2.81"centralizer-3'of 1.875"weight bar-2.75"centralizer- quick connect.to retrieve o ring. RIH but did not tag o-ring at 2.082'MD,Continue RIH T/4,000' SLMD,did not tag o-ring,decision made to POOH and commence c/o dummy valves.At surface w/BHA,steel wool was recovered from CT operations.RIH w/4-1/2"GS and catcher sub and set in XN nipple @ 8,486'SLMD(8,512'MD).POOH L/D 4-1/2"GS tool and M/U 4-1/2"OK6 kickout tool.RIH w/same and pull DGLV in GLM#4 @ 7,832'SLMD(7,856'MD). POOH w/dummy.RIH and latch onto DGLV in GLM#3 @ 6,336'SLMD(6,359'MD).POOH. Report for 00:00-06:00 hrs for 4/11/13 continued below. Page 4/6 Report Printed: 12/11/2013 PI 0 N E E R Operations Summary Report - State Well Name: ODSN-29 NAT LIRALRFSOURCFS Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 4/11/2013 4/12/2013 0.0 At 6:00 station 1 GLM valve is set at 2231'MD,2208'SLM. POOH and trip back in the hole to set station 2 GLM valve at 4277'MD,4252'SLM. POOH and trip back in the hole to set station 3 GLM valve.BHA-4.5"OK6 kick over tool-knuckle joint.Ran in the hole to 6359'MD-6336' SLM with same.Located in profile,set down and tap on same. POOH to inspect tools.Once out of the hole,the 1/4"orifice valve was still on the OK6 running tool.after inspection of valve the lower set of packing was damaged.We also had indications that the valve was on seat.Will lower shear value on OK6 tool for next run. Redress packing on orifice valve.At 11:30 Shut down slick line operation till HPBD was pumped on 32i. At 16:00 TIH with station 3 GLM valve to 6359'MD-6336'SLM.Same BHA with one shear pin in tool.Set valve in station#3 GLM @ 6,340'SLMD.POOH(valve set)and trip back in hole w/ GLM#4 valve.Set GLM valve @ 8,486'SLMD. POOH(valve set).M/U BHA to set frac sleeve. Set frac sleeve @ 2,056'SLMD and pressure tested to 500 psi.Report after midnight continued below. 4/12/2013 4/13/2013 0.0 PT on SSCV control line held 500 psi.POOH.Breakoff lubricator.Bottom swab valve had to be regreased in order to remove swab valve above that.Secure well.R/D HES slickline unit and move unit to ODSN-24. 4/30/2013 5/1/2013 0.0 cost placeholder 5/5/2013 5/6/2013 0.0 Rig up Expro, Pressure test lines,Holld pre-job meeting with Expro,operations and Wwellwork supervisor,T/I/O 651/785/465. Start methanol injection,GLR @ 300 mscf/d,open well to Expro. 5/6/2013 5/7/2013 0.0 Continue Flowing ODSN-29 to EXPRO. 24:00 WHP-558 psi/CK-40/IAP-1284 psi/BHP-3021 psi/LG-451 mscf/Gas flow-941 mscfd/Cum gas-128.98 mscf/BOPD-209.76 bbls/BWPD-1887.84 bbls/Cum Oil 128.98 bbls/Cum Wtr-230.91 bbls/ BS&W-90%/Oil-10%/H20-0.2%/Sediment-0.5%/sand at sand trap-1% 05:00 WHP-480 psi/CK-48/IAP-1337 psi/BHP 2789 psi/LG-494 mscf/Gas flow-1015 mscfd/Cum gas-343.23 mscf/BOPD- 1008 bbls/BWPD-2352 bbls/Cum Oil 357bb1s/Cum Wtr-633.7 bbls/ BS&W 70%/Oil-30%/H20-67%/Sediment-0.5%/sand at sand trap-trace. Continue to flow well to EXPRO equipment then to Operations.Begin getting significant amounts of sand from well to the EXPRO sparge tank. Bring in Mini Vac and Cusco. 12:00 WHP-395 psi/CK-48/IAP-1235 psi/BHP 2995 psi/LG-500 mscf/Gas flow-735 mscfd/Cum gas-690.7 mscf/BOPD- 1632.96 bbls/BWPD-1088.6 bbls/Cum Oil 819.34 bbls/Cum Wtr-1096.77 bbls/ BS&W 40%/Oil-60%/H20-39.8%/Solidst-0.2%/sand at sand trap-10% ,Gas lift was then shut off after this reading 17:00 Start Gas lift,WHP-462 psi/CK-48/IAP-1281 psi/BHP 2588 psi/LG-462 mscf/Gas flow-585 mscfd/Cum gas-803.13 mscf/BOPD-2443.54 bbls/BWPD-989.06 bbls/Cum Oil 1357.52 bbls/Cum Wtr-1298.58 bbls/ BS&W 29%/Oil-71%/H2O-28.9%/Solids- 0.1%/sand at sand trap-8% 24:00 WHP-511 psi/CK-48/IAP-1329 psi/BHP 2526 psi/LG-461 mscf/Gas flow-1147 mscfd/Cum gas-1153.98 mscf/BOPD-2624.55 bbls/BWPD-740..26 bbls/Cum Oil 2083.51 bbls/Cum Wtr-1583.69 bbls/ BS&W 22 %/Oil-78%!H2O-22%/Solids-0.1%/sand at sand trap-1% Page 5/6 Report Printed: 12/11/2013 PIONEEROperations Summary Report - State Well Name: ODSN-29 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 5/7/2013 5/8/2013 0.0 Continue flowing thruough Expro 0:00 WHP-511 psi/CK-48/IAP- 1329 psi/BHP 2526 psi/LG-461 mscf/Gas flow-1147 mscfd/Cum gas-1153.98 mscf/BOPD-2624.55 bbls/BWPD-740..26 bbls/Cum Oil 2083.51 bbls/Cum Wtr-1583.69 bbls/ BS&W 22%/Oil-78%/H20-22%/Solids-0.1%/sand at sand trap-1% 05:00 WHP-430 psi/CK 50/IAP-1320 psi/BHP 2432 psi/LG-532 mscf/Gas flow-1351 mscfd/Cum gas-11517.38 mscf/BOPD-2890.95 bbls/BWPD-550.66 bbls/Cum Oil 2601.47 bbls/Cum Wtr-1701 bbls/ BS&W 16%/Oil-84%/H2O-16%/Solids-0.1%/sand at sand trap-trace AT 06:00 sap from flowing to Operations tanks to flowing to Production. 5:00 WHP-501 psi/CK 64/IAP-1325 psi/BHP 2459 psi/LG-468 mscf/Gas flow-1260 mscfd/Cum gas-1879.71 mscf/BOPD-2890.48 bbls/BWPD-70.56 bbls/Cum Oil 3403.7 bbls/Cum Wtr-1744.14 bbls/ BS&W 2%/Oil-98%/H2O-1.85%%/Solids-0.15%/sand at sand trap-trace/ Oil API=18.6 17:00 WHP-503 psi/CK 128/IAP-1335 psi/BHP 2409 psi/LG-488 mscf/Gas flow-1169 mscfd/Cum gas-2132.15 mscf/BOPD-2056.06 bbls/BWPD-109.44 bbls/Cum Oil 3997.33 bbls/Cum Wtr-807.37 bbls/ BS&W 2%/Oil-97%/H20-3%/Solids trace/sand at sand trap- trace. Stop Flowing trhough Expro, flow direct to Production. 5/8/2013 5/9/2013 0.0 Continue flowing well to production not utilizing EXPRO equipment.Rig down EXPRO and move to ODST-47. 5/12/2013 5/13/2013 0.0 MIRU RU W/8'X2.125"STEM,OJ'S&LSS. Stab on wellhead,and PT with Gas to 1000 psi, RIH with QC 3.70"centralizer 2ea 2'X 1.875"WB 3.83 G ring Get only 27 turns,Call Vetco tech, works valve fully open with 29 turns. RIH tag top of frac sleeve @ 2106'SLM,POOH with tools, no sleeve.Change to a different 4.5 GS, RIH Set down at 2160',5 jar licks POOH with sleeve. RIH w/4.5"X LINE&4.5"FXE SSSV.Set down at 2063'SLM,Begin hand jarring,gain control line integrity to 5000 psi,continue jarring down,PU and Shear off POOH.Set lubricator back and replace tree cap. Tubing pressure 866 psi,dump hydraulic to SSSV and have operations bleed down to header pressure of 247 psi,draw down good.Pressure up control line tubing came up to 667 psi,Lay down lubricator and and tools.SSSV is operating properly.Turn Well over to operation to put back on production, SSSV TYPE 22FXE38122,SER#2954672-1 5/13/2013 5/14/2013 0.0 6/12/2013 6/13/2013 0.0 Resman sampling by Halliburton sample catchers. Page 6/6 Report Printed: 12/11/2013 PIONEER NATURAL RESOURCES ALASKA Letter of Transmittal Date: February 7, 2013 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Howard Okland 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— Digital Graphic CDs, logs ❑ Agreement DETAIL QTY DESCRIPTION ODSN-29 (API:50-703-20661-0000) 1 Digital Graphic Log CDs ODSN-29 PB1 (API:50-703-20661-7000) s/ 1 Report ( 1{/�-j 4L 1 25 Well Logs f O SN-29 PB2 (API:50-703-20661-7100) See Details Below We request that all data be treated as confidential information. Thank you. Received by: Date: Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 907-343-2193 fax 907-343-2128 phone 4. 0 February 7, 2013 QTY DESCRIPTION 1 CD Digital Graphic Logs- Digital Data 1 Report GeoTap Pressure Transient Analysis ODSN-29 (API:50-703-20661-0000) DGR, EWR-Phase 4, ALD,CTN, ABG— Inverted Presentation (1:240 & 1:600) 25 Well Logs ROP, DGR, EWR-Phase 4, ALD, CTN, ABG— Horizontal Presentation(1:240 & 1:600) ROP, DGR, EWR-Phase 4, ALD, CTN, ABG— Density Image Presentation (1:240 & 1:600) GeoTap Formation Pressure Tester-Processed Data ODSN-29 PB1 (API:50-703-20661-7000) DGR, EWR-Phase 4, ALD,CTN, ABG— Inverted Presentation (1:240 & 1:600) ROP, DGR, EWR-Phase 4, ALD, CTN, ABG— Horizontal Presentation(1:240 & 1:600) ROP, DGR, EWR-Phase 4, ALD, CTN, ABG— Density Image Presentation (1:240& 1:600) ODSN-29 PB2 (API:50-703-20661-7100) DGR, EWR-Phase 4, ALD,CTN,ABG— Inverted Presentation, Reverted Presentation (1:240 & 1:600) ROP, DGR, EWR-Phase 4, ALD, CTN, ABG— Horizontal Presentation(1:240 & 1:600) ROP, DGR, EWR-Phase 4, ALD, CTN, ABG— Density Image Presentation (1:240& 1:600) • Page 2 RECEIVED PIONEER FEB 272013 NATURAL RESOURCES ALASKA AOGCC Letter of Transmittal Date: February 26, 2013 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Howard Okland 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-29 (API:50-703-20661-0000) ODSN-29 PB1 (API:50-703-20661-7000) ODSN-29 PB2 (API:50-703-20661-7100) 1 Report (,64 ,� eD 0471, 1 Report Surface Data Logging- End of Well Report 12 Well Logs Surface Data Logging -2" MD Gas Ratio Log, CVE Gas Extraction (1:600) Surface Data Logging 2" MD Formation Evaluation Log, CVE Gas Extraction(1:600) Surface Data Logging 2" MD Drilling Engineering Log, CVE Gas Extraction(1:600) Surface Data Logging 5" MD Formation Evaluation Log, CVE Gas Extraction(1:240) We request that all data be treated as confidential information. Thank you. Received by: Date: Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 907-343-2193 fax 907-343-2128 phone icoF T�J� I//7 s, THE STATE Alaska Oil and Gas ° Conservation Commission fALAS}(.A GOVERNOR SEAN PARNELL 333 West Seventh Avenue AS�yD Anchorage, Alaska 99501-3572 AL Main: 907.279.1433 Fax: 907.276.7542 Jody Golding Well Work Supervisor at p T ! 0 6 Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-29 Sundry Number: 313-033 Dear Ms. Golding: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair 1St- DATED fDATED this J1 day of January, 2013. Encl. ii,, RECEIVED 11 ' STATE OF ALASKA2013 ALASKA OIL AND GAS CONSERVATION COMMISSION I't1 )T/ 34 8,6 APPLICATION FOR SUNDRY APPROVALS A G 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension ❑ Operations Shutdown E Re-enter Susp.Well ❑ Stimulate 04 Alter Casing❑ I Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Pioneer Natural Resources Alaska,Inc.• Exploratory ❑ Development 2- 212-106• 3.Address: 700 G Street,Suite 600 Stratigraphic ❑ Service ❑ 6.API Number Anchorage,AK 99501 50-703-20661-00-00- 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? WA ODSN-29. Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036/ADL 389958' 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): • 15716' 6430' . 15,705' 6430' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 4101' 11-3/4" 4140' 3544' 5830 psi 3180 psi Intermediate 1 3314' 9-5/8" 3924'-7238' 3413'-5506' 5750 psi 3090 psi Intermediate 2 9721' r 9759' 6430' 7240 psi 5410 psi Liner 6182' 4-1/2" 9524'-15,706' 6413'-6430' 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 4-1/2", 13.5# P-110,HYD 521 9540' 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 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development D. Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/24/2013' Oil QQ - Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG ❑ Abandoned p Commission Representative: GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact July Golding,343-2179 Email judy.golding©oxd.com Printed Name Judy Golding Title Well Work Supervisor Prepared By:Kathy Campoamor,343-2183 Signature #40._ Phone Date 343-2179 1/21/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 Other: 0 liBDMS FEB 01 1 t, Spacing Exception Required? Yes 0 No 2( Subsequent Form Required: /o- 1/041 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: /- /- /3 0 S Ka1R1 I 2 I Approved application Is valid 12 months from the date of,approval. ?tib 1,yo\aL X30-,3 3�,, ,��4 OtRf&ThIA L Pioneer Natural Resources Alaska Inc. ODSN-29 Page 2 AOGCC Form 10-403, Application For Sundry Approvals Present Well Condition Summary, Box #11 Perforation Depth (MD/TVD) - Attachment 4-W, 13.5#, P-110 Hydril 521 Uncemented Liner MultiPoint Frac Sleeves w/ Segmented Seat: MD TVD 10,179' - 10,182' 6445' - 6445' 10,336' - 10,340' 6444' - 6444' 10,750' - 10,754' 6433' - 6433' 10,909' - 10,913' 6430' - 6430' 11,379' - 11,382' 6415' - 6414' 11,537' - 11,541' 6410' - 6410' 12,231' - 12,235' 6407' - 6407' 12,389' - 12,393' 6409' - 6409' / S eV 12,903' - 12,907' 6415' - 6415' ( I Sc�� 13,059' - 13,063' 6409' - 6409' 13,726' - 13,730' 6417' - 6417' let s 4 - . 13,883' - 13,887' 6423' - 6423' 14,263' - 14,266' 6425' - 6425' 14,421' - 14,425' 6428' - 6428' 14,786' - 14,790' 6429' - 6429' 14,944' - 14,948' 6431' - 6431' MultiPoint Frac Sleeves w/ Solid Seat: MD TT/7D 10,410' - 10,413' 6442' -6442' 11,067' - 11,070' 6427' - 6427' 11,612' - 11,614' 6408' - 6408' 12,506' - 12,509' 6409' - 6409' 13,217' - 13,220' 6402' - 6402' 13,957' - 13,960' 6423' - 6423' 14,495' - 14,498' 6428' - 6428' 15,102' - 15,105' 6432' - 6432' Pressure Activated Sleeves: MD TVD 15,644' - 15,647' �,,,x'6429' - 6429' � 15,698' - 15,700' � €� 6430' - 6430' Pioneer Natural Resources Alaska Inc. ODSN-29 Page 3 AOGCC Form 10-403, Application For Sundry Approvals Present Well Condition Summary, Box #11 Packers and SSSV Type (MD/TVD) - Attachment `XXO' SVLN MD TVD 2082' 2020' ZXP 5" x 7" Hydril 521 Liner Top Packer MD TVD 9,523' — 9,549' 6413' — 6415' Slide-on Type Swell Packer MD TVD 11,770' 6407' ECP Packers MD TVD 9,949' — 9,972' 6436' — 6436' 10,647' — 10,670' 6434' — 6434' 11,178' — 11,201' 6423' — 6422' 12,017' — 12,040' 6407' — 6407' 12,701' — 12,724' 6416' — 6416' 13,370' — 13,394' 6401' — 6403' 13,508' — 13,531' 6408' — 6409' 14,110' — 14,133' 6424' — 6424' 14,648' — 14,671' 6427' — 6428' 15,249' — 15,273' 6431' — 6431' PIONEER NATURAL RESOURCES ALASKA ODSN-29 Frac Ref: Permit To DriII#: 212-106 Current status: ODSN-29 is presently completed and waiting for a fracture treatment. Procedure: 1. MIRU frac tanks. Load tanks with Conoco seawater(estimate 20 tanks per 1MM lbs of sand). 2. Heat and maintain fluids from 100-120 deg F. 3. MIT-IA to 3500 for 15 minutes. Ensure that the test is recorded on the DCS system. (The last MIT on this well was 12/15/12 ) 4. MIRU Halliburton frac pumps and associated equipment. 5. Rig up goat head with 10K spacer spool to ensure line connections are above the well bay. 6. Rig up treating lines to well and pressure test treating iron. 7. Tie hot oil truck into IA and pressure up IA to 3000 psi. Maintain this pressure during all pumping operations. (Tubemove calculations included as 'Attachment A') 8. The well will be fracture stimulated using 2,000,000 lbs of 16/20 ceramic plug proppant in the Halliburton 25#Hybor G-R-21 crosslinked fluid system. A wellbore intersection diagram and modeling for the treatment are attached as 'Attachment B and 'Attachment C'. The fluid system, 25# Hybor G-R, is a water based guar gel system with borate crosslinker. The chemical additives include: a. Crosslink enhancer at 0.3 gpt b. Buffer at 0.5 gpt c. Surfactant at 1 gpt d. Breaker at 2-4 ppt e. Clay controller at 0.5 gpt f. Biocide at 0.25 gpt The clean fluid volumes of 723,752 gallons include 25% pad. The stimulation will target the Nuiqsut reservoir in a 9 stage treatment, using the Baker fracpointsystem with ECP pac�ke5s for isolation between the frac sleeves. A combination of Segmented-Sleeves and one Solid(Ball Seat are used in each stage. The expected treating pressure is 5961 psi at 60 bpm. 9. The final stage will include 38 bbls of LVT to freeze protect the well to 2,500'. (All chemicals will be included on the Frac Focus Disclosure submittal). 10. Rig down frac equipment. 11. Set TWC and change out 10K tree for a 5K tree. Pressure test tree to 5000 psi. Pull TWC. 12. Rig up flowback equipment and CT. 13. RIH with CT to jet tubing and jewelry using slick water and Flo-pro. 14. RD CT and RU slickline. 15. Use slickline and pull the isolation sleeve in SSSV. Install GLV's. 16. RU CT to jet balls with 15%HCL(1000 gallons HCL with additives will be used). Returns will be taken through the Expro equipment. a. RIH to the top ball seat at 10,411' and tag up on ball. Jet with acid until coil falls through solid ball seat. Chase acid with neutralizer so that no"hot" fluids are returned to surface. b. Repeat this procedure through the ball seats as long as losses to the formation are less than 70%. c. When losses approach the 70%, pull above the last ball seat. Swap to extra slick water and Flo-pro. Nitrify fluids so that it is possible to get returns and jet liner with Flo-pro to clean up any residual sand in the liner. d. Chase final Flo-pro slug out of hole at 80%. e. Stop CT at 2,000' and monitor returns through Expro to ensure the well will continue to flow. 17. Flow back well with gas lift through the Expro testing equipment. (Diagram of equipment is 'Attachment D'). During this clean-up period,the goal is to drop the BHP by 200 psi every 24 hrs. This slow drop in BHP should prevent a large influx of frac sand from the formation. 18. When the solids content is below 0.5% for 2 hours, the well can then be diverted into production. 19. RU Slickline and install WRSSSV. General Well Info: MASP - 9500 psi Reservoir pressure/TVD - 3200 psi/6,436' TVD Wellhead Type/pressure rating Vetco MB 233 frac system/5000 psi Tree Configuration Vetco grey 10K dual valve frac tree r MIT-IA/MIT OA MIT-IA: Tested to 3500 psi, 12/15/12 MIT-OA: N/A open OA Cement The 7" casing was cemented with 25 bbls (59 sxs) Class'G' 12.5 ppg Lead slurry with additives and 51 bbls (251 sxs)Class `G' 15.8 ppg Tail slurry with additives.The cement was displaced with 11.2 ppg LSND mud. The plug was bumped with 352 bbls away . The plug was pressured up to 3500 psi and held for 10 minutes. Full returns throughout cementing and displacement. Well Type Producer Estimated Start Date February 25, 2013 Completion Engineer Tim Crumrine Well Site Supervisor Judy Golding Work phone 907-343-2179 Cell 907-231-0872 judy.golding@pxd.com TUBEMOVETM Attachment A BAKER HUGHES Completion Design Analysis ' ojectIn Operator Name: Pioneer Field Name: Oooguruk Well Name: ODSN-29 Rig Name: Wellbore Name: 1 Run#or Condition: Frac Casing;,infor natir"r Top MD Bottom MD Length Tool Name OD Weight ID 0.00 9,500.00 9,500.00 Surface Casing 7.000 26.00 6.276 — —— ,. T o• g forma i.'., Top MD(ft) Bottom MD(ft) Length(ft) Type OD(in) Weight(lbs/ft) ID(in) Material Type Yield Strength(psi) 0.00 9,500.00 9,500.00 Tubing 4.500 12.60 3.958 STEEL 110,000.00 P. r lnf• m.tio'`: Initiation High Space Out Anch.Yes Slack Off(+) Effective Seal PackerType Depth MD(ft) Pressure(psi) (in) or No Tension(-)(lbf) Plug MD(ft) Dia.(in) ELine 9,500.00 0.00 0.00 No 40,000.00 0.00 5.250 Wireline Tool Information Maximum OD: 0.000 in Initial Conditions Annulus Fluid 11t Bottom MD Fluid Weight 9,500.00 10.00 Alullant.... Bottom MD Fluid Weight 9,500.00 10.00 Bottom MD Temperature 0.00 40.00 9,500.00 170.00 Annulus: 0 psi Tubing 0 psi MD(ft) Packer to Tubing Force(Ibf) 9,500.00 40,000 ctual i i . `'e"gement at "•er(Negative • *"--- S' Packer Type MD(ft) Total(in) 1 ELine 9,500.00 -41.60 (if permitted)at Packer(Negative movement is up) Packer Type MD(ft) ton- ens on Buckling(in) Ballooning(In) Temperature(In) Total(in) Compression(in) ELine 9,500.00 41.52 0.08 0.00 0.00 41.60 Initial Landed CoolditioasitNegafve force is Tubing Annulus Safety Factor Tubing Section MD(ft) Force Stress(psi) Pressure Pressure DLS Max Length of (Stress vs. (ibf) (psi) (psi) (degaf100ft) WL Tool(ft) Yield Strength %) Well head 0.00 -22,403 6,222 0 0 0.00 infinity 17.68(5.7%) Eline Packer 9,600.00 51,950 16,054 3,319 3,319 0.00 Infinity 6.85(14.6%) 12/19/2012 5:06:12 PM Baker Oil Tools Inauest"'7U8EMETM v2,0.10000088(5123/2012) Page' Copyright©2006-2008 Baker Hughes,Inc.All Rights FAKER TUBEMOVETM HUGHES Completion Design Analysis Project Informa ', Operator Name: Pioneer Field Name: Oooguruk Well Name: ODSN-29 Rig Name: Wellbore Name: 1 Run#or Condition: Frac Final Conditions +� T Annulus Fluid Weight AMU Bottom MD Fluid Weight 2,000.00 6.90 9,500.00 10.00 Tubing Fluid Weight`" Bottom MD 9,500.00 12.80 Temperature Profile Bottom MD Temperature 0.00 70.00 9,600.00 100.00 Annulus: 3000 psi Tubing 9500 psi MD(ft) Packer to Tubing Force(lbf) Differential Pressure(psi) Torque(lbf.ft) 9,500.00 0 7,749 0 Final Actual Tubing Movement at Packer (Negative movement is up) Packer Type MD(ft) Total(in) ELine 9,500.00 -117.34 Final Theoretical Tubing Movement(if permitted)at Packer (Negative movement is up) Packer Type MD(ft) P(kn Buckling(in) Ballooning(in) Temperature(In) Total(in) ELine 9,500.00 -85.18 -7.86 -50.14 -15.73 -158.91 Combined Movtglatiall `" Adjusted initial Actual High Space Out(in) Final Theoretical Final Position(in) Movement(in) Movement(in) 41.60 0.00 -158.91 -117.31 Final Landed Conditions(Negative force is tensile'"" Tubing Annulus afety-Factor Tubing Section MD(ft) Force(lbf) Stress DLS Max Length of (Stress vs. Pressure Pressure (psi) (psi) (psi) (degal100ft) WL Tool(ft) Yield Strength %) Well head 0.00 19,652 60,440 9,500 3,000 11 37.01 1.82(54.9%) Eline Packer 9,500.00 94,006 87,853 13,748 5,9991 21 26.98 1„ ikc.e: There arc stresses that exceed maximum tubing yield strengkh.Please check your input anu result carefully. 12/19/2012 5:06:13 PM Baker Olt Tools inauest'"10BEMOVE'"v2.0.10000.88(612312012) Page 2 Copyright®2006-2C08 Baker Hughes.Inc.All Rights Reserved • Attachment B Pioneer Natural Resources Inc.Alaska Asset Fracture Modeling Study-Nuiqsut Background The Alaska Oil and Gas Conservation Commission (AOGCC) has requested that fracture modeling is conducted on the Nuiqsut reservoir to determine height growth. Height growth of the induced hydraulic fracture is an important parameter to determine whether the fracture grows beyond the defined oil pool confining sedimentary rock layers violating pool rules (Oooguruk-Nuiqsut Pool) or Area Injection Order 034 in order to ensure protection of surrounding reserves. Pioneer has contracted a third party, Barree and Associates, LLC to conduct the fracture modeling study using the software program GOHFER. A meeting was held on December 17, 2012 at the AOGCC office in Anchorage, Alaska with AOGCC representatives, Chris Wallace, Guy Schwartz, Patricia Bettis, and Steve Davies, and Pioneer representatives Tim Crumrine, Andy Bond, Pat Foley, and Vern Johnson. The meeting discussion centered on conducting a fracture study that would be inclusive of all potential fracture stimulation rates and pressures, so that each individual well would not be modeled,but instead one model could be built in which the rates and pressures would exceed the capabilities of fracturing equipment hydraulic horsepower on location at the time of the fracture stimulation. This study is intended to cover all hydraulic fracture stimulations in the Nuiqsut oil pool, propped and unpropped(often referred to as high pressure breakdowns)in either producing or water injection wells. The following sections discuss the model input assumptions and the results from the induced hydraulic fracture study. Model Inputs and Assumptions `/ Nuiqsut producing wells will be stimulated with two-million lbs of 16/20 mesh Carbolite ceramic proppant with approximately 200,000 lbs per stage for a total of 10 stages. Each producer well completion is set up to be mechanically or dynamically diverted, with some wells having a combination design. The greatest likelihood for a fracture to grow out of its confining intervals comes from a well with a vertical wellbore and a limited entry single perforation near the top or bottom of the interval being stimulated. Pioneer Alaska's wells are horizontal wells with multiple entry points that are landed in the middle of the zone. Essentially fractures in this type of wellbore are much less prone to fracturing out of zone. Each stage will contain approximately 200,000 lbs of 16/20 mesh Carbolite ramped from 0.5— 10 ppa concentration with a 25 ppt cross-linked borate gel. The hydraulic horsepower on location during a fracture stimulation is approximately 12,000 HHP— based on anticipated pressures and rates. This equates to a rate limit of 60 barrels per minute based on expected pressures. Rates for the fracture modeling study were set at a limit of 80 barrels per minute: well above the available hydraulic horsepower on location. High pressure breakdown/scour treatments will be performed on injector wells with no more than 20,000 — 50,000 lbs of 20/40 mesh Carbolite proppant per stage. The injector well completions have smaller upper completions that limit the rate to 25 barrels per minute and are dynamically diverted. The fracture model geological input parameters were based on the Kalubik-1 well log data. Log data from the Kalubik-1 well were processed to derive rock mechanical properties and a stress profile for the fracture growth modeling. Based on previous MDT/RFT measurements, the pore pressure in the Nuiqsut was assumed to be on an effective 0.51 psi/ft gradient. No tectonic boundary conditions were applied to the stress profile. The Nuiqsut zone is shown in the figure below by the blue box. The two arrows indicate the upper and lower landing positions assumed for the modeling. These two fracture initiation sites are expected to represent any landing point in the zone. Kalubik 1 Processed Log Summary CM •Rr:' FM '10M _01-# ettEt.tprq :.1: .rat _ •.•.• r t ......,.......,• . .....,,......: 6300 00 _ - — -lit 6325 00 • -- 4 - fad. r- 6350 00 -- __— - -_=.___;: 637500 _ '" a�.re ��ms. �•• ' la �, 640000 - •. 4.?, 6425 00 — VIM .w _ i• ImIr -- 8450 00 .. f'•� 6475 00 t 3 1= 8500 00 __ _, .a:•: , • ' ' Nechelik —Li— 6525 00 = 7-75: — Esso a0 , --._,,��••••. ji- 6575 00 _ _� .-,.a_ - 6600 00 8".11 �" "-fie_ ,•. a 8825 00 C 2012 1e r� =- 665000 ..— :c. " Figure 1. Kalubik-1 Processed Log Summary Modeling Results The proppant profile(side view)of the created vertical fracture in the upper part of the Nuiqsut is shown in the color-filled plot below. See Figure 2. The scale is 0-3 lb/ft2, shown at right.The fracture stays contained in the Nuiqsut at a maximum 80 bpm pump rate. 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EID= 1 ssr 1 ce.wtr rig.eox Ta w.rMm xe.ew r n1 aoz t ___ __ .. 1 -Y— n S. . 1 O 1ID L I b E 2" ------.s•.r Z1 a rn z rn rn ON —I c ....... —+ 1 o rn 1 CCD m2 • C-0N c. — �3 rn ns (Z r--1 Zr-9 m 2to � O c m —_� -1 s —9e s I m I A I I ODSN-29 Nuiqsut Production Well Completion Updated 12/20/2012 A I , Upper CompletionMQMat 16"Conductor 1)Tubing Hanger 43' 43' 2)4'/"13.5#/ft Hydril 521 Tubing Packer Fluid mix: 3)4-/ Halliburton'XXO'SVLN w/3.813""X"profile RTS-8 2082' 2020' I Inhibited Kill weight with singlet/4"x 0.049"s/s control line. Cannon Cross-coupling clamps on every joint CDI 3 • Brine 4)4-'/:"13 5#/ft Hydril 521 Tubing with 2000' TVD 5)4-Yz'x 1"GLM, KBMG Hydril 521 w/SOV 2231' 2155' h I diesel cap 6)4-'/:"13.5#/ft Hydril 521 Tubing 7)HES X 3.813" 2299' 2208' 8)4-W 13.5#/ft Hydril 521 Tubing • 9)4-%"x 1"GLM,KBMG Hydril 521 w/DV 4277' 3635' 10)4-W 13.5#/ft Hydril 521 Tubing 11)4-1/2"x 1"GLM, KBMG Hydril 521 w/DV 6359' 4957' 11-3/4"60 ppf L-80 BTC 12)4-%"13.5#/ft Hydril 521 Tubing Surface Casing 13)4-Yi'x 1"GLM, KBMG Hydril 521 w/DV 7856' 5900' I @ 4140' MD/3544'TVD 14)4-14 13.5#/ft Hydril 521 Tubing GL© _ J 15)HES XN 3.813"(3.725"NoGo)-with RHC Plug 8512' 6265' ' cemented to surface 16)4-A 13.5#/ft Hydril 521 Tubing i _ 17)4-1/2"Halliburton'ROC'Gauge Carrier w/1/4"x 0 049"s/s control line 8617' 6306' o I1 18)4-W 13.5#/ft Hydril 521 Tubing 19)Bullet Seal Assembly with Ratcheting Mule Shoe 9538' 6413' Bottom of Shoe 9540' 6414' GLj 0 I \ 9-5/8"40 ppf L-80 Hydril 521 Intermediate 1 Casing @ 7238' MD /5506'TVD O cL ,4I 4-1/2" 13.5 ppf P-110 Hydril 521 Tubing 13 GL J k 0 IXN1 Iiiii. !ii r Je;E TOC Estimated `I. 500'above top of ii'iL• Kuparuk vil,i qvi '''!i. \ * .. ,4:. e•s. ;' Fault @ 13,470' MD 32 44 �� O 54 56 66 (Dia 60 90 �� 7" 26 ppf L-80 BTC- �'®; II 50 - ...1 C Mod + Hydril 521 '®''''71-447 z6 ;44/ 111-1 - _ :-I - -:- - `- - - - I-:1- I : / Intermediate 2 =_ - Casing _ @ 9759' MD/6430' 411) 1 TVD Fault @ FAILED ECP 11,980 ft MD 6-1/8" Hole TD at at 15716'MD/ 4-Y2" Hydril 521 Liner with Baker Hughes Multi- 6430'TVD Point Frac Sleeves(3 per stage) isolated with ECP's+ Resman Carriers ODSN-29 Nuiqsut Production Well Completion Updated 12/20/2012 Lower Comoletion MI2 TVQ 20)Baker 5-14"X 7"ZXP Liner Top Packer with 15ft Tie Back 9524' 6413' I , 16" Conductor extension and Flex Lock Hanger 21)4-Y2"13.5#/ft Hydril 521 Liner Packer Fluid mix; /2 22)Baker ECP Packer(4-'/z"Hydril 521) . InhibitedKill weight23)4- 13.5#/ft Hydril 521 Liner 24)Baker Multi-Point Frac Sleeve with segmented ball seat(3.000 ball/2.948 Seat) 10179' 6445' rnn pIaxBrine 25)4-14 13.5#/ft Hydril 521 Liner • with 2000'TVD 26)4-'4"Resman Tracer Carrier w/15 ft pups on each side I„ diesel cap 27)4-'/:"13.5#/ft Hydril 521 Liner mw,an 28)Baker Multi-Point Frac Sleeve with segmented ball seat(3.000 ball/2.948 Seat) 10336' 6444' 1 29)4-%"13.5#/ft Hydril 521 Liner 30)Baker Multi-Point Frac Sleeve with solid ball seat(3.000 ball/2.948 Seat) 10411' 6442' 31)4-1/2"13.5#Ift Hydril 521 Liner Aliglag 32)Baker ECP Packer(4-Y:"Hydril 521) 10647' 8434' 11-3/4" 60 ppf L-80 BTC 33)4-'%"13.5#/ft Hydril 521 Liner i Surface Casing 34)Baker Mufti-Point Frac Sleeve with segmented ball seat(2.938 ball/2.885 Seat) 10751' 6433' 5 I @4140' MD/3544'TVD 35)4-'/z"13.5#/ft Hydril 521 Liner 36)4-'14"Resman Tracer Carrier w/15 ft pups on each side I. 7... cemented to surface 37)4-14'13.5#/ft Hydril 521 Liner 38)Baker Multi-Point Frac Sleeve with segmented ball seat(2.938 ball 12.885 Seat) 10910' 6430' 7 39)4-Y2"13.5#/ft Hydril 521 Liner 40)4-W Resman Tracer Carrier w/15 ft pups on each side 41)4-'/°13.5#Ift Hydril 521 Liner • 42)Baker Multi-Point Frac Sleeve with solid ball seat(2.938 ball/2.885 Seat) 11068' 6427' 43)4-Y2"13.5#/ft Hydril 521 Liner 44)Baker ECP Packer(4-W Hydril 521) I" 9-5/8"40 ppf L-80 Hydril 521 45)4-Y2"13.5#/ft Hydril 521 Liner 46)Baker Multi-Point Frac Sleeve with segmented ball seat(2.875 ball/2 823 Seat) 11379' 6415' Intermediate 1 Casing 47)4-W 13.5#/ft Hydril 521 Liner @ 7238' MD/5506'TVD 48)4-14"Resman Tracer Carrier w/15 ft pups on each side 49)4-Y2"13.5#/ft Hydril 521 Liner 50)Baker Multi-Point Frac Sleeve with segmented ball seat(2.875 ball/2.823 Seat) 11538' 6410' 51)4-Y"13.5#/ft Hydril 521 Liner i 1 4-1/2" 13.5 ppf 52)Baker Multi-Point Frac Sleeve with solid ball seat(2.875 ball/2.823 Seat) 11612' 6408' P-110 Hydril 53)4-Y2"13.5#/ft Hydril 521 Liner 54)4-Mt"13.5#lft Hydril 521 Liner with 2 HLB slide on centralizers 11756' 6407' 521 55)4-Y2"13.5#/ft Hydril 521 Liner Tubing 56)Baker ECP Packer(4-W Hydril 521) • 57)4-1/2"13.5#/ft Hydril 521 Liner 13 58)Baker Multi-Point Frac Sleeve with segmented ball seat(2.813 ball/2.760 Seat) 12231' 6407' 59)4-'/2"13.5#/ft Hydril 521 Liner " I 60)4-Yz Resman Tracer Carrier w/15 ft pups on each side 15 Ili'. 61)4-W 13.5#/ft Hydril 521 Liner f' I Inti 62)Baker Multi-Point Frac Sleeve with segmented ball seat(2.813 ball/2.760 Seat) 12389' 6409' •GI iio rl' 63)4-1/2"13.5#/ft Hydril 521 Liner 111° 64)Baker Multi-Point Frac Sleeve with solid ball seat(2.813 ball/2.760 Seat) 12506' 6409' '1`. TOC Estimated •ly. 65)4-Y2"13.5#/ft Hydril 521 Liner !i, 500'above top of 66)Baker ECP Packer(4-W Hydril 521) iiilli Fl, Kuparuk 67)4-Y2"13.5#/ft Hydril 521 Liner gill 68)Baker Multi-Point Frac Sleeve with segmented ball seat(2.750 ball/2.698 Seat) 12903' 6415' '(ir; 69)4-'/2 13.5#/ft Hydril 521 Liner 70)4-',4"Resman Tracer Carrier w/15 ft pups on each side 12977' 6412' 0 71)4-Y2"13.5#/ft Hydril 521 Liner 72)Baker Multi-Point Frac Sleeve with segmented ball seat(2.750 ball/2.698 Seat) 13060' 6409' 73)4-'4"13.5#/ft Hydril 521 Liner / .. 74)4-W Resman Tracer Carrier WI 15 ft pups on each side 13134' 6405' Iliii _i� 75)4-'A 13.5#/ft Hydril 521 Liner ,,,,,0 l:/, Fault @ 13,470' MD O 54:/i) 86 78 80 90 0435, 7" 26 ppf L-80 BTC- 111 £4k/ EIIIE -II 7. 2 Intermediate 2 Casing @ 9759'MD/6430' 1CO TVD Fault @ I FAILED ECP 11,980 ft MD 6-1/8" Hole TD at 4-'/2" Hydril 521 Liner with Baker Hughes Multi-Point at 15716' MD/ Frac Sleeves(3 per stage)isolated with ECP's+ 6430'TVD Resman Carriers ODSN-29 Nuiqsut Production Well Completion Updated 12/20/2012 I J"ower Completion MQ 13t12 111;;;; 16"Conductor 76)Baker Multi-Point Frac Sleeve with solid ball seat(2.750 ball/2.698 Seat) 13218' 6402' ill 77)4-'1/2"13.5#/ft Hydril 521 Liner `l'•,j I Packer Fluid mix: 78)Baker ECP Packer(4-%"Hydril 521) 13370' 6402' til1J 79)4-11/2"13.5#/ft Hydril 521 Liner ;;F Inhibited Kill weight 80)Baker ECP Packer(4-W Hydril 521) 13508' 6408' ; $ I Brine 81)4-'/2"13.5#/ft Hydril 521 Liner ii _-.,., with 2000'TVD 82)Baker Multi-Point Frac Sleeve with segmented ball seat(2.688 ball/2.635 Seat) 13727' 6417' Mil :• -r diesel cao 83)4-W 13.5#/ft Hydril 521 Liner • / 84)4-W Resman Tracer Carrier w/15 ft pups on each side • 6420' ,, 85)4-'h"13.5#/ft Hydril 521 Liner 86)Baker Multi-Point Frac Sleeve with segmented ball seat(2.688 ball/2.635 Seat) 13884' 6423' 11116 87)4-'/2"13.5#/ft Hydril 521 Liner 88)Baker Multi-Point Frac Sleeve with solid ball seat(2.688 ball/2.635 Seat) 13958' 6423' 11-3/4"60 ppf L-80 BTC 89)4-1/2"13.5#/ft Hydril 521 Liner Surface Casing 90)Baker ECP Packer(4-1/2"Hydril 521) 14110' 6424' GL I @ 4140' MD/3544'TVD 91)4-v2"13.5#/ft Hydril 521 Liner © _ 92)Baker Multi-Point Frac Sleeve with segmented ball seat(2.625 ball/2.573 Seat) 14263' 6425' cemented to surface 93)4-'1/2"13.5#/ft Hydril 521 Liner 94)4-'1/2W Resman Tracer Carrier WI 15 ft pups on each side 14339' 6426' O x ''I 95)4- "13.5#Ift Hydril 521 Liner ililiI 96)Baker Multi-Point Frac Sleeve with segmented ball seat(2.625 ball/2.573 Seat) 14422' 6428' iiiii Pi 97)4-%2"13.5#/ft Hydril 521 Liner pi 98)Baker Multi-Point Frac Sleeve with solid ball seat(2.625 ball/2.573 Seat) 14496' 6428' 99)4-'/2"13.5#/ft Hydril 521 Liner iiiii GL I 100)Baker ECP Packer(4-%"Hydril 521) 14648' 8427' 0 I h. 9-5/8"40 ppf L-80 Hydril 521 101)4-'i2"13.5#/ft Hydril 521 Liner 102)Baker Multi-Point Frac Sleeve with segmented ball seat(2.563 ball/2.510 Seat) 14787' 6429' Intermediate 1 Casing 103)4-%2"13.5#/ft Hydril 521 Liner @ 7238' MD/ 5506'TVD 104)4-'/z Resman Tracer Carrier w/15 ft pups on each side 105)4-'/2"13.5#/ft Hydril 521 Liner 106)Baker Multi-Point Frac Sleeve with segmented ball seat(2.563 ball/2.510 Seat) 14945' 6431' 107)4-'/2"13.5#/ft Hydril 521 Liner 11 GL 4-1/2" 13.5 ppf 108)4-'1/2"Resman Tracer Carrier w/15 ft pups on each side P-110 Hydril 109)4-'/2"13.5#/ft Hydril 521 Liner 521 110)Baker Multi-Point Frac Sleeve with solid ball seat(2.563 ball/2.510 Seat) 15102' 6432' 111)4-'/2"13.5#/ft Hydril 521 Liner Tubing 112)Baker ECP Packer(4-1/2"Hydril 521) 15249' 6432' 113)444"13.5#/ft Hydril 521 Liner 13 GL 'i( 114)4'/z 13.5#/ft Hydril 521—10 ft Pup +°1` 115)4-%2"Resman Tracer Carrier w/15 ft pups on each side 15469' 6431' 0xry I 116)Pressure Activated Sleeve"B"5,800 psi 15644' 6430' 117)Pressure Activated Sleeve"A"5,600 psi 15698' 6430' 118)Wellbore Isolation Valve"WIV" 15700' 6430' GI r Hx 111, 119)Eccentric Shoe 15705' 6430' =_ ; TOC Estimated Bottom of Shoe 15706' 6430' iiiiii 500'above top of Ng: $ Kuparuk 0 \ ♦.'sl -0 0 Fault 13,470'MD 32 44 54 ' S6 66 78 80 90 7" 26 ppf L-80 BTC ®' �:"_.. 50 I■ ■ -■ Mod+ Hydril 521 2e „7444:' - _ _ _ _ _ _ _ - _ _ _ -:I- -...-1- 1-_,„, _ _ __ _ Intermediate 2 - - -�I- - - _ - ' �_ l=I - 2 Casing ® A_ ---__ -- 1 Z__-- @ 9759'MD/6430' T TVD Fault @ 4111) FAILED ECP 11,980 ft MD 6-1/8" Hole TD at at 15716' MD/ 4-1/2"Hydril 521 Liner with Baker Hughes Multi-Point 6430'TVD Frac Sleeves(3 per stage) isolated with ECP's+ Resman Carriers STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil ❑., • Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 2OAAC 25.110 Development ❑- Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: _One Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Aband.: 12/912012- 212-106- 3.Address: 700 G Street,Suite 600 6.Date Spudded: 13.API Number: Anchorage,AK 99501 10/15/2012• 50-703-20661-00-00 • 4a.Location of Well(Govemmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 2992'FSL, 1075'FEL,Sec. 11,T13N, R7E,UM. 12/1/2012 ODSN-29' Top of Productive Horizon: 8. KB(ft above MSL):• 56.2'• 15.Field/Pool(s): 2813'FSL,3705' FEL,Sec. 1,T13N, R7E, UM GL(ft above MSL): 13.5'• Total Depth: 9.Plug Back Depth(MD+TVD): Oooguruk-Nuigsut Oil Pool 1756'FSL,2617 FEL,Sec.35,T14N,R7E,UM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 469923.95• y- 6031108.44• Zone-ASP4 • 15,716'MD/6430'TVD ADL 355036/ADL 389958 TPI: x- 472584.08 y- 6036197.82 Zone-ASP4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 468416.07 y- 6040436.83 Zone-ASP 4 • 2087 MD/2020'TVD 417497 18.Directional Survey: •Yes Q No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) - N/A (ft MSL) 835'MD/827'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drillLateral Top Window MD/TVD: Gyro,MWD/LWD,DIR,DGR,DDSr,ABI,ABG,EWR,PWD,GABI,ALD,CTN,DDS-DGR,DM,Geo-Tap N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 109# H-40 Surface 158' Surface 158' 24" Driven L-80 / 11-3/4" 60# BTC-mi Surface 4140' Surface 3544' 14-1/2" 452 sx PF'12;635 sx Class'G' HYD 521 L-80 / 80 sx, 12.5 9-5/8" 40# BTC-M/ 3924' 7238' 3413' 5506' 11-3/4" ppg,Class'G' HYD 511 172 sx, 15.8 ppg, Class'G' L-80 / 7" 26# BTC-M/ Surface 9759' Surface 6430' 8-1/2" 59 sx, 12.5 ppg,Class'G' HYD 511 251 sx, 15.8 ppg, Class'G' 4-1/2" 13.5# HYD 521 9524' 15,706' 6413' 6430' 6-1/8" Uncemented 24.Open to production or injection? Yes ❑ No ❑ 25. TUBING RECORD If Yes,list each interval open(MD+TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 4-1/2", 13.5#, P 110Hyd 521 9540' See Attachment,pg.3 RECEIVED. ` ACID,FRACTURE,CEMENT SQUEEZE, ETC. �µ`.' `.C•'•Q''' See Attachment, pg.2 Was hydraulic fracturing used during completion? Yes❑ No O ' DEC 2 1 2012 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED ./4 . a� r AUGCC 2416' Freeze Protect 11-3/4"x7"annulus w/150 bbls diesel Freeze Protect 4-1/2 tbg&7"annulus w/90 bbls diesel 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period -♦ Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. ,24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No❑✓ 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. ' • •• ‘ , ,I.. -I r, None ?clw G Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only13 XK ,iC 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes .❑ No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top 862' 854' needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1697' 1669' Top West Sak 2565' 2433' Brookian 2B 5379' 4331' Top Torok 6610' 5110' None Top HRZ 7805' 5865' Kalubik 8150' 6075' Top Kuparuk C 8263' 6139' BCU 8742' 6342' Top Nuiqsut 9594' 6418' Formation at total depth: 15,716' 6430' 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 Email: alex.vauohan(ftxd.com Printed Name: Alex Vau•hanTitle: Sr. Drilling Engineer Signatur=i' / � Phone: 343-2186 Date: 12/21/2012 Well Name/Number:ODSN-2' Permit .'Drill:212-106 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 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-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 10/2012 Pioneer Ndlural Resources Alaska Inc. ODSN-29 Page 2 AOGCC Form 10-407 Well Completion or Recompletion Report and Log Open to Production or Injection Box #24 - Attachment 24. Open to production or injection 4-W, 13.5#, P-110 Hydril 521 Uncemented Liner MultiPoint Frac Sleeves w/ Segmented Seat: MD TVD 10,179' - 10,182' 6445' - 6445' 10,336' - 10,340' 6444' - 6444' 10,750' - 10,754' 6433' - 6433' 10,909' - 10,913' 6430' - 6430' 11,379' - 11,382' 6415' - 6414' 11,537' - 11,541' 6410' - 6410' 12,231' - 12,235' 6407' - 6407' 12,389' - 12,393' 6409' - 6409' 12,903' - 12,907' 6415' - 6415' 13,059' - 13,063' 6409' - 6409' 13,726' - 13,730' 6417' - 6417' 13,883' - 13,887' 6423' - 6423' 14,263' - 14,266' 6425' - 6425' 14,421' - 14,425' 6428' - 6428' 14,786' - 14,790' 6429' - 6429' 14,944' - 14,948' 6431' - 6431' MultiPoint Frac Sleeves w/ Solid Seat: MD TVD 10,410' - 10,413' 6442' - 6442' 11,067' - 11,070' 6427' - 6427' 11,612' - 11,614' 6408' - 6408' 12,506' - 12,509' 6409' - 6409' 13,217' - 13,220' 6402' - 6402' 13,957' - 13,960' 6423' - 6423' 14,495' - 14,498' 6428' - 6428' 15,102' - 15,105' 6432' - 6432' Pressure Activated Sleeves: MD TVD 15,644' - 15,647' 6429' - 6429' 15,698' - 15,700' 6430' - 6430' I Pioneer Natural Resources Alaska Inc. ODSN-29 Page 3 AOGCC Form 10-407 Well Completion or Recompletion Report and Log Packer Set (MD/TVD), Box #25 - Attachment ZXP 5" x 7" Hydril 521 Liner Top Packer MD TVD 9,523' — 9,549' 6413' — 6415' Slide-on Type Swell Packer MD TVD 11,770' 6407' ECP Packers MD TVD 9,949' — 9,972' 6436' — 6436' 10,647' — 10,670' 6434' — 6434' 11,178' — 11,201' 6423' — 6422' 12,017' — 12,040' 6407' — 6407' 12,701' — 12,724' 6416' — 6416' 13,370' — 13,394' 6401' — 6403' 13,508' — 13,531' 6408' — 6409' 14,110' — PI 0 N E E R Operations Summary Report - St Well Name: ODSN-29 NATURAL RESOURCES Well Name: ODSN-29 Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: ORIG DRILL&COMPLETE Start Date: 10/14/2012 End Date: Start Depth Foot/Meters Dens Last Start Date End Date (EKE) (ft) Mud(Ib/gal) Summary 10/14/2012 10/15/2012 0.0 RD all stairs,landings and berms.Make all preparations to move rig.Move Nabors 19AC from ODST-45A to ODSN-29.Spot rig over the well and level subs and mud pits--RU same. NU starting flange,surface riser and flow line.Change out top drive handling equipment from 4"XT- 39 to 4 1/2"I.F.Clear rig floor of all 4"handling tools and stage BHA subs on rig floor.RU 5" handling tools. PU 5"DP in mouse hole and rack back in derrick. 10/15/2012 10/16/2012 158.0 379.00 9.55 PU 5"DP and HWDP in mouse hole and rack back in derrick.MU bit,motor and 1 stand HWDP to clean out conductor.Fill riser and check same for leaks,test pump lines to 3000 psi--Good test.Tag bottom at 42'and clean out conductor 0158'.Rack back HWDP and LD motor and bit. Spot ESP spool for gyro unit and RU all Gyro equipment.MU BHA#1 for spud.Directionaldrill_ new 14-1/2"surface hole f/158't/225'.PU MWD tools,up load same and scribe BHA.Directional drill 14-1/2"surface hole f/225't/537'. 10/16/2012 10/17/2012 537.0 1,615.00 9.40 Directional drill new 14-1/2"surface hole f/537't/2,152'. 10/17/2012 10/18/2012 2,152.0 1,086.00 9.50 Directional drill new surface hole(/2,152'112,437'.Pump 40 bbl hi-vis sweep and CBU hole clean 2x.POOH f/2,437'U surface.Reconfigure BHA and TIH with same t/1,880'--tight spot.Ream in the hole f/1,880'112,437'.Directional drill f/2,437'113,238'. 10/18/2012 10/19/2012 3,238.0 907.00 9.60 Directional drill new 14-1/2"surface hole f/3,238'U4,145'.Circulate hole clean and condition mud for casing run.Rack back 1 stand every bottoms up f/4,145'U3,869'.Pump 100 bbl SAPP pill and carbide bomb;strokes indicate12.72"hole. Pumped second carbide bomb;strokes indicate 12.75"hole.POOH(/3,869'112,537'. Back ream and circulate bottoms up f/2,537'112,442'. POOH f/2,442'U surface. Note:Gave AOGCC 24 hour notice of BOP test at 0100 hrs 10/19/12. 10/19/2012 10/20/2012 4,145.0 0.00 9.50 RU 11 3/4"casing equipment and casing running tool.RIH with 11 3/4"60# L-80 casing f/ surface 11790'.Rotate and circulate to work casing pasfleide x1790'.RIH with 11 3/4"60# L-80 casing f/790'112,533'.Attempt to work casing past ledge-washed f/2,533'112,536'.RU rig floor,/ to POOH laying down casing.POOH laying down 11 3/4"casing f/2,536'11975'. 10/20/2012 10/21/2012 4,145.0 0.00 9.45 POOH with 11 3/4"casing and LD same.MU clean out BHA#3 and RIH.Work thru tight spot at 2,536'. Ream down to TD at 4,145'.Circ and cond hole. Pump dry job.POOH wiping several tight spots U3,420'-no further progress. RIH 113,774'. Start backreaming out 113,583'. 10/21/2012 10/22/2012 4,145.0 0.00 9.50 Backream out of hole f/3,583'111,680'.POOH on elevators to surface and LD BHA components. RU and run 11-3/4"60#L-80 BTC-M Hydril 521 surface casing 111,988'. Break circ up to 8 bpm and CBU 2x.Cont RIH 113,119'.Break circ. Note:Gave AOGCC 24 hour notice of BOP test at 1000 hrs 10/21/12. 10/22/2012 10/23/2012 4,145.0 0.00 9.50 CBU 2x at 3,119'.Continue running 11 3/4"casing and land with shoe at 4,139.7'.Break circ and stage up to 12 bpm @ 500 psi.Drop carbide pill and pump around-came back 49 bbls early. cA„jtl_ RU to cement.Pump 10 bbls seawater.Test lines to 4000 psi. Load top plug. Pump 100 bbls J�� 10.0 ppg Tuned Spacer @ 5 bpm. Release 2nd btm plug.Pump 356 bbls(452 sx)10.7 ppg Permafrost'L'lead slurry with 0.15%D-Air 5000P at 5 bpm. Pump132 bbls(628 sx)of 15_8 ppg Premium'G'tail slurry with 1%CaCl2 and 0.2%CFR-3 at 2.5 bpm.Lost returns after pumping 65 bbls tail slurry away and re-gained returns after 105 bbls away. Release top plug and clear lines with 20 bbls seawater.Switch to rig pump and displace with 442 bbls mud at 12 bpm.Bump plug with 3500 psi. Bleed off pressure-floats held.CIP @ 12:20 hrs. Got back 18 bbls 10.7 ppg slurry to surface. Monitor well f/30 min. RD cement head,cement lines&casing tools. ND riser and spacer spools. NU 11 3/4"drilling adapter&BOPE. NOTE:Witness of BOP test waived by AOGCC Rep John Crisp at 17:00 hrs on 10/22/2012. Page 1/7 Report Printed: 12/21/2012 PI O N E E R Operations Summary Report - Str Well Name: ODSN-29 : : kL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 10/23/2012 10/24/2012 4,145.0 20.00 10.55 Test BOPE as per AOGCC PTD.Test upper and lower VBR w/5"test joint to 250 psi low/4500 psi high.Test upper and lower IBOP valves to 250 psi low/4500 psi high.Test annular w/5"test joint to 250 psi low/2500 psi high.Test all floor valves to 250 psi low/4500 psi high.Test 14 choke manifold valves to 250 psi low/4500 psi high. Initial system psi:3000;2000 after closure; 200 psi=25 sec,full pressure 1 min.58 sec. MU clean out BHA#4. RIH PUDP.Wash down to 4,050'.CBU.Test casing to 3500 psi for 30 min-good test.Drill out shoe track and clean out rat hole t/4,145'MD.Displace hole to 10.6 ppg MOBM.Drill 20'of new hole t/4,165'MD.Perform FIT to 12.7 ppg EMW.POOH t/1,010'.Cut drilling line.Continue POOH&LD BHA. 10/24/2012 10/25/2012 4,165.0 764.00 10.55 LD BHA#4 and PU drilling BHA#5-GeoPilot.RIH t14,074'and wash down to btm at 4,165'. Drill t/4,245'.Activate underreamer and pull test against casing shoe.Drill 11 3/4"new intermediate) hole f/4,245'[/4,929'MD. 10/25/2012 10/26/2012 4,929.0 1,381.00 10.65 Continue drilling 11 3/4"new intermediate) hole f/4,929'06,310'MD. 10/26/2012 10/27/2012 6,310.0 960.00 10.60 Continue drilling 11 3/4"new intermediate) hole to TD at 7,270'MD/6,627'TVD.Perform quadrant reaming on btm of hole with RSS at full deflection to open up rat hole below reamer depth.Close underreamer cutters.Pump steel seal/CaCO3 pill and continue circulating 800 gpm to condition hole for 9 5/8"casing. 10/27/2012 10/28/2012 7,270.0 0.00 10.60 Continue CBU hole clean 7x.POOH pumping 2 bpm.Work and wipe various tight spots.POOH 05,095'.Packed off while wiping one tight area. RIH 05,405'.Break circ.Stage up pumps and CBU.POOH f/5,405'U4,074'.CBU lx and pump 50 bbls HV sweep to surface.Continue to circ hole clean at 11 3/4"shoe.Make 5 stand check trip into casing(/4,074'113,599'. RIH f/3,599'U TD at 7,270'.Stage pumps up and CBU.Pump HV sweep to surface and continue to circulate hole clean. 10/28/2012 10/29/2012 7,270.0 0.00 10.60 Continue CBU 7x total until shakers at background level.POOH f/7,270'11±4560'while pumping 1 bpm, 100 psi and rotating 10 rpm.Break circ and work through tight spot at 4,560'until cleaned up.Continue to POOH[/4,074'.Pump 90 bbls HV sweep to surface and circulate until shakers cleaned up.POOH on elevators f/4,074'U surface.LD BHA.Change bottom rams f/2 7/8"x 5" variables to 9 5/8".Test 9 5/8"rams to 250 psi low/4500 psi high f/5 charted min each test.RD test equipment.Clear floor.RU Tesco Casing equipment. 10/29/2012 10/30/2012 7,270.0 0.00 10.60 Continue to RU casing equip. PU shoe track.Fill pipe&check floats.Continue to RIH w/9 5/8" 40#L-80 Hyd 521 casing U7,187'. Break circulation w/1/2 bpm and stage up to 4 bpm.Circulate &rotate down 117,239'. Experiencing tight hole and packing off at 7,239'.Decision made to set liner hanger and cement at 7,238'. 10/30/2012 10/31/2012 7,270.0 0.00 10.60 Set 9 5/8"liner hanger w/2800 psi and release off hanger-OK. Liner top at 3,924'MD.Shoe at 7,238'MD. Line up cementers&pump 10 bbls seawater.Test lines to 4000 psi. Pump 60 bbls Tuned Spacer at 11.5 ppg-5 bpm @ 1300 psi. Mix&pump 34_bbls(80sx)Class'G'Lead cement at 4 bpm/900 psi 12.5 ppg w/2.42 cu ft/sk yield and 13.58 gaUsk mix water.Additives: 0.067%SCR-100,0.25%HALAD 344 and 0.133%SCR-100. Mix&pump 35 bbls(172 sx) Class'G'Tail cement at 4 bpm/850 psi. 15.8 ppg w/1.17 cu ft/sk yield and 5.11 gaUsk mix water. Additives:0.15%SCR-100. Drop DP wiper dart&kick out w/20 bbls seawater-4 bpm @ 325 psi. Switch to rig pump and displace cement w/10.6 ppg MOBM using rig pumps-5 bpm @ 750 psi initial slowing to 1 bpm at 340 psi final pressure. NOTE:approximately_40%retums throughout circulating and 50%retu�r s throughout cement job. PU liner wiper plug and continue displacement.Bump liner wiper plug with 238 bbls away. -CIP at 07:00 hrs on 10/30/2012. Pressure up against plug to 3500 psi and hold for 5 min. Bleed off pressure-floats holding OK. Set liner top packer and test to 3500 psi for 5 min.POOH w/liner running tool&LD same. NU wellhead and BOPE.Start testing BOPE to 250psi low/4500 psi high-annular to 250 psi low/2500 psi high,5 min each test. Witness of test waived by AOGCC Rep Lou Grimaldi at 10:45 hrs on 10/30/2012. Page 2/7 Report Printed: 12/21/2012 PI C) N E E R Operations Summary Report - Str Well Name: ODSN-29 ►: ; kL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftK8) (ft) Mud(lb/gal) Summary 10/31/2012 11/1/2012 7,270.0 20.00 10.20 Continue testing BOPE as per AOGCCPTD.Test upper and lower VBR w/5"test joint to 250 psi low/4500 psi high.Test upper and lower IBOP valves to 250 psi low/4500 psi high.Test annular w/5"test joint to 250 psi low/2500 psi high.Test all floor valves to 250 psi low/4500 psi high. Test 14 choke manifold valves to 250 psi low/4500 psi high. Initial system psi:3000.2000 psi r) after closure.200 psi in 21 sec.Full pressure attained in 1 min.48 sec. 5 nitrogen back-up bottles at 1750 psi each. 1 failure-lower 2 7/8"x 5"VBR's failed initial test. Remove and re- 7i dress ram blocks. Re-test to 250 psi low/4500 psi high-passed. -Witness of test waived by AOGCC Rep Lou Grimaldi at 10:45 hrs on 10/30/2012. RD test equipment. Install wear ring. MU clean out BHA and RIH PUDP Tag cmt at 7,050'MD. s Test casing to 3500 psi for 30 min recorded on chart-good test. Drill out 9 5/8"shoe track and clean out rat hole 1/7,270'MD.Displace well to 10.2 ppg WBM. Drill 20'of new hole[/7,290'MD. Perform FIT to 13.5 ppq EMW.POOH and LD clean out BHA. 11/1/2012 11/2/2012 7,290.0 143.00 10.20 Finish LD BHA#6.Pull wear ring&set test plug.Pressure test MPD equipment and lines. Remove MPD test plug.Run wear ring. MU BHA#7&RIH.Cut drilling line&service rig.Install RCD&commission MPD equipment. Drill intermediate2 new hole f/7,290't/7,433'maintaining 13.0 ppg while using MPD-encountered losses starting at 7,353'.Loss rate at 150 bph initially, dropping to 45 bph with addition of LCM but increasing back up to 150 bph. 11/2/2012 11/3/2012 7,433.0 846.00 10.20 Wait on electrician to restore rig power.Continue drilling f/7,433'[/7,777'.At 7,353',experiencing downhole losses.Continue drilling while adding Baracarb and Steel Seal LCM.Suspend drilling at 7,777'.Mix and spot 55 bbls LCM pill in annulus f/7,777'to 9 5/8"shoe at 7,238'.POOH [/7,233'placing bit inside casing shoe.Squeeze LCM pill w/MPD pump holding 12.8 ppg ECD and staging up to 13.0 ppg ECD until losses stop.RIH t/±7,700'.Open Rhino Reamer blades and circulate w/700 gpm while observing well f/losses.No losses observed.Continue drilling f/7,777'[/8,279'. 11/3/2012 11/4/2012 8,279.0 277.00 10.20 Directional drill f/8,279'1/8,321.At 8,306'experiencing losses in excess of 350 bph.Top of Kuparuk Sand @ 8,263'and—losses in Kuparuk.Continue to drill in attempt get below loss zone and allow to heal.Suspend drilling due to low ROP and low mud volume.Mix and pump 95 bbls 10.7 ppg HV LCM pill w/50 ppb-10 ppb each 10,25,50&150 Baracarb+ 10 ppb Steel Seal. Spot 95 bbls pill in annulus f/8,321'top 9 5/8'shoe at 7,238'. POOH[/7,233'placing bit inside shoe-Holding 13.0 ppg ECD w/MPD and monitor well f/losses.Building mud volume in pits& RSC while squeezing LCM and monitoring losses.RIH 1/8,321'.Drilling f/8,321'[/8,470'. Reduced ECD to 12.8 at Top of Kuparuk @ 8,263'md.Mad Pass and correlate depths for Geo- Tap.Perform Geo-Tap procedures at 11 stations.Drill new intermediate2 hole f/8,470'[/8,556'. 11/4/2012 11/5/2012 8,556.0 1,056.00 10.20 Continue drill new intermediate2 hole f/8,556'1/9,537'maintaining 12.8 ppg EMW using MPD. Clean plugged suction screens on MP#1 &2.Continue drilling f/9,537'[/9,612'. 11/5/2012 11/6/2012 9,612.0 162.00 10.20, Continue drilling f/9,612't191774'(Intermediate2 TD).Circulate open hole volume-Change out RCD(bearing leaking).Pump 50 bbls HV sweep surface to surface&CBU 3x.POOH f/9,774' ha [/8,706'.Experiencing overpull and packoff at 8,706'.RIH[/8,755'.Step rate pumps up to 600 gpm.Backream out f/8,755'[/8,390'.Mad Pass f/8,390'1/8,279'.Backream f/8,279'1/8,228'and experience packoff.Losing fluid in excess of 190 bph after pulling through Kuparuk.RIH[/8,365'. Spot LCM pill f/8,365'[/7,365'.POOH to 9 5/8"casing shoe.Prepare to pump DOB2C Stop Loss Pill. 11/6/2012 11/7/2012 9,774.0 0.00 10.20 POOH f/7,500'after cycling pumps to close reamer.Pull into casing w/no issues.RU cement line to standpipe in preparation to pump DOB2C Stop Loss Pill. Flush cement line w/LVT. Clean MP suction screens.Service rig while Cementers blend&prep DOB2C pill. RIH f/7,238'.Stack weight at 8,259'(Top of Kuparuk).Fill pipe and stage up to 3 bpm, 1000 psi.-Wash down [/8,370'(Base Kuparuk). Increase rate&cycle pumps to ensure reamer closed-OK. Backream f/8,370'[/8,279'spotting bit±25'above loss zone. -±120 bph losses while backreaming through Kuparuk.Slowed to 35-40 bph static with MPD holding 12.8 ppg.Pump DOB2C pill down DP and chase to bit w/drilling mud. Bullhead 5-1/4 bbls DOB2C pill into loss zone at±8,306'.Pressured up to 970 psi.POOH[/7,708'while pumping 2.36 bbls per stand.CBU 3x.Observed 28 bph losses after packoff event.POOH[/7,233'placing bit inside casing.Wait on DOBC2 pill to set up while holding 12.8 ppg EMW w/MPD.Wash& ream f/7,733'[/8,565'.POOH f/8,565'[/7,733'.Observe 30 bphr losses while building mud volume and blending DOB2C pill#2. Page 3/7 Report Printed: 12/21/2012 PI O N E E R Operations Summary Report - Str Well Name: ODSN-29 : kL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 11/7/2012 11/8/2012 9,774.0 0.00 10.20 Continue to build mud volume and blend DOB2C pill#2. RIH t18,300'placing bit±6'above loss zone. Fill pipe and circulate w/3bpm, 1000 psi-pump down DP.Pump 3 bbls 10.2 ppg"bland" LSND-Pressure test lines to 3000 psi.Pump 90 more bbls 10.2 ppg LSND followed by 10 bbls LVT, 14 bbls DOB2C and 10 bbls LVT.Chase with 109 bbls of 10.2 ppg drilling mud placing 5 bbls LVT outside bit-Close MPD chokes. Proceed pumping DOB2C at 1:2 ratio-HES pumping 1 bpm DOB2C down drill pipe,rig pumping down annulus w/2 bpm mud.At 4 bbls DOB2C out bit and 8 bbls LSND down annulus,pressured up to 1100 psi.Stop pumps-Strip out of hole at 50'fpm while pumping 2.3 bbls per stand with Halliburton down drill pipe t/7,740'adjusting pulling speed according to WHP.Break circulation w/3 bpm and stage up to 600 gpm,3400 psi-80 rpm, 12k tq.CBU 3x.POOH f/7,740't/7,233'placing bit inside 9 5/8"shoe. **Function test BOP equip.per AOGCC weekly requirement.** Service rig while waiting on DOB2C pill to set up.RIH f/7,233't/7,708'.Wash&ream f/7,708' t18,565'.RIH with 2 stands on elevators after ghost reamer reached base of Kuparuk. RIH t18,772'and stack out. PU to top of stand at 8,749'and Wash&ream f/8,772't18,941'.RIH f/8,941'09,707'while rotating 30 rpm with no pump.Fill pipe and break circulation staging up to 600 gpm.Circulate 1-1/2 open hole volumes. Pump HV sweep surface to surface. 11/8/2012 11/9/2012 9,774.0 0.00 12.00 Continue to CBU hole clean after sweep lx.At BU after the sweep,lost 300 psi pump pressure and observed an increase in torque indicating that the Rhino reamer blades were open.Attempt to cycle pumps several times with no response.Continue to CBU 3x with 470 gpm as this will not extend the blades.Lubricate out of hole f19,774't17,233'placing bit inside 9 5/8"shoe.Service rig.RIH to TD at 9774'.Pump HV sweep.Displace well from 10.2 ppg LSND to 12.0 ppg LSND KWM.POOH f/9,774'to 9 5/8"shoe at 7,238'while pumping 1 1/2 bpm.POOH open elevators f/7,238'to 9 5/8"liner top at 3,924'. 11/9/2012 11/10/2012 9,774.0 0.00 11.20 Pump 56 bbls 13.5 ppg HV pill and chase w/50 bbls 13.5 ppg LSND KWM.POOH f/3,924' 03,428'.Pump calculated displacement strokes to displace well w/13.5 ppg.Observe well. Pull RCD bearing-Install Trip Nipple.Take returns to suction pit-Circulate±30 more bbls. POOH 3,428'to 673'(BHA).Stand back HWDP.LD remainder of BHA.Change upper rams from variables to 7".Test 7"rams to 250 psi lo w/4500 psi high for 5 charted minutes each test.RU Tesco casing equipment.RIH w/7"26#L-80 BTC casing w/torque rings to 3,444'(85 jts). 11/10/2012 11/11/2012 9,774.0 0.00 11.20 Continue to RIH w/7"26#L-80 BTC-M casing f/3,444't/6,463'(160 Its'.PU BTC-M x Hyd,511 XO pup.Continue RIH w/7"26#L-80 Hyd 511 casing t/9,712'.PU landing joint and 7"casing hanger.Land casing in wellhead placing 7"shoe at 9,759'.RD Tesco casing equipment.RU Halliburton cement head and lines.Break circulation and stage pumps up to 5 bpm.Circulate and condition mud for cement job. 4 Pump 18 bbls seawater-Drop 1st bottom plug and kick out w/2 bbls seawater.Test lines to 4000 psi Bleed off and load top plug.Pump 38 bbls Dual Spacer at 11.7 ppg-4 1/2 bpm,560 psi.Drop 2nd bottom plug&kick out w/last 2 bbls Dual Spacer. Mix&pump 2.5 bbls(59 sx)Lead cement at 12.5 ppg(2.42 yield)-2 bpm,300 psi.Additives: 0.2%CFR-3,0.75%laIad 344,1.0%EZ-Flo,2.0%SCR-100&15 lb/sk Microlite.Mix&pump 5tbbls(251 sx.LTail cement at 15.8 ppg(1.17 yield)-4 bpm,400 psi.Additives:0.2%CFR-3, 0.65%Haled 344&0.2%SCR-100. Drop top plug&kick out w/20 bbls seawater.Displace cement w/11.2 ppg LSND using rig pumps.5 bpm, 1800 psi-Slow to 3 bpm, 1300 psi at 330 bbls away.Bumped plug w/352 bbls-Pressure up to 3500 psi and hold f/10 min.Check floats- Held-CIP©18:30 hrs.-Full returns throughout cementing and displacement. A- Pump down 7"x 11 3/4"annulus and break down w/950 psi.Continue to pump down annulus w/ 2 bbls 11.2 ppg LSND.Back out landing joint.Install 7"packoff.Test packoff to 5000 psi.LD 16 jts of 5"HWDP and 96 jts of 5"DP from derrick utilizing mousehole. 11/11/2012 11/12/2012 9,774.0 0.00 11.20 Continue to LD 5"DP from derrick.300 joints total LD.Continue to pump 5 bbls down OA every 30 min w/1 1/2 bpm,800 psi.Pump 100 bbls of 11.2 ppg LSND mud down 7"x 11 3/4"annulus. Change Top Drive upper IBOP and saver sub to 4"XT-39.Change top rams from 7"to 2 7/8"x 5"variables. -AOGCC Rep.John Crisp waived witness of upcoming BOP test at 14:40 hrs on 11/11/12. *Man down on rig called by rig personnel. **Safety Stand Down called for entire Oooguruk Drill Site until further notice. 11/12/2012 11/13/2012 9,774.0 0.00 11.25 Continue Safety Stand Down for entire Oooguruk Drill Site until further notice. Page 4/7 Report Printed: 12/21/2012 [' 10NEER Operations Summary Report - Str Well Name: ODSN-29 ►: : L13ESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 11/13/2012 11/14/2012 9,774.0 0.00 11.25 Continue Safety Stand Down for entire Oooguruk Drill Site until further notice. Test BOPE per AOGCC PTD: Test upper and lower VBR w/4" test joint to 250 psi low/4500 psi high.Test upper and lower IBOP valve to 250 psi low/4500 psi high.Test annular w/4" test joint to 250 psi low/2500 psi high.Test all floor valves to 250 psi low/4500 psi high.Test 14 choke manifold valves to 250 psi low/4500 psi high while POOH. **1 failure-Lower Ram door seal on Drillers side** Change seal.Retest.Passed. All tests charted and all tests held for 5 min. Initial system psi: 3000;2000 after closure;200 psi=25 sec,full pressure 2 min.5 sec. -AOGCC Rep.John Crisp waived right to witness test at 14:40 hrs on 11/11/2012. RD test equipment. Install Wear ring 11/14/2012 11/15/2012 9,774.0 0.00 11.25 Continue with rig safety stand down until crew notified rigsite management that they were ready to resume operations. RIH PU 4"DP.Rack back same.Test 7"casing to 3500 psi for 30 min-good test.PU clean out BHA#8 and RIH PU 4"DP t/9,055'. SIMOPS:Freeze protect 11 3/4"x 7"annulus with 150 bbls diesel. 11/15/2012 11/16/2012 9,774.0 11.20 TIH picking up 4"DP from pipe shed f/9,055't19,503'.Tagged cement stringer with 25k at 9,503'. Drill cement f/9,503't19,654'.Trouble shoot top drive communications issues and repair same. Found comm cable was cut in wire tray.Drill cement and float equipment f/9,654't19,774'.CBU hole clean 3x. POOH f/9,774't/5,713'. 11/16/2012 11/17/2012 9,774.0 90.00 7.65 POOH f/5,713'to surface and LD BHA#8.TIH with BHA#9 from surface t/9,746'.Slip and cut 98'of drill line.Remove trip nipple and install RCD bearing.Displace well from 11.2 ppg WBM to 7.5 ppg MOBM.Directional drill new production hole f/9,774't19,794'.Perform F.I.T.at 9,794' / md/6,426'tvd with 7.7 ppg MOBM to 1610 psi for EMW of 12.52 ppg.Directional drill f/9,794' � t19,864'. 11/17/2012 11/18/2012 9,864.0 748.00 7.60 Directional drill f/9,864'U10,227'.Perform static draw down pore pressure test at 10,227' md/6,455'tvd=9.5 ppg EMW.Directional drill new production hole maintaining 9.9 ppg EMW using MPD f/10,227'U10,612'. 11/18/2012 11/19/2012 10,612.0 1,011.00 7.65 Directional drill new production hole maintaining 9.9 ppg EMW using_ D' 10,612'U11,623'. 11/19/2012 11/20/2012 11,623.0 841.00 7.80 Directional drill new production hole f/11,623'U11,916'maintaining 10.0 ppg EMW using MPD. Circulate while geologists confer with town geologist about geo-steering.Directional drill f/11,916' U12,387'.Circulate while geologists confer with town geologist about geo-steering.Directional drill f/12,387't112,464'--packed off at 12,464'.Work pipe thru tight hole with multiple pack off events. POOH f/12,464'U11,900'. Orient tool face and trough f/11,900'U11,930'for open hole sidetrack. 11/20/2012 11/21/2012 11,930.0 384.00 7.85 Time drill asQer sidetrack procedure f/11,930't/11,94$'.Directional drill f/11,948'U12,057'. ' Service rig and top drive while function testing BOPE—Good test.Directional drill f/12,057' U12,250'.POOH f/12,250't/11,880'to check sidetrack point.Wipe thru sidetrack point 3x f/11,900'U11,950'.TIH f/11,950't/12,250'.Directional drill f/12,250'1/12,314'maintaining 10.0 ppg EMW using MPD. 11/21/2012 11/22/2012 12,314.0 485.00 7.85 Directional drill f/12,314't/12,469'.Change out RCD head due to element failure.Directional drill new production hole f/12,469't112,799'maintaining 10.0 ppg EMW using MPD. 11/22/2012 11/23/2012 12,799.0 946.00 8.00 Directional drill new production hole f/12,799'U13,745'maintaining 10.2 ppg EMW using MPD. 11/23/2012 11/24/2012 13,745.0 596.00 8.00 Directional drill f/13,745'U13,887'.Change out RCD head due to element failure. Directional drill f/13,887't/14,341'. 11/24/2012 11/25/2012 14,341.0 123.00 8.00 Directional drill new production hole f/14,341'U14,404'.CBU 4x in attempt to clean up sticky hole.Directional drill f/14,404'U14,464'.Stage up pumps after pack off event and attempt to clean up sticky hole-- Unable to achieve full drilling rate due to pack off events.POOH f/14,464' U13,374'.Stage up pumps and CBU with no pack off events.Change out RCD head due to bearing seal failure. Page 5/7 Report Printed: 12/21/2012 PI C) N E E R Operations Summary Report - Str Well Name: ODSN-29 k : 1L RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) 1` (ft) Mud(lb/gal) Summary 11/25/2012 11/26/2012 13,160.0 139.00 7.95 Change out RCD head due to bearing seal failure.Service rig and top drive while changing out saver sub on top drive. POOH f/13,342't/13,117'. Orient tool face and trough f/13,130'[/13,160'. Directional drill as per sidetrack procedure f/13,160'[/13,299'maintaining 10.2 ppg EMW using MPD. 11/26/2012 11/27/2012 13,299.01 31.00 10.00 Control drill as per sidetrack procedure f/13,299'U13,330'.CBU hole clean.POOH f/13,330' t/10,227'.Pump 18 bbls hi-vis 10.0 ppg pill and spot same f/10,227't/9,746'.Displace well from 8.0 ppg to 10.0 ppg MOBM.Remove RCD head and install trip nipple.POOH f/9,746't/849'. 11/27/2012 11/28/2012 13,330.0 10.00 POOH laying down DP f/849'to surface.TIH,pick up 66 joints of DP[/2,112'.Flush DP 1.5 times DP volume.TOOH f/2,112'to Surface.Remove wear bushing and install test plug.Test BOPE per AOGCC PTD:Test upper and lower VBR w/4" and 4 1/2"test joint to 250 psi low/4500 psi high. Test upper and lower IBOP valve to 250 psi low/4500 psi high.Test annular w/4" test joint to 250 psi low/2500 psi high.Test all floor valves to 250 psi low/4500 psi high. Test 14 choke manifold valves to 250 psi low/4500 psi high while POOH. 1 failure-Lower Ram piston mud seal on lower pipe rams.All tests charted and all tests held for 5 min.Initial system psi:3050;2100 after closure;200 psi=25 sec,full pressure 1 min.49 sec. AOGCC Rep.John Crisp on location to witnessed test.Change out ram piston mud seal on lower pipe rams. RU test equipment and retest lower VBR w/4" and 4 1/2"test joint to 250 psi low/4500 psi high. All tests charted and all tests held for 5 min. Remove test plug and install wear bushing.PU DP,flush same with 1.5x DP volume,and rack back same. PU BHA#10 from surface 076'. 11/28/2012 11/29/2012 13,330.0 2.00 8.05 Continue PU BHA#10 and TIH U9,747'.Slip and cut drill line. Install RCD bearing.Displace well from 10 ppg to 7.9 ppg MOBM.TIH f/9,747'U11,900.CBU.TIH f/11,900'[/13,310'--taking rotational check shot surveys and MADD pass as needed for geological information.Drill sliding f/13,310'U13,330'.Time drill f/13,330'U13,332' 11/29/2012 11/30/2012 13,332.0 148.00 7.85 Directional drill new production hole f/13,332'[/13,480'maintaining 10.2 ppg EMW using MPD. 11/30/2012 12/1/2012 13,480.0 978.00 7.90 Directional drill new production hole f/13,480'[/14,458'maintaining 10.3 ppg EMW using MPD. 12/1/2012 12/2/2012 14,458.0 1,258.00 8.00 Directional drill f/14,458'015,716'.Circulate hole clean 2.5x open hole volume.Change out RCD element.Backream out the hole for HSI data f/15,620'[/13,984'. 12/2/2012 12/3/2012 15,716.0, 0.00' 8.00 Backream f/13,984'to 7"shoe @ 9,746'.CBU casing clean 2x.Change out swivel packing on top drive.TIH on elevators f/9,746'[/11,916'. 12/3/2012 12/4/2012 15,716.0 0.00 10.00 TIH f/11,961'U15,716'. Displace 8.0 ppg MOBM w/10.0 ppg MOBM.Remove RCD bearing, install trip nipple.TOOH f/15,716'[/9,170'pumping out the hole to alleviate swabbing.CBU 2x. TOOH f/9,170'U6,664'hole not taking proper fill.CBU.TOOH f/6,664'U3,677'. 12/4/2012 12/5/2012 15,716.0 0.00 10.00 TOOH f/3,677'U surface laying down BHA.PU 24 joints 4"DP from pipe shed and TIH with same.Pump 1.5x DP capacity. Rack back clean HWDP in derrick.RU 4.5"liner equipment and stage liner jewelry in pipe shed as per tally.RIH w/4 1/2"Hyd 521,P-110 13.5#liner f/surface U6,143'.MU BHI FlexLock hanger/ZXP packer assembly f/6,143'[/6,186'.Service rig and function test BOPE as per AOGCC PTD--Good test. • 12/5/2012 12/6/2012 15,716.0 0.00 10.00 LD SGL,CBU @ 6,186'. MU Bumper Sub and Magnet. Run 4 1/2"HYD 521 liner on 4"drill pipe stands f/6,304'[/15,706'. Top of liner--9,523'. Establish circulation using step rate method. RU pup joint,pump in sub,and cement lines to drill pipe. As per Baker Rep--drop ball,set hanger, pump ball on seat to WIV. Inflate ECP 1-10 using cement pump. ECP#8 would not inflate-- possible damage to element. Inflate 9&10 ECP. Pressure up back side to 350 psi,bleed back to 250 psi,pressure up to 350 psi continue to bleed back to 250 psi. Page 6/7 Report Printed: 12/21/2012 II C) N E E R Operations Summary Report - Str Well Name: ODSN-29 ►: : �L RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 12/6/2012 12/7/2012 15,716.0 0.00 10.00 PU and expose Pkr setting dogs.Rotate at 20 rpm,set down 55k on liner top to set Pkr.Drop 1- 3/4"ball and pressure test liner top packer and annulus between drill pipe and 7"casing 3500 psi for 30 minutes,test OK--Chart same. Change out long bails to rig bails, RSC builds 10 ppg Brine. Displace 10 ppg MOBM with 10 ppg Brine--50 bbl Spacer,313 bbls of 10 ppg Brine,last 200 bbls treated with corrosion inhibiter. Slip and cut 66'of drill line. TOOH and LD 4"DP, LD magnet,bumper sub,and running tool. RU and run 4 1/2"12.6#/13.5#P110 HYD-521 frac tubing from surface t/1,415'. MU ROC gauge and test as per Rep @ 917'. Installing cannon clamps every joint.Torque turn every connection to 5K Ft/Lbs,32 joints in hole. 12/7/2012 12/8/2012 15,716.0 0.00 10.00 RIH with 4 1/2"12.6#/13.5# frac tubing t/9,523'(223 total full joints)as per tally. Locate liner top wit- hyo-Go,PU to neutral weight,Close annular and test annulus to 200 psi to test seals-5 minutes. Perform space out-LD joint#223. MU tubing hanger. Perform SVLN control line and ROC gauge I-Wire feed through hanger. Land hanger in well head. RILDS. Test upper and lower hanger seals 10000 psi-Test OK. Pressure test upper completion to 3500 psi chart same. Pressure test annulus to 3500 psi chart same. Shear DCK-2. Confirm DCK fully sheared.RD testing lines and landing joint. 12/8/2012 12/9/2012 15,716.0 0.00 10.00 ND BOPE. Install TWC in hanger.Terminate SVLN control line and ROC gauge I-Wire and route through well head. NU Tree and pressure test to 5000 psi 10 minute and chart same. Pull TWC. Secure Tree and clean well bay. Turn over to operations to freeze protect well. LD drill pipe from derrick. Prep rig for move to ODSN-24. Rig Released 12/09/12 @ 00:00 hrs. "'Operations freeze protect 4 1/2"tubing and 7"annulus with 90 bbls of diesel.*** Page 7/7 Report Printed: 12/21/2012 ODSN-29 Nuiqsut Production Well Completion Updated 12/20/2012 i • Upper Completion mQ DM ,[ii 'I'I', 16"Conductor 1)Tubing Hanger 43' 43' 2)4-'/"13.5#/ft Hydril 521 Tubing °''' iiiii ii3)4-'/"Halliburton'XXO'SVLN w/3.813""X"profile RTS-8 2082' 2020'• Packer Fluid mix: with singlel/4"x 0.049"s/s control line. I Inhibited Kill weight Cannon Cross-coupling clamps on every joint I I'I Brine 4)4-%"13.5#/ft Hydril 521 Tubing 3 i"" with 2000'TVD 5)4-'/"x 1"GLM,KBMG Hydril 521 w/SOV 2231' 2155' fj s diesel cap 6)4-%:"13.5#/ft Hydril 521 Tubing 7)HES X 3.813" 2299' 2208' 8)4-%"13.5#/ft Hydril 521 Tubing iiiiiiiii1111111 9)4-%"x 1"GLM,KBMG Hydril 521 w/DV 4277' 3635' 10)4-W 1 3.5#/ft Hydril 521 Tubing 11)4-'W x 1"GLM, KBMG Hydril 521 w/DV 6359' 4957' 11-3/4"60 ppf L-80 BTC 12)4-W 13.5#/ft Hydril 521 Tubing Surface Casing 13)4-%"x 1"GLM, KBMG Hydril 521 w/DV 7856' 5900' @ 4140' MD/3544'TVD 14)4-W 1 3.5#/ft Hydril 521 Tubing 015)HES XN 3.813"(3.725"NoGo)-with RHC Plug 8512' 6265' I I cemented to surface 16)4-%"1 3.5#/ft Hydril 521 Tubing 17)4-1/2"Halliburton'ROC'Gauge Carrier w/1/4"x 0.049"s/s control line 8617' 6306' 0 177 18)4-%"13.5#/ft Hydril 521 Tubing 19)Bullet Seal Assembly with Ratcheting Mule Shoe 9538' 6413' Bottom of Shoe 9540' 6414' I 0 iI. iiiii iii. 9-5/8"40 ppf L-80 Hydril 521 Intermediate 1 Casing @ 7238' MD/5506'TVD C 4-1/2" 13.5 ppf i P-110 Hydril i 521 i Tubing I Iii, ® Iiii i 1111.1i fi TOC Estimated €'i€i 500'above top of ': Kuparuk Iiii '11111I, .0 '''111111!]:.\*...11111,,. 0 Fault @ 13,470' MD 32 44 4kEIII4E9.T4I 7890• Ill =0 - - - -I - - - -I- - 2 Casing „ @9759' MD/6430' 1 CO TVD Fault @ I I FAILED ECP 11,980 ft MD 6-1/8" Hole TD at at 15716' MD/ 4-'/" Hydril 521 Liner with Baker Hughes Multi- 6430'TVD Point Frac Sleeves(3 per stage) isolated with ECP's+ Resman Carriers ODSN-29 Nuiqsut Production Well Completion Updated 12/20/2012 I iiiiiiij Lower Completion M0 D(12 i 20)Baker 5-/ X 7"ZXP Liner Top Packer with 15ft Tie Back 9524' 6413' A1111111ijlj* 16"Conductor extension and Flex Lock Hanger iiiiiiiiI 21)4-'/2"13.5#/ft Hydril 521 Liner iiiiiiii Packer mix: 22)Baker ECP Packer(4-%"Hydril 521) 9949' 6436' I is Inhibitedkr Fluidi weight 23)4-/ 13.5#/ft Hydril 521 Liner iiiiiiii9 24)Baker Multi-Point Frac Sleeve with segmented ball seat(3.000 ball/2.948 Seat) 10179' 6445' IiIIIiii � Brine 25)4-'/:"13.5#/ft Hydril 521 Liner IiiiIiIi 3 iiili with 2000'TVD 26)4-%2 Resman Tracer Carrier w/15 ft pups on each side 10253' 6445' i diesel cap 27)4-%I"13.5#/ft Hydril 521 Liner :Ili itu 28)Baker Multi-Point Frac Sleeve with segmented ball seat(3.000 ball/2.948 Seat) 10336' 6444' I 29)4-'/z"13.5#/ft Hydril 521 Liner 30)Baker Multi-Point Frac Sleeve with solid ball seat(3.000 bal I/2.948 Seat) 10411' 6442' 31)4-%"13.5#/ft Hydril 521 Liner 32)Baker ECP Packer(4-%"Hydril 521) 10647' 6434' 11-3/4" 60 ppf L-80 BTC 33)4-'/3"13.5#/ft Hydril 521 Liner Surface Casing 34)Baker Multi-Point Frac Sleeve with segmented ball seat(2.938 ball/2.885 Seat) 10751' 6433' 35 4-%"13.5#/ft Hydril 521 Liner © I @ 4140' MD/3544'TVD 36)4-W Resman Tracer Carrier w/15 ft pups on each side 10826' 6431' I cemented to surface 37)4-W 13.5#/ft Hydril 521 Liner 0 I 38)Baker Multi-Point Frac Sleeve with segmented ball seat(2.938 ball/2.885 Seat) 10910' 6430' 39)4-W 13.5#/ft Hydril 521 Liner 40)4-'%"Resman Tracer Carrier w/15 ft pups on each side 10985' 6429' _ 41)4-'/:"13.5#/ft Hydril 521 Liner 42)Baker Multi-Point Frac Sleeve with solid ball seat(2.938 ball/2.885 Seat) 11068' 6427' 43)4-'/ 13.5#/ft Hydril 521 Liner i 44)Baker ECP Packer(4-%"Hydril 521) 11178' 6423' 0 I ` 9-5/8"40 ppf L-80 Hydril 521 45)4-W 13.5#/ft Hydril 521 Liner 46)Baker Multi-Point Frac Sleeve with segmented ball seat(2.875 ball/2.823 Seat) 11379' 6415' Intermediate 1 Casing 47)4-W 13.5#/ft Hydril 521 Liner @ 7238' MD/5506'TVD 48)4-'/"Resman Tracer Carrier w/15 ft pups on each side 11454' 6413' 49)4-W 13.5#/ft Hydril 521 Liner 50)Baker Multi-Point Frac Sleeve with segmented ball seat(2.875 ball/2.823 Seat) 11538' 6410' 51)4-%"13.5#/ft Hydril 521 Liner 4110 4-1/2" 13.5 ppf 52)Baker Multi-Point Frac Sleeve with solid ball seat(2.875 ball/2.823 Seat) 11612' 6408' P-110 Hydril 53)4-W 13.5#/ft Hydril 521 Liner 54)4-1/ 13.5#/ft Hydril 521 Liner with 2 HLB slide on centralizers 11756' 6407' 521 55)4-%"13.5#/ft Hydril 521 Liner Tubing 56)Baker ECP Packer(4-%"Hydril 521) 12017' 6407' 57)4-'W 13.5#/ft Hydril 521 Liner 13GLI :° 58)Baker Multi-Point Frac Sleeve with segmented ball seat(2.813 ball/2.760 Seat) 12231' 6407' ;1 59)4-%'13.5#/ft Hydril 521 Liner ® XN iii i 60)4-%"Resman Tracer Carrier w/15 ft pups on each side 6408' 61)4-'//13.5#/ft Hydril 521 Liner 62)Baker Multi-Point Frac Sleeve with segmented ball seat(2.813 bat/2.760 Seat) 12389' 6409' R 63)4-W 13.5#/ft Hydril 521 Liner Iiiiii _= TOC Estimated 64)Baker Multi-Point Frac Sleeve with solid ball seat(2.813 ball/2.760 Seat) 12506' 6409' i 500'above top of 65)4- "13.5#/ft Hydril 521 Liner 66)Baker ECP Packer(4-14"Hydril 521) 12701' 6416' Kuparuk 67)4-%2"13.5#/ft Hydril 521 Liner 68)Baker Multi-Point Frac Sleeve with segmented ball seat(2.750 ball/2.698 Seat) 12903' 6415' 69)4-Y2'13.5#/ft Hydril 521 Liner 70)4-'/"Resman Tracer Carrier w/15 ft pups on each side 12977' 6412' " 'VP 71)4-'/z"13.5#/ft Hydril 521 Liner .. "!,,,;,_ "iii 72)Baker Multi-Point Frac Sleeve with segmented ball seat(2.750 ball/2.698 Seat) 13060' 6409' ��`iii: 73)4-%3"13.5#/ft Hydril 521 Liner 74)4-%"Resman Tracer Carrier w/15 ft pups on each side 13134' 6405' "`ii:, :. ;`0 75)4-%"13.5#/ft Hydril 521 Liner 'lliiiii CO, Fault @ 13,470' MD 32 44 54 56 66 78 80 90 �� 0 7"26 ppf L-80 BTC- � 50 ■ Mod + Hydril 521 za ® _ _ _ - _ _ __ - - - _ - _ _- _ _ _ __ Intermediate 2 - — — — — — — — — — —_ — — — — — — — — — — — Casing 1 11111 1 Z @ 9759' MD/6430' 1 0 ND f Fault @ / I FAILED ECP 11,980 ft MD 6-1/8" Hole TD at 4-'/" Hydril 521 Liner with Baker Hughes Multi-Point at 15716' MD/ Frac Sleeves(3 per stage) isolated with ECP's+ 6430'ND Resman Carriers ODSN-29 Nuiqsut Production Well Completion Updated 12/20/2012 Iililiili Lower Completion MITQ 12 fi'l'l`, 16"Conductor 76)Baker Multi-Point Frac Sleeve with solid ball seat(2.750 ball/2.698 Seat) 13218' 6402' 77)4-'/"13.5#/ft Hydril 521 Liner Packer Fluid mix 78)Baker ECP Packer(4-%"Hydril 521) 13370' 6402' !PIN InIIIIIlb Inhibited Kill weight 79)4-%"13.5#/ft Hydril 521 Liner g 80)Baker ECP Packer(4-%"Hydril 521) 13508' 6408' I <€• Brine 81)4-%"13.5#/ft Hydril 521 Liner s with 2000'TVD 82)Baker Multi-Point Frac Sleeve with segmented ball seat(2.688 ball/2.635 Seat) 13727' 6417' Illilillp I diesel cap 83)4-%"13.5#/ft Hydril 521 Liner 84)4-/ Resman Tracer Carrier w/15 ft pups on each side 13801' 6420' I ii< 85)4-%"13.5#/ft Hydril 521 Liner • 'i•'i''• 86)Baker Multi-Point Frac Sleeve with segmented ball seat(2.688 ball/2.635 Seat) 13884' 6423' 87)4-'/"13.5#/ft Hydril 521 Liner 88)Baker Multi-Point Frac Sleeve with solid ball seat(2.688 ball/2.635 Seat) 13958' 6423' 11-3/4"60 ppf L-80 BTC 89)4-'Y2"13.5#/ft Hydril 521 Liner Surface Casing 90)Baker ECP Packer(4-W Hydril 521) 14110' 6424' @ 4140' MD/3544'TVD 91)4-'i4"13.5#/ft Hydril 521 Liner © 92)Baker Multi-Point Frac Sleeve with segmented ball seat(2.625 ball/2.573 Seat) 14263' 6425' cemented to surface 93)4-%"13.5#/ft Hydril 521 Liner 94)4-Y"Resman Tracer Carrier w/15 ft pups on each side 14339' 6426' Q 95)4-%"13.5#/ft Hydril 521 Liner 96)Baker Multi-Point Frac Sleeve with segmented ball seat(2.625 ball/2.573 Seat) 14422' 6428' 97)4-%"13.5#/ft Hydril 521 Liner III 98)Baker Multi-Point Frac Sleeve with solid ball seat(2.625 ball/2.573 Seat) 14496' 6428' Iiii 99)4-'h"13.5#/ft Hydril 521 Liner iIiIi 100)Baker ECP Packer(4-Y:"Hydril 521) 14648' 6427' 0 I '` 9-5/8"40 ppf L-80 Hydril 521 101)4-%"13.5#/ft Hydril 521 Liner Intermediate 1 Casing102)Baker Multi-Point Frac Sleeve with segmented ball seat(2.563 ball/2.510 Seat) 14787' 6429' 103)4-%"13.5#/ft Hydril 521 Liner @ 7238' MD/5506'TVD 104)4-14"Resman Tracer Carrier w/15 ft pups on each side 14862' 6430' 105)4-Y"13.5#/ft Hydril 521 Liner 106)Baker Multi-Point Frac Sleeve with segmented ball seat(2.563 ball/2.510 Seat) 14945' 6431' 107)4-%"13.5#/ft Hydril 521 Liner 11 4-1/2" 13.5 ppf 108)4-'4"Resman Tracer Carrier w/15 ft pups on each side 15020' 6431' j P-110 Hydril 109)4-'i"13.5#/ft Hydril 521 Liner 521 110)Baker Multi-Point Frac Sleeve with solid ball seat(2.563 ball/2.510 Seat) 15102' 6432' 111)4-%"13.5#/ft Hydril 521 Liner Tubing 112)Baker ECP Packer(4-'h"Hydril 521) 15249' 6432' i 113)4-1"13.5#/ft Hydril 521 Liner 0 114)4-'/:"13.5#/ft Hydril 521—10 ft Pup I € 115)4-%"Resman Tracer Carrier w/15 ft pups on each side 15469' 6431' ® I illill 116)Pressure Activated Sleeve"B"5,800 psi 15644' 6430' illiil I 1 0111 117)Pressure Activated Sleeve"A"5,600 psi 15698' 6430' 118)Wellbore Isolation Valve"WIV" 15700' 6430' 119)Eccentric Shoe 15705' 6430' TOC Estimated Bottom of Shoe 15706' 6430' €i: 500'above top of ibilli:;::1;:h. Kuparuk i. • • UP .%:: ',4,, ."„„,,. ..... ... ....... 0 Fault 13,470' MD �j 32 44 54 I 56 66 78 80 90 07"26 ppf L-80 BTC- , ® 50 2e Mod+ Hydril 521 ® - -j- - n - - - --_-- - - - --'- - -I- 1:-. - 2 Intermediate 2 - - - - - -I - - - - - -I - - - - - - - Casing @ 9759' MD/6430' T CO TVD Fault @ I FAILED ECP 11,980 ft MD 6-1/8" Hole TD at at 15716' MD/ 4-W Hydril 521 Liner with Baker Hughes Multi-Point 6430'TVD Frac Sleeves(3 per stage) isolated with ECP's+ Resman Carriers Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-29 PN5 50-703-20661-00-00 Sperry Drilling Services Definitive Survey Report 14 December, 2012 HALLIBURTON Sperry Drilling Services Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 Database: EDM_Alaska Project Oooguruk Development Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well ODSN-29 Well Position +N/-S 0.00 ft Northing: 6,031,108.44 ft Latitude: 70°29'45.820 N +E/-W 0.00 ft Easting: 469,923.95 ft Longitude: 150°14'45.357 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSN-29 PN5 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF2010 10/10/2012 20.57 80.97 57,668 Design ODSN-29 PN5 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 13,041.26 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (bearing) 42.70 0.00 0.00 350.27 Survey Program Date 12/14/2012 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 100.00 729.00 ODSN-29 GYRO(ODSN-29 PN5 PB1) SRG-SS Surface readout gyro single shot 11/07/2012 775.48 4,138.70 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 4,139.70 7,238.00 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 7,238.00 9,697.60 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 9,776.70 11,885.85 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 11,930.00 13,041.26 ODSN-29 PN5 MWD(ODSN-29 PN5 PB MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/20/2012 13,138.40 15,641.71 ODSN-29 MWD(ODSN-29 PN5) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/26/2012 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (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 6,031,108.44 469,923.95 0.00 0.00 UNDEFINED 100.00 0.12 142.74 100.00 43.80 -0.05 0.04 6,031,108.39 469,923.99 0.21 -0.05 SRG-SS(1) 172.00 0.15 342.94 172.00 115.80 -0.02 0.05 6,031,108.42 469,924.00 0.37 -0.03 SRG-SS(1) 261.00 1.50 148.91 260.99 204.79 -0.90 0.62 6,031,107.53 469,924.57 1.85 -1.00 SRG-SS(1) 354.00 4.95 146.57 353.83 297.63 -5.30 3.46 6,031,103.13 469,927.39 3.71 -5.80 SRG-SS(1) 448.00 9.11 143.99 447.10 390.90 -14.70 10.07 6,031,093.70 469,933.96 4.44 -16.20 SRG-SS(1) 541.00 11.62 142.76 538.58 482.38 -28.12 20.07 6,031,080.24 469,943.91 2.71 -31.11 SRG-SS(1) 636.00 10.55 138.46 631.81 575.61 -42.25 31.63 6,031,066.07 469,955.41 1.42 -46.98 SRG-SS(1) 729.00 10.64 121.05 723.24 667.04 -53.05 44.63 6,031,055.22 469,968.36 3.43 -59.83 SRG-SS(1) 12/142012 11:00:26AM Page 2 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'©56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'©56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 775.48 10.70 114.93 768.92 712.72 -57.08 52.22 6,031,051.15 469,975.94 2.44 -65.09 MWD+IFR2+MS+sag(2) 871.35 10.29 106.10 863.19 806.99 -63.21 68.52 6,031,044.96 469,992.21 1.73 -73.88 MWD+IFR2+MS+sag(2) 967.21 8.57 109.64 957.76 901.56 -67.98 83.48 6,031,040.13 470,007.14 1.89 -81.11 MWD+IFR2+MS+sag(2) 1,057.98 8.88 89.26 1,047.50 991.30 -70.17 96.85 6,031,037.89 470,020.51 3.40 -85.53 MWD+IFR2+MS+sag(2) 1,156.87 8.63 82.17 1,145.24 1,089.04 -69.06 111.84 6,031,038.94 470,035.50 1.12 -86.96 MWD+IFR2+MS+sag(2) 1,252.66 9.64 75.68 1,239.81 1,183.61 -66.09 126.73 6,031,041.84 470,050.40 1.50 -86.56 MWD+IFR2+MS+sag(2) 1,344.56 11.97 66.08 1,330.09 1,273.89 -60.33 142.90 6,031,047.54 470,066.59 3.20 -83.61 MWD+IFR2+MS+sag(2) 1,443.83 14.03 61.93 1,426.81 1,370.61 -50.49 162.93 6,031,057.30 470,086.66 2.28 -77.30 MWD+IFR2+MS+sag(2) 1,538.72 16.10 60.74 1,518.43 1,462.23 -38.64 184.56 6,031,069.05 470,108.33 2.21 -69.28 MWD+IFR2+MS+sag(2) 1,630.58 18.58 58.48 1,606.11 1,549.91 -24.76 208.15 6,031,082.84 470,131.98 2.80 -59.59 MWD+IFR2+MS+sag(2) 1,726.05 20.24 53.90 1,696.16 1,639.96 -7.08 234.46 6,031,100.41 470,158.36 2.36 -46.60 MWD+IFR2+MS+sag(2) 1,823.57 23.59 50.42 1,786.62 1,730.42 15.30 263.14 6,031,122.67 470,187.13 3.68 -29.39 MWD+IFR2+MS+sag(2) 1,919.50 24.52 50.45 1,874.22 1,818.02 40.20 293.29 6,031,147.45 470,217.37 0.97 -9.94 MWD+IFR2+MS+sag(2) 2,012.11 26.18 49.20 1,957.91 1,901.71 65.79 323.57 6,031,172.92 470,247.75 1.88 10.16 MWD+IFR2+MS+sag(2) 2,108.98 29.74 46.35 2,043.46 1,987.26 96.35 357.14 6,031,203.34 470,281.45 3.92 34.61 MWD+IFR2+MS+sag(2) 2,203.85 30.55 43.54 2,125.51 2,069.31 130.07 390.78 6,031,236.92 470,315.22 1.71 62.16 MWD+IFR2+MS+sag(2) 2,300.31 30.90 43.41 2,208.43 2,152.23 165.84 424.69 6,031,272.54 470,349.27 0.37 91.68 MWD+IFR2+MS+sag(2) 2,394.61 30.17 41.08 2,289.65 2,233.45 201.29 456.90 6,031,307.86 470,381.62 1.47 121.18 MWD+IFR2+MS+sag(2) 2,485.66 32.87 41.15 2,367.26 2,311.06 237.15 488.20 6,031,343.59 470,413.06 2.97 151.23 MWD+IFR2+MS+sag(2) 2,582.97 34.96 40.94 2,448.01 2,391.81 278.10 523.85 6,031,384.39 470,448.87 2.15 185.56 MWD+IFR2+MS+sag(2) 2,676.49 35.93 37.95 2,524.20 2,468.00 319.98 558.29 6,031,426.12 470,483.47 2.12 221.02 MWD+IFR2+MS+sag(2) 2,772.74 37.48 37.32 2,601.37 2,545.17 365.54 593.41 6,031,471.54 470,518.77 1.66 259.99 MWD+IFR2+MS+sag(2) 2,866.80 38.36 38.20 2,675.57 2,619.37 411.23 628.81 6,031,517.08 470,554.35 1.10 299.05 MWD+IFR2+MS+sag(2) 2,962.28 39.48 38.14 2,749.85 2,693.65 458.39 665.88 6,031,564.09 470,591.61 1.17 339.26 MWD+IFR2+MS+sag(2) 3,056.78 42.54 37.76 2,821.15 2,764.95 507.29 704.00 6,031,612.82 470,629.93 3.25 381.01 MWD+IFR2+MS+sag(2) 3,152.51 44.40 38.36 2,890.62 2,834.42 559.14 744.61 6,031,664.50 470,670.74 1.99 425.25 MWD+IFR2+MS+sag(2) 3,244.56 45.78 38.50 2,955.61 2,899.41 610.20 785.13 6,031,715.40 470,711.46 1.50 468.73 MWD+IFR2+MS+sag(2) 3,339.91 44.52 38.40 3,022.85 2,966.65 663.14 827.16 6,031,768.16 470,753.70 1.32 513.81 MWD+IFR2+MS+sag(2) 3,437.78 44.79 38.83 3,092.47 3,036.27 716.89 870.09 6,031,821.73 470,796.84 0.41 559.52 MWD+IFR2+MS+sag(2) 3,531.82 46.35 36.87 3,158.31 3,102.11 769.92 911.28 6,031,874.59 470,838.24 2.23 604.83 MWD+IFR2+MS+sag(2) 3,628.46 46.31 36.78 3,225.04 3,168.84 825.87 953.18 6,031,930.36 470,880.36 0.08 652.90 MWD+IFR2+MS+sag(2) 3,721.08 49.15 38.54 3,287.33 3,231.13 880.10 995.06 6,031,984.42 470,922.46 3.37 699.27 MWD+IFR2+MS+sag(2) 3,815.98 52.06 38.95 3,347.55 3,291.35 937.29 1,040.96 6,032,041.42 470,968.59 3.08 747.88 MWD+IFR2+MS+sag(2) 3,913.69 53.35 38.96 3,406.76 3,350.56 997.74 1,089.83 6,032,101.66 471,017.70 1.32 799.20 MWD+IFR2+MS+sag(2) 4,007.06 52.27 39.23 3,463.20 3,407.00 1,055.47 1,136.73 6,032,159.19 471,064.83 1.18 848.17 MWD+IFR2+MS+sag(2) 4,093.51 53.19 39.45 3,515.55 3,459.35 1,108.67 1,180.34 6,032,212.22 471,108.65 1.08 893.24 MWD+IFR2+MS+sag(2) 4,193.35 50.77 38.33 3,577.04 3,520.84 1,169.88 1,229.73 6,032,273.22 471,158.28 2.58 945.22 MWD+IFR2+MS+sag(3) 4,235.17 50.22 38.20 3,603.64 3,547.44 1,195.21 1,249.71 6,032,298.47 471,178.36 1.34 966.81 MWD+IFR2+MS+sag(3) 4,329.62 50.67 36.91 3,663.79 3,607.59 1,252.94 1,294.10 6,032,356.01 471,222.97 1.16 1,016.21 MWD+IFR2+MS+sag(3) 4,424.83 50.66 37.77 3,724.14 3,667.94 1,311.49 1,338.76 6,032,414.37 471,267.87 0.70 1,066.37 MWD+IFR2+MS+sag(3) 12/14/2012 11:00:26AM Page 3 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7+13.5 @ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Weilbore: ODSN-29 PN5 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 Database: EDM Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,520.03 51.23 38.51 3,784.12 3,727.92 1,369.63 1,384.42 6,032,472.32 471,313.76 0.85 1,115.96 MWD+IFR2+MS+sag(3) 4,614.29 51.72 40.80 3,842.84 3,786.64 1,426.40 1,431.48 6,032,528.89 471,361.04 1.97 1,163.95 MWD+IFR2+MS+sag(3) 4,710.58 51.23 38.43 3,902.82 3,846.62 1,484.42 1,479.51 6,032,586.71 471,409.30 1.99 1,213.02 MWD+IFR2+MS+sag(3) 4,805.30 49.64 37.91 3,963.15 3,906.95 1,541.82 1,524.63 6,032,643.92 471,454.66 1.73 1,261.97 MWD+IFR2+MS+sag(3) 4,899.73 49.48 38.02 4,024.40 3,968.20 1,598.48 1,568.85 6,032,700.40 471,499.09 0.19 1,310.34 MWD+IFR2+MS+sag(3) 4,992.80 50.29 38.34 4,084.37 4,028.17 1,654.43 1,612.84 6,032,756.16 471,543.31 0.91 1,358.05 MWD+IFR2+MS+sag(3) 5,090.15 50.44 39.45 4,146.47 4,090.27 1,712.78 1,659.92 6,032,814.31 471,590.61 0.89 1,407.60 MWD+IFR2+MS+sag(3) 5,185.51 51.01 37.43 4,206.84 4,150.64 1,770.59 1,705.80 6,032,871.94 471,636.73 1.75 1,456.83 MWD+IFR2+MS+sag(3) 5,280.47 50.10 37.49 4,267.17 4,210.97 1,828.80 1,750.40 6,032,929.96 471,681.56 0.96 1,506.67 MWD+IFR2+MS+sag(3) 5,375.64 49.67 38.02 4,328.49 4,272.29 1,886.35 1,794.96 6,032,987.32 471,726.35 0.62 1,555.85 MWD+IFR2+MS+sag(3) 5,471.03 51.32 37.62 4,389.17 4,332.97 1,944.48 1,840.09 6,033,045.27 471,771.70 1.76 1,605.53 MWD+IFR2+MS+sag(3) 5,565.75 51.40 38.05 4,448.32 4,392.12 2,002.92 1,885.47 6,033,103.51 471,817.32 0.36 1,655.45 MWD+IFR2+MS+sag(3) 5,661.24 51.07 37.96 4,508.10 4,451.90 2,061.58 1,931.31 6,033,161.98 471,863.39 0.35 1,705.52 MWD+IFR2+MS+sag(3) 5,755.74 50.60 37.62 4,567.79 4,511.59 2,119.48 1,976.21 6,033,219.70 471,908.52 0.57 1,755.00 MWD+IFR2+MS+sag(3) 5,852.58 50.84 37.86 4,629.10 4,572.90 2,178.76 2,022.09 6,033,278.78 471,954.64 0.31 1,805.68 MWD+IFR2+MS+sag(3) 5,948.17 51.25 37.06 4,689.20 4,633.00 2,237.77 2,067.30 6,033,337.60 472,000.08 0.78 1,856.19 MWD+IFR2+MS+sag(3) 6,041.98 50.15 37.38 4,748.61 4,692.41 2,295.57 2,111.21 6,033,395.22 472,044.22 1.20 1,905.75 MWD+IFR2+MS+sag(3) 6,136.90 49.57 37.71 4,809.80 4,753.60 2,353.11 2,155.43 6,033,452.57 472,088.66 0.67 1,954.98 MWD+IFR2+MS+sag(3) 6,233.24 49.87 39.47 4,872.09 4,815.89 2,410.55 2,201.27 6,033,509.82 472,134.73 1.43 2,003.85 MWD+IFR2+MS+sag(3) 6,327.80 50.83 38.16 4,932.43 4,876.23 2,467.28 2,246.90 6,033,566.36 472,180.59 1.47 2,052.05 MWD+IFR2+MS+sag(3) 6,422.21 50.76 37.12 4,992.11 4,935.91 2,525.21 2,291.58 6,033,624.10 472,225.49 0.86 2,101.60 MWD+IFR2+MS+sag(3) 6,517.54 51.12 37.06 5,052.18 4,995.98 2,584.26 2,336.22 6,033,682.96 472,270.37 0.38 2,152.25 MWD+IFR2+MS+sag(3) 6,612.58 50.97 38.58 5,111.93 5,055.73 2,642.64 2,381.53 6,033,741.15 472,315.91 1.25 2,202.13 MWD+IFR2+MS+sag(3) 6,708.03 50.51 38.55 5,172.34 5,116.14 2,700.42 2,427.60 6,033,798.75 472,362.21 0.48 2,251.30 MWD+IFR2+MS+sag(3) 6,803.17 50.84 38.39 5,232.63 5,176.43 2,758.04 2,473.39 6,033,856.18 472,408.23 0.37 2,300.35 MWD+IFR2+MS+sag(3) 6,898.93 51.00 39.16 5,293.00 5,236.80 2,816.00 2,519.94 6,033,913.93 472,455.01 0.65 2,349.60 MWD+IFR2+MS+sag(3) 6,994.31 51.17 38.97 5,352.91 5,296.71 2,873.62 2,566.71 6,033,971.36 472,502.01 0.24 2,398.49 MWD+IFR2+MS+sag(3) 7,089.04 51.17 37.23 5,412.31 5,356.11 2,931.69 2,612.24 6,034,029.24 472,547.77 1.43 2,448.03 MWD+IFR2+MS+sag(3) 7,186.05 50.62 36.84 5,473.50 5,417.30 2,991.78 2,657.58 6,034,089.14 472,593.35 0.65 2,499.59 MWD+IFR2+MS+sag(3) 7,239.97 51.01 37.04 5,507.57 5,451.37 3,025.18 2,682.70 6,034,122.44 472,618.60 0.78 2,528.27 MWD+IFR2+MS+sag(4) 7,253.31 51.20 37.06 5,515.94 5,459.74 3,033.47 2,688.96 6,034,130.70 472,624.89 1.43 2,535.38 MWD+IFR2+MS+sag(4) 7,347.99 51.20 38.68 5,575.27 5,519.07 3,091.71 2,734.25 6,034,188.75 472,670.41 1.33 2,585.14 MWD+IFR2+MS+sag(4) 7,443.25 50.19 38.10 5,635.62 5,579.42 3,149.48 2,780.03 6,034,246.33 472,716.42 1.16 2,634.34 MWD+IFR2+MS+sag(4) 7,538.01 49.51 37.02 5,696.72 5,640.52 3,206.90 2,824.18 6,034,303.56 472,760.80 1.13 2,683.46 MWD+IFR2+MS+sag(4) 7,633.13 50.49 34.29 5,757.86 5,701.66 3,266.10 2,866.64 6,034,362.59 472,803.49 2.43 2,734.64 MWD+IFR2+MS+sag(4) 7,728.76 51.43 30.23 5,818.11 5,761.91 3,328.90 2,906.25 6,034,425.22 472,843.35 3.44 2,789.84 MWD+IFR2+MS+sag(4) 7,822.71 52.22 26.12 5,876.20 5,820.00 3,393.98 2,941.10 6,034,490.15 472,878.46 3.54 2,848.10 MWD+IFR2+MS+sag(4) 7,919.13 51.97 19.97 5,935.47 5,879.27 3,463.93 2,970.86 6,034,559.97 472,908.50 5.04 2,912.01 MWD+IFR2+MS+sag(4) 8,014.10 52.00 15.77 5,993.97 5,937.77 3,535.11 2,993.81 6,034,631.06 472,931.74 3.48 2,978.29 MWD+IFR2+MS+sag(4) 8,109.08 54.08 9.02 6,051.12 5,994.92 3,609.17 3,010.03 6,034,705.04 472,948.25 6.08 3,048.54 MWD+IFR2+MS+sag(4) 12/142012 I1:00:26AM Page 4 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'©56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'©56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 Database: EDM Alaska 'Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 8,204.65 55.50 4.49 6,106.24 6,050.04 3,686.68 3,019.18 6,034,782.51 472,957.72 4.15 3,123.39 MWD+IFR2+MS+sag(4) 8,299.52 56.76 357.64 6,159.15 6,102.95 3,765.36 3,020.61 6,034,861.17 472,959.46 6.14 3,200.70 MWD+IFR2+MS+sag(4) 8,395.04 59.96 354.49 6,209.26 6,153.06 3,846.47 3,014.99 6,034,942.29 472,954.17 4.37 3,281.58 MWD+IFR2+MS+sag(4) 8,490.01 63.54 352.73 6,254.21 6,198.01 3,929.58 3,005.66 6,035,025.43 472,945.18 4.11 3,365.08 MWD+IFR2+MS+sag(4) 8,585.18 68.13 351.60 6,293.16 6,236.96 4,015.58 2,993.81 6,035,111.47 472,933.68 4.94 3,451.84 MWD+IFR2+MS+sag(4) 8,680.70 72.73 351.59 6,325.15 6,268.95 4,104.59 2,980.66 6,035,200.52 472,920.89 4.82 3,541.80 MWD+IFR2+MS+sag(4) 8,775.68 77.59 351.73 6,349.47 6,293.27 4,195.40 2,967.35 6,035,291.38 472,907.95 5.12 3,633.55 MWD+IFR2+MS+sag(4) 8,871.40 81.78 350.38 6,366.60 6,310.40 4,288.40 2,952.70 6,035,384.43 472,893.68 4.59 3,727.69 MWD+IFR2+MS+sag(4) 8,966.20 85.58 350.25 6,377.04 6,320.84 4,381.27 2,936.85 6,035,477.35 472,878.21 4.01 3,821.90 MWD+IFR2+MS+sag(4) 9,017.12 87.31 349.59 6,380.19 6,323.99 4,431.30 2,927.96 6,035,527.41 472,869.52 3.64 3,872.72 MWD+IFR2+MS+sag(4) 9,060.56 87.43 349.78 6,382.19 6,325.99 4,474.00 2,920.19 6,035,570.13 472,861.92 0.52 3,916.11 MWD+IFR2+MS+sag(4) 9,112.53 87.43 349.67 6,384.52 6,328.32 4,525.08 2,910.93 6,035,621.25 472,852.87 0.21 3,968.03 MWD+IFR2+MS+sag(4) 9,156.56 87.01 349.26 6,386.65 6,330.45 4,568.32 2,902.89 6,035,664.52 472,845.00 1.33 4,012.00 MWD+IFR2+MS+sag(4) 9,252.44 87.06 344.00 6,391.62 6,335.42 4,661.44 2,880.75 6,035,757.72 472,823.25 5.48 4,107.53 MWD+IFR2+MS+sag(4) 9,346.04 85.39 339.79 6,397.78 6,341.58 4,750.19 2,851.74 6,035,846.58 472,794.60 4.83 4,199.90 MWD+IFR2+MS+sag(4) 9,442.51 84.96 334.69 6,405.90 6,349.70 4,838.81 2,814.56 6,035,935.33 472,757.78 5.29 4,293.52 MWD+IFR2+MS+sag(4) 9,537.10 85.58 330.13 6,413.70 6,357.50 4,922.33 2,770.91 6,036,019.02 472,714.48 4.85 4,383.22 MWD+IFR2+MS+sag(4) 9,632.57 85.64 324.03 6,421.02 6,364.82 5,002.20 2,719.21 6,036,099.09 472,663.10 6.37 4,470.68 MWD+IFR2+MS+sag(4) 9,663.68 85.70 322.57 6,423.37 6,367.17 5,027.07 2,700.67 6,036,124.03 472,644.66 4.68 4,498.33 MWD+IFR2+MS+sag(4) 9,697.60 85.58 320.58 6,425.95 6,369.75 5,053.56 2,679.65 6,036,150.61 472,623.75 5.86 4,527.99 MWD+IFR2+MS+sag(4) 9,776.75 87.78 318.00 6,430.53 6,374.33 5,113.45 2,628.12 6,036,210.70 472,572.47 4.28 4,595.73 MWD+IFR2+MS+sag(5) 9,862.68 88.58 317.11 6,433.26 6,377.06 5,176.83 2,570.16 6,036,274.30 472,514.77 1.39 4,667.99 MWD+IFR2+MS+sag(5) 9,959.37 88.46 317.67 6,435.76 6,379.56 5,247.97 2,504.72 6,036,345.70 472,449.63 0.59 4,749.16 MWD+IFR2+MS+sag(5) 10,055.30 86.60 317.60 6,439.89 6,383.69 5,318.78 2,440.14 6,036,416.76 472,385.34 1.94 4,829.87 MWD+IFR2+MS+sag(5) 10,152.06 88.21 316.05 6,444.27 6,388.07 5,389.26 2,374.00 6,036,487.51 472,319.50 2.31 4,910.52 MWD+IFR2+MS+sag(5) 10,248.25 90.74 313.95 6,445.15 6,388.95 5,457.27 2,306.00 6,036,555.78 472,251.78 3.42 4,989.04 MWD+IFR2+MS+sag(5) 10,344.58 90.99 313.70 6,443.70 6,387.50 5,523.96 2,236.51 6,036,622.75 472,182.56 0.37 5,066.52 MWD+IFR2+MS+sag(5) 10,441.15 91.67 313.39 6,441.46 6,385.26 5,590.47 2,166.53 6,036,689.54 472,112.86 0.77 5,143.90 MWD+IFR2+MS+sag(5) 10,536.95 92.22 312.87 6,438.21 6,382.01 5,655.93 2,096.66 6,036,755.27 472,043.26 0.79 5,220.22 MWD+IFR2+MS+sag(5) 10,633.35 91.85 314.43 6,434.78 6,378.58 5,722.43 2,026.95 6,036,822.04 471,973.83 1.66 5,297.54 MWD+IFR2+MS+sag(5) 10,729.68 90.56 314.67 6,432.76 6,376.56 5,789.99 1,958.32 6,036,889.87 471,905.48 1.36 5,375.73 MWD+IFR2+MS+sag(5) 10,825.68 91.30 314.76 6,431.20 6,375.00 5,857.52 1,890.11 6,036,957.68 471,837.55 0.78 5,453.82 MWD+IFR2+MS+sag(5) 10,922.06 90.37 313.66 6,429.80 6,373.60 5,924.72 1,821.03 6,037,025.15 471,768.76 1.49 5,531.73 MWD+IFR2+MS+sag(5) 11,018.42 91.17 310.85 6,428.50 6,372.30 5,989.50 1,749.73 6,037,090.21 471,697.72 3.03 5,607.63 MWD+IFR2+MS+sag(5) 11,115.04 92.47 310.17 6,425.43 6,369.23 6,052.23 1,676.31 6,037,153.23 471,624.56 1.52 5,681.87 MWD+IFR2+MS+sag(5) 11,210.97 92.59 309.82 6,421.20 6,365.00 6,113.83 1,602.89 6,037,215.12 471,551.40 0.39 5,754.98 MWD+IFR2+MS+sag(5) 11,307.49 92.29 311.57 6,417.09 6,360.89 6,176.70 1,529.78 6,037,278.28 471,478.55 1.84 5,829.31 MWD+IFR2+MS+sag(5) 11,403.74 91.54 313.13 6,413.87 6,357.67 6,241.50 1,458.69 6,037,343.36 471,407.73 1.80 5,905.19 MWD+IFR2+MS+sag(5) 11,500.65 91.61 314.11 6,411.21 6,355.01 6,308.33 1,388.56 6,037,410.47 471,337.88 1.01 5,982.91 MWD+IFR2+MS+sag(5) 11,595.80 92.16 315.42 6,408.08 6,351.88 6,375.30 1,321.04 6,037,477.70 471,270.64 1.49 6,060.33 MWD+IFR2+MS+sag(5) 12/142012 11:00:26AM Page 5 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'©56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 Database: EDM Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,692.96 89.82 317.05 6,406.40 6,350.20 6,445.45 1,253.85 6,037,548.11 471,203.74 2.93 6,140.82 MWD+IFR2+MS+sag(5) 11,787.10 89.75 316.37 6,406.75 6,350.55 6,513.97 1,189.30 6,037,616.89 471,139.47 0.73 6,219.27 MWD+IFR2+MS+sag(5) 11,885.85 90.06 316.41 6,406.92 6,350.72 6,585.47 1,121.19 6,037,688.66 471,071.66 0.32 6,301.25 MWD+IFR2+MS+sag(5) 11,930.00 91.64 315.62 6,406.26 6,350.06 6,617.23 1,090.53 6,037,720.54 471,041.13 4.00 6,337.74 MWD+IFR2+MS+sag(6) 11,982.38 88.70 316.59 6,406.11 6,349.91 6,654.98 1,054.22 6,037,758.42 471,004.98 5.91 6,381.08 MWD+IFR2+MS+sag(6) 12,078.63 90.49 317.22 6,406.79 6,350.59 6,725.25 988.46 6,037,828.96 470,939.51 1.97 6,461.46 MWD+IFR2+MS+sag(6) 12,173.76 89.69 319.77 6,406.64 6,350.44 6,796.49 925.43 6,037,900.44 470,876.77 2.81 6,542.32 MWD+IFR2+MS+sag(6) 12,270.70 88.95 319.99 6,407.79 6,351.59 6,870.61 862.97 6,037,974.81 470,814.62 0.80 6,625.94 MWD+IFR2+MS+sag(6) 12,367.70 90.00 322.34 6,408.68 6,352.48 6,946.16 802.15 6,038,050.60 470,754.11 2.65 6,710.68 MWD+IFR2+MS+sag(6) 12,463.93 90.37 324.79 6,408.36 6,352.16 7,023.58 745.00 6,038,128.24 470,697.28 2.57 6,796.63 MWD+IFR2+MS+sag(6) 12,560.38 87.10 323.14 6,410.49 6,354.29 7,101.54 688.28 6,038,206.42 470,640.89 3.80 6,883.06 MWD+IFR2+MS+sag(6) 12,656.14 88.21 318.40 6,414.41 6,358.21 7,175.63 627.79 6,038,280.75 470,580.70 5.08 6,966.31 MWD+IFR2+MS+sag(6) 12,753.18 88.46 312.81 6,417.24 6,361.04 7,244.91 559.96 6,038,350.30 470,513.16 5.76 7,046.06 MWD+IFR2+MS+sag(6) 12,849.23 92.10 310.33 6,416.77 6,360.57 7,308.63 488.12 6,038,414.30 470,441.58 4.59 7,121.00 MWD+IFR2+MS+sag(6) 12,945.70 91.91 311.58 6,413.39 6,357.19 7,371.82 415.31 6,038,477.78 470,369.03 1.31 7,195.59 MWD+IFR2+MS+sag(6) 13,041.26 92.60 311.23 6,409.63 6,353.43 7,434.97 343.69 6,038,541.21 470,297.68 0.81 7,269.94 MWD+IFR2+MS+sag(6) 13,138.40 92.78 310.74 6,405.07 6,348.87 7,498.61 270.44 6,038,605.14 470,224.70 0.54 7,345.04 MWD+IFR2+MS+sag(7) 13,160.00 92.77 310.86 6,404.03 6,347.83 7,512.71 254.11 6,038,619.30 470,208.42 0.56 7,361.70 MWD+IFR2+MS+sag(7) 13,234.94 90.68 312.66 6,401.77 6,345.57 7,562.60 198.24 6,038,669.41 470,152.76 3.68 7,420.30 MWD+IFR2+MS+sag(7) 13,266.42 91.23 316.02 6,401.25 6,345.05 7,584.59 175.73 6,038,691.49 470,130.34 10.81 7,445.79 MWD+IFR2+MS+sag(7) 13,298.81 91.05 319.60 6,400.60 6,344.40 7,608.58 153.98 6,038,715.57 470,108.70 11,06 7,473.11 MWD+IFR2+MS+sag(7) 13,331.05 89.75 321.63 6,400.38 6,344.18 7,633.50 133.53 6,038,740.56 470,088.35 7.48 7,501.12 MWD+IFR2+MS+sag(7) 13,375.93 87.03 320.97 6,401.64 6,345.44 7,668.50 105.48 6,038,775.68 470,060.44 6.24 7,540.37 MWD+IFR2+MS+sag(7) 13,425.25 87.30 320.72 6,404.08 6,347.88 7,706.70 74.38 6,038,814.00 470,029.50 0.75 7,583.27 MWD+IFR2+MS+sag(7) 13,521.42 87.61 320.24 6,408.35 6,352.15 7,780.82 13.24 6,038,888.35 469,968.67 0.59 7,666.65 MWD+IFR2+MS+sag(7) 13,620.64 87.37 318.22 6,412.69 6,356.49 7,855.88 -51.49 6,038,963.67 469,904.25 2.05 7,751.58 MWD+IFR2+MS+sag(7) 13,713.69 88.09 316.20 6,416.38 6,360.18 7,924.11 -114.64 6,039,032.15 469,841.38 2.30 7,829.50 MWD+IFR2+MS+sag(7) 13,813.11 87.22 317.68 6,420.45 6,364.25 7,996.69 -182.46 6,039,104.99 469,773.86 1.73 7,912.49 MWD+IFR2+MS+sag(7) 13,908.93 89.73 316.11 6,423.00 6,366.80 8,066.61 -247.91 6,039,175.17 469,708.70 3.09 7,992.47 MWD+IFR2+MS+sag(7) 14,006.48 90.23 315.81 6,423.03 6,366.83 8,136.73 -315.72 6,039,245.56 469,641.18 0.60 8,073.05 MWD+IFR2+MS+sag(7) 14,102.79 89.29 314.52 6,423.43 6,367.23 8,205.03 -383.63 6,039,314.13 469,573.56 1.66 8,151.84 MWD+IFR2+MS+sag(7) 14,195.99 89.38 313.30 6,424.52 6,368.32 8,269.66 -450.76 6,039,379.02 469,506.69 1.31 8,226.88 MWD+IFR2+MS+sag(7) 14,293.79 89.56 313.82 6,425.42 6,369.22 8,337.05 -521.63 6,039,446.69 469,436.10 0.56 8,305.28 MWD+IFR2+MS+sag(7) 14,390.20 88.63 314.82 6,426.94 6,370.74 8,404.40 -590.60 6,039,514.31 469,367.42 1.42 8,383.32 MWD+IFR2+MS+sag(7) 14,485.27 90.58 314.45 6,427.60 6,371.40 8,471.19 -658.25 6,039,581.37 469,300.05 2.09 8,460.58 MWD+IFR2+MS+sag(7) 14,581.72 89.93 314.43 6,427.17 6,370.97 8,538.72 -727.11 6,039,649.17 469,231.47 0.67 8,538.78 MWD+IFR2+MS+sag(7) 14,679.67 89.62 313.98 6,427.55 6,371.35 8,607.01 -797.32 6,039,717.74 469,161.54 0.56 8,617.95 MWD+IFR2+MS+sag(7) 14,776.13 89.10 313.02 6,428.63 6,372.43 8,673.41 -867.29 6,039,784.41 469,091.85 1.13 8,695.22 MWD+IFR2+MS+sag(7) 14,872.86 89.03 312.36 6,430.21 6,374.01 8,738 98 -938.38 6,039,850.27 469,021.03 0.69 8,771.86 MWD+IFR2+MS+sag(7) 14,964.83 89.75 313.07 6,431.19 6,374.99 8,801.37 -1,005.95 6,039,912.92 468,953.72 1.10 8,844.77 MWD+IFR2+MS+sag(7) 12/142012 11:00:26AM Page 6 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'©56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 Database: EDM_Alaska ,Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) ('11001 (ft) Survey Tool Name 15,063.55 89.94 312.28 6,431.46 6,375.26 8,868.28 -1,078.53 6,039,980.12 468,881.42 0.82 8,922.99 MWD+IFR2+MS+sag(7) 15,155.42 90.03 312,05 6,431.48 6,375.28 8,929.95 -1,146.62 6,040,042.06 468,813.58 0.27 8,995.28 MWD+IFR2+MS+sag(7) 15,254.31 90.00 312.14 6,431.45 6,375.25 8,996.24 -1,220.00 6,040,108.64 468,740.48 0.10 9,073.02 MWD+IFR2+MS+sag(7) 15,351.08 90.52 313.51 6,431.02 6,374.82 9,062.02 -1,290.97 6,040,174.70 468,669.78 1.51 9,149.85 MWD+IFR2+MS+sag(7) 15,448.71 90.06 314.71 6,430.52 6,374.32 9,129.97 -1,361.07 6,040,242.92 468,599.97 1.32 9,228.67 MWD+IFR2+MS+sag(7) 15,545.35 90.69 316.31 6,429.89 6,373.69 9,198.91 -1,428.79 6,040,312.13 468,532.53 1.78 9,308.06 MWD+IFR2+MS+sag(7) 15,641.71 89.87 316.89 6,429.42 6,373.22 9,268.92 -1,494.99 6,040,382.40 468,466.62 1.04 9,388.25 MWD+IFR2+MS+sag(7) 15,716.00 89.87 316.89 6,429.59 6,373.39 9,323.16 -1,545.76 6,040,436.83 468,416.07 0.00 9,450.29 PROJECTED to TD 12/14/2012 11:00:26AM Page 7 COMPASS 2003.16 Build 42 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-29 PN5 PB1 50-703-20661-00-70 Sperry Drilling Services Definitive Survey Report 14 December, 2012 HALLIBURTON Sperry Drilling Services Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB1 Database: EDM_Alaska Project Oooguruk Development Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well ODSN-29 Well Position +N/-S 0.00 ft Northing: 6,031,108.44 ft Latitude: 70°29'45.820 N +E/-W 0.00 ft Easting: 469,923.95 ft Longitude: 150°14'45.357 W'' Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft Wellbore ODSN-29 PN5 PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF2010 10/10/2012 20.57 80.97 57,668 Design ODSN-29 PN5 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) (bearing) 42.70 0.00 0.00 350.27 Survey Program Date 12/14/2012 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 100.00 729.00 ODSN-29 GYRO(ODSN-29 PN5 PB1) SRG-SS Surface readout gyro single shot 11/07/2012 775.48 4,139.70 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2.IIFR dec&3-axis correction+sag 11/08/2012 4,139.70 7,238.00 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 7,238.00 9,759.10 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 9,759.10 12,367.53 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (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 6,031,108.44 469,923.95 0.00 0.00 UNDEFINED 100.00 0.12 142.74 100.00 43.80 -0.05 0.04 6,031,108.39 469,923.99 0.21 -0.05 SRG-SS(1) 172.00 0.15 342.94 172.00 115.80 -0.02 0.05 6,031,108.42 469,924.00 0.37 -0.03 SRG-SS(1) 261.00 1.50 148.91 260.99 204.79 -0.90 0.62 6,031,107.53 469,924.57 1.85 -1.00 SRG-SS(1) 354.00 4.95 146.57 353.83 297.63 -5.30 3.46 6,031,103.13 469,927.39 3.71 -5.80 SRG-SS(1) 448.00 9.11 143.99 447.10 390.90 -14.70 10.07 6,031,093.70 469,933.96 4.44 -16.20 SRG-SS(1) 541.00 11.62 142.76 538.58 482.38 -28.12 20.07 6,031,080.24 469,943.91 2.71 -31.11 SRG-SS(1) 636.00 10.55 138.46 631.81 575.61 -42.25 31.63 6,031,066.07 469,955.41 1.42 -46.98 SRG-SS(1) 729.00 10.64 121.05 723.24 667.04 -53.05 44.63 6,031,055.22 469,968.36 3.43 -59.83 SRG-SS(1) 775.48 10.70 114.93 768.92 712.72 -57.08 52.22 6,031,051.15 469,975.94 2.44 -65.09 MWD+IFR2+MS+sag(2) 12/142012 12:52:27PM Page 2 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5' 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Weilbore: ODSN-29 PN5 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB1 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 871.35 10.29 106.10 863.19 806.99 -63.21 68.52 6,031,044.96 469,992.21 1.73 -73.88 MWD+IFR2+MS+sag(2) 967.21 8.57 109.64 957.76 901.56 -67.98 83.48 6,031,040.13 470,007.14 1.89 -81.11 MWD+IFR2+MS+sag(2) 1,057.98 8.88 89.26 1,047.50 991.30 -70.17 96.85 6,031,037.89 470,020.51 3.40 -85.53 MWD+IFR2+MS+sag(2) 1,156.87 8.63 82.17 1,145.24 1,089.04 -69.06 111.84 6,031,038.94 470,035.50 1.12 -86.96 MWD+IFR2+MS+sag(2) 1,252.66 9.64 75.68 1,239.81 1,183.61 -66.09 126.73 6,031,041.84 470,050.40 1.50 -86.56 MWD+IFR2+MS+sag(2) 1,344.56 11.97 66.08 1,330.09 1,273.89 -60.33 142.90 6,031,047.54 470,066.59 3.20 -83.61 MWD+IFR2+MS+sag(2) 1,443.83 14.03 61.93 1,426.81 1,370.61 -50.49 162.93 6,031,057.30 470,086.66 2.28 -77.30 MWD+IFR2+MS+sag(2) 1,538.72 16.10 60.74 1,518.43 1,462.23 -38.64 184.56 6,031,069.05 470,108.33 2.21 -69.28 MWD+IFR2+MS+sag(2) 1,630.58 18.58 58.48 1,606.11 1,549.91 -24.76 208.15 6,031,082.84 470,131.98 2.80 -59.59 MWD+IFR2+MS+sag(2) 1,726.05 20.24 53.90 1,696.16 1,639.96 -7.08 234.46 6,031,100.41 470,158.36 2.36 -46.60 MWD+IFR2+MS+sag(2) 1,823.57 23.59 50.42 1,786.62 1,730.42 15.30 263.14 6,031,122.67 470,187.13 3.68 -29.39 MWD+IFR2+MS+sag(2) 1,919.50 24.52 50.45 1,874.22 1,818.02 40.20 293.29 6,031,147.45 470,217.37 0.97 -9.94 MWD+IFR2+MS+sag(2) 2,012.11 26.18 49.20 1,957.91 1,901.71 65.79 323.57 6,031,172.92 470,247.75 1.88 10.16 MWD+IFR2+MS+sag(2) 2,108.98 29.74 46.35 2,043.46 1,987.26 96.35 357.14 6,031,203.34 470,281.45 3.92 34.61 MWD+IFR2+MS+sag(2) 2,203.85 30.55 43.54 2,125.51 2,069.31 130.07 390.78 6,031,236.92 470,315.22 1.71 62.16 MWD+IFR2+MS+sag(2) 2,300.31 30.90 43.41 2,208.43 2,152.23 165.84 424.69 6,031,272.54 470,349.27 0.37 91.68 MWD+IFR2+MS+sag(2) 2,394.61 30.17 41.08 2,289.65 2,233.45 201.29 456.90 6,031,307.86 470,381.62 1.47 121.18 MWD+IFR2+MS+sag(2) 2,485.66 32.87 41.15 2,367.26 2,311.06 237.15 488.20 6,031,343.59 470,413.06 2.97 151.23 MWD+IFR2+MS+sag(2) 2,582.97 34.96 40.94 2,448.01 2,391.81 278.10 523.85 6,031,384.39 470,448.87 2.15 185.56 MWD+IFR2+MS+sag(2) 2,676.49 35.93 37.95 2,524.20 2,468.00 319.98 558.29 6,031,426.12 470,483.47 2.12 221.02 MWD+IFR2+MS+sag(2) 2,772.74 37.48 37.32 2,601.37 2,545.17 365.54 593.41 6,031,471.54 470,518.77 1.66 259.99 MWD+IFR2+MS+sag(2) 2,866.80 38.36 38.20 2,675.57 2,619.37 411.23 628.81 6,031,517.08 470,554.35 1.10 299.05 MWD+IFR2+MS+sag(2) 2,962.28 39.48 38.14 2,749.85 2,693.65 458.39 665.88 6,031,564.09 470,591.61 1.17 339.26 MWD+IFR2+MS+sag(2) 3,056.78 42.54 37.76 2,821.15 2,764.95 507.29 704.00 6,031,612.82 470,629.93 3.25 381.01 MWD+IFR2+MS+sag(2) 3,152.51 44.40 38.36 2,890.62 2,834.42 559.14 744.61 6,031,664.50 470,670.74 1.99 425.25 MWD+IFR2+MS+sag(2) 3,244.56 45.78 38.50 2,955.61 2,899.41 610.20 785.13 6,031,715.40 470,711.46 1.50 468.73 MWD+IFR2+MS+sag(2) 3,339.91 44.52 38.40 3,022.85 2,966.65 663.14 827.16 6,031,768.16 470,753.70 1.32 513.81 MWD+IFR2+MS+sag(2) 3,437.78 44.79 38.83 3,092.47 3,036.27 716.89 870.09 6,031,821.73 470,796.84 0.41 559.52 MWD+IFR2+MS+sag(2) 3,531.82 46.35 36.87 3,158.31 3,102.11 769.92 911.28 6,031,874.59 470,838.24 2.23 604.83 MWD+IFR2+MS+sag(2) 3,628.46 46.31 36.78 3,225.04 3,168.84 825.87 953.18 6,031,930.36 470,880.36 0.08 652.90 MWD+IFR2+MS+sag(2) 3,721.08 49.15 38.54 3,287.33 3,231.13 880.10 995.06 6,031,984.42 470,922.46 3.37 699.27 MWD+IFR2+MS+sag(2) 3,815.98 52.06 38.95 3,347.55 3,291.35 937.29 1,040.96 6,032,041.42 470,968.59 3.08 747.88 MWD+IFR2+MS+sag(2) 3,913.69 53.35 38.96 3,406.76 3,350.56 997.74 1,089.83 6,032,101.66 471,017.70 1.32 799.20 MWD+IFR2+MS+sag(2) 4,007.06 52.27 39.23 3,463.20 3,407.00 1,055.47 1,136.73 6,032,159.19 471,064.83 1.18 848.17 MWD+IFR2+MS+sag(2) 4,093.51 53.19 39.45 3,515.55 3,459.35 1,108.67 1,180.34 6,032,212.22 471,108.65 1.08 893.24 MWD+IFR2+MS+sag(2) 4,193.35 50.77 38.33 3,577.04 3,520.84 1,169.88 1,229.73 6,032,273.22 471,158.28 2.58 945.22 MWD+IFR2+MS+sag(3) 4,235.17 50.22 38.20 3,603.64 3,547.44 1,195.21 1,249.71 6,032,298.47 471,178.36 1.34 966.81 MWD+IFR2+MS+sag(3) 4,329.62 50.67 36.91 3,663.79 3,607.59 1,252.94 1,294.10 6,032,356.01 471,222.97 1.16 1,016.21 MWD+IFR2+MS+sag(3) 4,424.83 50.66 37.77 3,724.14 3,667.94 1,311.49 1,338.76 6,032,414.37 471,267.87 0.70 1,066.37 MWD+IFR2+MS+sag(3) 4,520.03 51.23 38.51 3,784.12 3,727.92 1,369.63 1,384.42 6,032,472.32 471,313.76 0.85 1,115.96 MWD+IFR2+MS+sag(3) 12/14/2012 12:52:27PM Page 3 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB1 Database: EDM Alaska Survey Map Map Vertical MD Inc Az! TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,614.29 51.72 40.80 3,842.84 3,786.64 1,426.40 1,431.48 6,032,528.89 471,361.04 1.97 1,163.95 MWD+IFR2+MS+sag(3) 4,710.58 51.23 38.43 3,902.82 3,846.62 1,484.42 1,479.51 6,032,586.71 471,409.30 1.99 1,213.02 MWD+IFR2+MS+sag(3) 4,805.30 49.64 37.91 3,963.15 3,906.95 1,541.82 1,524.63 6,032,643.92 471,454.66 1.73 1,261.97 MWD+IFR2+MS+sag(3) 4,899.73 49.48 38.02 4,024.40 3,968.20 1,598.48 1,568.85 6,032,700.40 471,499.09 0.19 1,310.34 MWD+IFR2+MS+sag(3) 4,992.80 50.29 38.34 4,084.37 4,028.17 1,654.43 1,612.84 6,032,756.16 471,543.31 0.91 1,358.05 MWD+IFR2+MS+sag(3) 5,090.15 50.44 39.45 4,146.47 4,090.27 1,712.78 1,659.92 6,032,814.31 471,590.61 0.89 1,407.60 MWD+IFR2+MS+sag(3) 5,185.51 51.01 37.43 4,206.84 4,150.64 1,770.59 1,705.80 6,032,871.94 471,636.73 1.75 1,456.83 MWD+IFR2+MS+sag(3) 5,280.47 50.10 37.49 4,267.17 4,210.97 1,828.80 1,750.40 6,032,929.96 471,681.56 0.96 1,506.67 MWD+IFR2+MS+sag(3) 5,375.64 49.67 38.02 4,328.49 4,272.29 1,886.35 1,794.96 6,032,987.32 471,726.35 0.62 1,555.85 MWD+IFR2+MS+sag(3) 5,471.03 51.32 37.62 4,389.17 4,332.97 1,944.48 1,840.09 6,033,045.27 471,771.70 1.76 1,605.53 MWD+IFR2+MS+sag(3) 5,565.75 51.40 38.05 4,448.32 4,392.12 2,002.92 1,885.47 6,033,103.51 471,817.32 0.36 1,655.45 MWD+IFR2+MS+sag(3) 5,661.24 51.07 37.96 4,508.10 4,451.90 2,061.58 1,931.31 6,033,161.98 471,863.39 0.35 1,705.52 MWD+IFR2+MS+sag(3) 5,755.74 50.60 37.62 4,567.79 4,511.59 2,119.48 1,976.21 6,033,219.70 471,908.52 0.57 1,755.00 MWD+IFR2+MS+sag(3) 5,852.58 50.84 37.86 4,629.10 4,572.90 2,178.76 2,022.09 6,033,278.78 471,954.64 0.31 1,805.68 MWD+IFR2+MS+sag(3) 5,948.17 51.25 37.06 4,689.20 4,633.00 2,237.77 2,067.30 6,033,337.60 472,000.08 0.78 1,856.19 MWD+IFR2+MS+sag(3) 6,041.98 50.15 37.38 4,748.61 4,692.41 2,295.57 2,111.21 6,033,395.22 472,044.22 1.20 1,905.75 MWD+IFR2+MS+sag(3) 6,136.90 49.57 37.71 4,809.80 4,753.60 2,353.11 2,155.43 6,033,452.57 472,088.66 0.67 1,954.98 MWD+IFR2+MS+sag(3) 6,233.24 49.87 39.47 4,872.09 4,815.89 2,410.55 2,201.27 6,033,509.82 472,134.73 1.43 2,003.85 MWD+IFR2+MS+sag(3) 6,327.80 50.83 38.16 4,932.43 4,876.23 2,467.28 2,246.90 6,033,566.36 472,180.59 1.47 2,052.05 MWD+IFR2+MS+sag(3) 6,422.21 50.76 37.12 4,992.11 4,935.91 2,525.21 2,291.58 6,033,624.10 472,225.49 0.86 2,101.60 MWD+IFR2+MS+sag(3) 6,517.54 51.12 37.06 5,052.18 4,995.98 2,584.26 2,336.22 6,033,682.96 472,270.37 0.38 2,152.25 MWD+IFR2+MS+sag(3) 6,612.58 50.97 38.58 5,111.93 5,055.73 2,642.64 2,381.53 6,033,741.15 472,315.91 1.25 2,202.13 MWD+IFR2+MS+sag(3) 6,708.03 50.51 38.55 5,172.34 5,116.14 2,700.42 2,427.60 6,033,798.75 472,362.21 0.48 2,251.30 MWD+IFR2+MS+sag(3) 6,803.17 50.84 38.39 5,232.63 5,176.43 2,758.04 2,473.39 6,033,856.18 472,408.23 0.37 2,300.35 MWD+IFR2+MS+sag(3) 6,898.93 51.00 39.16 5,293.00 5,236.80 2,816.00 2,519.94 6,033,913.93 472,455.01 0.65 2,349.60 MWD+IFR2+MS+sag(3) 6,994.31 51.17 38.97 5,352.91 5,296.71 2,873.62 2,566.71 6,033,971.36 472,502.01 0.24 2,398.49 MWD+IFR2+MS+sag(3) 7,089.04 51.17 37.23 5,412.31 5,356.11 2,931.69 2,612.24 6,034,029.24 472,547.77 1.43 2,448.03 MWD+IFR2+MS+sag(3) 7,186.05 50.62 36.84 5,473.50 5,417.30 2,991.78 2,657.58 6,034,089.14 472,593.35 0.65 2,499.59 MWD+IFR2+MS+sag(3) 7,239.97 51.01 37.04 5,507.57 5,451.37 3,025.18 2,682.70 6,034,122.44 472,618.60 0.78 2,528.27 MWD+IFR2+MS+sag(4) 7,253.31 51.20 37.06 5,515.94 5,459.74 3,033.47 2,688.96 6,034,130.70 472,624.89 1.43 2,535.38 MWD+IFR2+MS+sag(4) 7,347.99 51.20 38.68 5,575.27 5,519.07 3,091.71 2,734.25 6,034,188.75 472,670.41 1.33 2,585.14 MWD+IFR2+MS+sag(4) 7,443.25 50.19 38.10 5,635.62 5,579.42 3,149.48 2,780.03 6,034,246.33 472,716.42 1.16 2,634.34 MWD+IFR2+MS+sag(4) 7,538.01 49.51 37.02 5,696.72 5,640.52 3,206.90 2,824.18 6,034,303.56 472,760.80 1.13 2,683.46 MWD+IFR2+MS+sag(4) 7,633.13 50.49 34.29 5,757.86 5,701.66 3,266.10 2,866.64 6,034,362.59 472,803.49 2.43 2,734.64 MWD+IFR2+MS+sag(4) 7,728.76 51.43 30.23 5,818.11 5,761.91 3,328.90 2,906.25 6,034,425.22 472,843.35 3.44 2,789.84 MWD+IFR2+MS+sag(4) 7,822.71 52.22 26.12 5,876.20 5,820.00 3,393.98 2,941.10 6,034,490.15 472,878.46 3.54 2,848.10 MWD+IFR2+MS+sag(4) 7,919.13 51.97 19.97 5,935.47 5,879.27 3,463.93 2,970.86 6,034,559.97 472,908.50 5.04 2,912.01 MWD+IFR2+MS+sag(4) 8,014.10 52.00 15.77 5,993.97 5,937.77 3,535.11 2,993.81 6,034,631.06 472,931.74 3.48 2,978.29 MWD+IFR2+MS+sag(4) 8,109.08 54.08 9.02 6,051.12 5,994.92 3,609.17 3,010.03 6,034,705.04 472,948.25 6.08 3,048.54 MWD+IFR2+MS+sag(4) 8,204.65 55.50 4.49 6,106.24 6,050.04 3,686.68 3,019.18 6,034,782.51 472,957.72 4.15 3,123.39 MWD+IFR2+MS+sag(4) 12/14/2012 12:52:27PM Page 4 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB1 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (4/100') (ft) Survey Tool Name 8,299.52 56.76 357.64 6,159.15 6,102.95 3,765.36 3,020.61 6,034,861.17 472,959.46 6.14 3,200.70 MWD+IFR2+MS+sag(4) 8,395.04 59.96 354.49 6,209.26 6,153.06 3,846.47 3,014.99 6,034,942.29 472,954.17 4.37 3,281.58 MWD+IFR2+MS+sag(4) 8,490.01 63.54 352.73 6,254.21 6,198.01 3,929.58 3,005.66 6,035,025.43 472,945.18 4.11 3,365.08 MWD+IFR2+MS+sag(4) 8,585.18 68.13 351.60 6,293.16 6,236.96 4,015.58 2,993.81 6,035,111.47 472,933.68 4.94 3,451.84 MWD+IFR2+MS+sag(4) 8,680.70 72.73 351.59 6,325.15 6,268.95 4,104.59 2,980.66 6,035,200.52 472,920.89 4.82 3,541.80 MWD+IFR2+MS+sag(4) 8,775.68 77.59 351.73 6,349.47 6,293.27 4,195.40 2,967.35 6,035,291.38 472,907.95 5.12 3,633.55 MWD+IFR2+MS+sag(4) 8,871.40 81.78 350.38 6,366.60 6,310.40 4,288.40 2,952.70 6,035,384.43 472,893.68 4.59 3,727.69 MWD+IFR2+MS+sag(4) 8,966.20 85.58 350.25 6,377.04 6,320.84 4,381.27 2,936.85 6,035,477.35 472,878.21 4.01 3,821.90 MWD+IFR2+MS+sag(4) 9,017.12 87.31 349.59 6,380.19 6,323.99 4,431.30 2,927.96 6,035,527.41 472,869.52 3.64 3,872.72 MWD+IFR2+MS+sag(4) 9,060.56 87.43 349.78 6,382.19 6,325.99 4,474.00 2,920.19 6,035,570.13 472,861.92 0.52 3,916.11 MWD+IFR2+MS+sag(4) 9,112.53 87.43 349.67 6,384.52 6,328.32 4,525.08 2,910.93 6,035,621.25 472,852.87 0.21 3,968.03 MWD+IFR2+MS+sag(4) 9,156.56 87.01 349.26 6,386.65 6,330.45 4,568.32 2,902.89 6,035,664.52 472,845.00 1.33 4,012.00 MWD+IFR2+MS+sag(4) 9,252.44 87.06 344.00 6,391.62 6,335.42 4,661.44 2,880.75 6,035,757.72 472,823.25 5.48 4,107.53 MWD+IFR2+MS+sag(4) 9,346.04 85.39 339.79 6,397.78 6,341.58 4,750.19 2,851.74 6,035,846.58 472,794.60 4.83 4,199.90 MWD+IFR2+MS+sag(4) 9,442.51 84.96 334.69 6,405.90 6,349.70 4,838.81 2,814.56 6,035,935.33 472,757.78 5.29 4,293.52 MWD+IFR2+MS+sag(4) 9,537.10 85.58 330.13 6,413.70 6,357.50 4,922.33 2,770.91 6,036,019.02 472,714.48 4.85 4,383.22 MWD+IFR2+MS+sag(4) 9,632.57 85.64 324.03 6,421.02 6,364.82 5,002.20 2,719.21 6,036,099.09 472,663.10 6.37 4,470.68 MWD+IFR2+MS+sag(4) 9,663.68 85.70 322.57 6,423.37 6,367.17 5,027.07 2,700.67 6,036,124.03 472,644.66 4.68 4,498.33 MWD+IFR2+MS+sag(4) 9,697.60 85.58 320.58 6,425.95 6,369.75 5,053.56 2,679.65 6,036,150.61 472,623.75 5.86 4,527.99 MWD+IFR2+MS+sag(4) 9,776.75 87.78 318.00 6,430.53 6,374.33 5,113.45 2,628.12 6,036,210.70 472,572.47 4.28 4,595.73 MWD+IFR2+MS+sag(5) 9,862.68 88.58 317.11 6,433.26 6,377.06 5,176.83 2,570.16 6,036,274.30 472,514.77 1.39 4,667.99 MWD+IFR2+MS+sag(5) 9,959.37 88.46 317.67 6,435.76 6,379.56 5,247.97 2,504.72 6,036,345.70 472,449.63 0.59 4,749.16 MWD+IFR2+MS+sag(5) 10,055.30 86.60 317.60 6,439.89 6,383.69 5,318.78 2,440.14 6,036,416.76 472,385.34 1.94 4,829.87 MWD+IFR2+MS+sag(5) 10,152.06 88.21 316.05 6,444.27 6,388.07 5,389.26 2,374.00 6,036,487.51 472,319.50 2.31 4,910.52 MWD+IFR2+MS+sag(5) 10,248.25 90.74 313.95 6,445.15 6,388.95 5,457.27 2,306.00 6,036,555.78 472,251.78 3.42 4,989.04 MWD+IFR2+MS+sag(5) 10,344.58 90.99 313.70 6,443.70 6,387.50 5,523.96 2,236.51 6,036,622.75 472,182.56 0.37 5,066.52 MWD+IFR2+MS+sag(5) 10,441.15 91.67 313.39 6,441.46 6,385.26 5,590.47 2,166.53 6,036,689.54 472,112.86 0.77 5,143.90 MWD+IFR2+MS+sag(5) 10,536.95 92.22 312.87 6,438.21 6,382.01 5,655.93 2,096.66 6,036,755.27 472,043.26 0.79 5,220.22 MWD+IFR2+MS+sag(5) 10,633.35 91.85 314.43 6,434.78 6,378.58 5,722.43 2,026.95 6,036,822.04 471,973.83 1.66 5,297.54 MWD+IFR2+MS+sag(5) 10,729.68 90.56 314.67 6,432.76 6,376.56 5,789.99 1,958.32 6,036,889.87 471,905.48 1.36 5,375.73 MWD+IFR2+MS+sag(5) 10,825.68 91.30 314.76 6,431.20 6,375.00 5,857.52 1,890.11 6,036,957.68 471,837.55 0.78 5,453.82 MWD+IFR2+MS+sag(5) 10,922.06 90.37 313.66 6,429.80 6,373.60 5,924.72 1,821.03 6,037,025.15 471,768.76 1.49 5,531.73 MWD+IFR2+MS+sag(5) 11,018.42 91.17 310.85 6,428.50 6,372.30 5,989.50 1,749.73 6,037,090.21 471,697.72 3.03 5,607.63 MWD+IFR2+MS+sag(5) 11,115.04 92.47 310.17 6,425.43 6,369.23 6,052.23 1,676.31 6,037,153.23 471,624.56 1.52 5,681.87 MWD+IFR2+MS+sag(5) 11,210.97 92.59 309.82 6,421.20 6,365.00 6,113.83 1,602.89 6,037,215.12 471,551.40 0.39 5,754.98 MWD+IFR2+MS+sag(5) 11,307.49 92.29 311.57 6,417.09 6,360.89 6,176.70 1,529.78 6,037,278.28 471,478.55 1.84 5,829.31 MWD+IFR2+MS+sag(5) 11,403.74 91.54 313.13 6,413.87 6,357.67 6,241.50 1,458.69 6,037,343.36 471,407.73 1.80 5,905.19 MWD+IFR2+MS+sag(5) 11,500.65 91.61 314.11 6,411.21 6,355.01 6,308.33 1,388.56 6,037,410.47 471,337.88 1.01 5,982.91 MWD+IFR2+MS+sag(5) 11,595.80 92.16 315.42 6,408.08 6,351.88 6,375.30 1,321.04 6,037,477.70 471,270.64 1.49 6,060.33 MWD+IFR2+MS+sag(5) 11,692.96 89.82 317.05 6,406.40 6,350.20 6,445.45 1,253.85 6,037,548.11 471,203.74 2.93 6,140.82 MWD+IFR2+MS+sag(5) 12/14/2012 12:52:27PM Page 5 COMPASS 2003.16 Build 42 t Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB1 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°100') (ft) Survey Tool Name 11,787.10 89.75 316.37 6,406.75 6,350.55 6,513.97 1,189.30 6,037,616.89 471,139.47 0.73 6,219.27 MWD+IFR2+MS+sag(5) 11,885.85 90.06 316.41 6,406.92 6,350.72 6,585.47 1,121.19 6,037,688.66 471,071.66 0.32 6,301.25 MWD+IFR2+MS+sag(5) 11,982.48 93.52 314.68 6,403.90 6,347.70 6,654.40 1,053.56 6,037,757.85 471,004.32 4.00 6,380.62 MWD+IFR2+MS+sag(5) 12,078.69 93.09 316.94 6,398.35 6,342.15 6,723.27 986.61 6,037,826.98 470,937.66 2.39 6,459.81 MWD+IFR2+MS+sag(5) 12,175.48 92.28 316.73 6,393.82 6,337.62 6,793.79 920.47 6,037,897.76 470,871.81 0.86 6,540.49 MWD+IFR2+MS+sag(5) 12,270.85 92.59 315.57 6,389.76 6,333.56 6,862.50 854.46 6,037,966.73 470,806.08 1.26 6,619.37 MWD+IFR2+MS+sag(5) 12,367.53 92.59 314.85 6,385.40 6,329.20 6,931.04 786.42 6,038,035.54 470,738.33 0.74 6,698.43 MWD+IFR2+MS+sag(5) 12,464.00 92.59 314.85 6,381.04 6,324.84 6,999.01 718.10 6,038,103.78 470,670.29 0.00 6,776.97 PROJECTED to TD 12/14/1012 12:52:27PM Page 6 COMPASS 2003.16 Build 42 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-29 PN5 PB2 50-703-20661-00-71 Sperry Drilling _ Definitive Survey Report 14 December, 2012 1-IALLIBURTON Sperry Drilling Services Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB2 Database: EDM_Alaska Project Oooguruk Development Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well ODSN-29 Well Position +N/-S 0.00 ft Northing: 6,031,108.44 ft Latitude: 70°29'45.820 N +E/-W 0.00 ft Easting: 469,923.95 ft Longitude: 150°14'45.357 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSN-29 PN5 PB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF2010 10/10/2012 20.57 80.97 57,668 L- Design ODSN-29 PN5 PB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,885.85 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (bearing) 42.70 0.00 0.00 350.27 Survey Program Date 12/14/2012 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 100.00 729.00 ODSN-29 GYRO(ODSN-29 PN5 PB1) SRG-SS Surface readout gyro single shot 11/07/2012 775.48 4,138.70 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 4,139.70 7,238.00 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 7,238.00 9,759.10 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 9,759.10 11,885.85 ODSN-29 MWD(ODSN-29 PN5 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/08/2012 11,930.00 14,292.19 ODSN-29 PN5 MWD(ODSN-29 PN5 PB MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 11/20/2012 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (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 6,031,108.44 469,923.95 0.00 0.00 UNDEFINED 100.00 0.12 142.74 100.00 43.80 -0.05 0.04 6,031,108.39 469,923.99 0.21 -0.05 SRG-SS(1) 172.00 0.15 342.94 172.00 115.80 -0.02 0.05 6,031,108.42 469,924.00 0.37 -0.03 SRG-SS(1) 261.00 1.50 148.91 260.99 204.79 -0.90 0.62 6,031,107.53 469,924.57 1.85 -1.00 SRG-SS(1) 354.00 4.95 146.57 353.83 297.63 -5.30 3.46 6,031,103.13 469,927.39 3.71 -5.80 SRG-SS(1) 448.00 9.11 143.99 447.10 390.90 -14.70 10.07 6,031,093.70 469,933.96 4.44 -16.20 SRG-SS(1) 541.00 11.62 142.76 538.58 482.38 -28.12 20.07 6,031,080.24 469,943.91 2.71 -31.11 SRG-SS(1) 636.00 10.55 138.46 631.81 575.61 -42.25 31.63 6,031,066.07 469,955.41 1.42 -46.98 SRG-SS(1) 729.00 10.64 121.05 723.24 667.04 -53.05 44.63 6,031,055.22 469,968.36 3.43 -59.83 SRG-SS(1) 775.48 10.70 114.93 768.92 712.72 -57.08 52.22 6,031,051.15 469,975.94 2.44 -65.09 MWD+IFR2+MS+sag(2) 12/14/2012 1:08:21PM Page 2 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5©56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB2 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (11001 (ft) Survey Tool Name 871.35 10.29 106.10 863.19 806.99 -63.21 68.52 6,031,044.96 469,992.21 1.73 -73.88 MWD+IFR2+MS+sag(2) 967.21 8.57 109.64 957.76 901.56 -67.98 83.48 6,031,040.13 470,007.14 1.89 -81.11 MWD+IFR2+MS+sag(2) 1,057.98 8.88 89.26 1,047.50 991.30 -70.17 96.85 6,031,037.89 470,020.51 3.40 -85.53 MWD+IFR2+MS+sag(2) 1,156.87 8.63 82.17 1,145.24 1,089.04 -69.06 111.84 6,031,038.94 470,035.50 1.12 -86.96 MWD+IFR2+MS+sag(2) 1,252.66 9.64 75.68 1,239.81 1,183.61 -66.09 126.73 6,031,041.84 470,050.40 1.50 -86.56 MWD+IFR2+MS+sag(2) 1,344.56 11.97 66.08 1,330.09 1,273.89 -60.33 142.90 6,031,047.54 470,066.59 3.20 -83.61 MWD+IFR2+MS+sag(2) 1,443.83 14.03 61.93 1,426.81 1,370.61 -50.49 162.93 6,031,057.30 470,086.66 2.28 -77.30 MWD+IFR2+MS+sag(2) 1,538.72 16.10 60.74 1,518.43 1,462.23 -38.64 184.56 6,031,069.05 470,108.33 2.21 -69.28 MWD+IFR2+MS+sag(2) 1,630.58 18.58 58.48 1,606.11 1,549.91 -24.76 208.15 6,031,082.84 470,131.98 2.80 -59.59 MWD+IFR2+MS+sag(2) 1,726.05 20.24 53.90 1,696.16 1,639.96 -7.08 234.46 6,031,100.41 470,158.36 2.36 -46.60 MWD+IFR2+MS+sag(2) 1,823.57 23.59 50.42 1,786.62 1,730.42 15.30 263.14 6,031,122.67 470,187.13 3.68 -29.39 MWD+IFR2+MS+sag(2) 1,919.50 24.52 50.45 1,874.22 1,818.02 40.20 293.29 6,031,147.45 470,217.37 0.97 -9.94 MWD+IFR2+MS+sag(2) 2,012.11 26.18 49.20 1,957.91 1,901.71 65.79 323.57 6,031,172.92 470,247.75 1.88 10.16 MWD+IFR2+MS+sag(2) 2,108.98 29.74 46.35 2,043.46 1,987.26 96.35 357.14 6,031,203.34 470,281.45 3.92 34.61 MWD+IFR2+MS+sag(2) 2,203.85 30.55 43.54 2,125.51 2,069.31 130.07 390.78 6,031,236.92 470,315.22 1.71 62.16 MWD+IFR2+MS+sag(2) 2,300.31 30.90 43.41 2,208.43 2,152.23 165.84 424.69 6,031,272.54 470,349.27 0.37 91.68 MWD+IFR2+MS+sag(2) 2,394.61 30.17 41.08 2,289.65 2,233.45 201.29 456.90 6,031,307.86 470,381.62 1.47 121.18 MWD+IFR2+MS+sag(2) 2,485.66 32.87 41.15 2,367.26 2,311.06 237.15 488.20 6,031,343.59 470,413.06 2.97 151.23 MWD+IFR2+MS+sag(2) 2,582.97 34.96 40.94 2,448.01 2,391.81 278.10 523.85 6,031,384.39 470,448.87 2.15 185.56 MWD+IFR2+MS+sag(2) 2,676.49 35.93 37.95 2,524.20 2,468.00 319.98 558.29 6,031,426.12 470,483.47 2.12 221.02 MWD+IFR2+MS+sag(2) 2,772.74 37.48 37.32 2,601.37 2,545.17 365.54 593.41 6,031,471.54 470,518.77 1.66 259.99 MWD+IFR2+MS+sag(2) 2,866.80 38.36 38.20 2,675.57 2,619.37 411.23 628.81 6,031,517.08 470,554.35 1.10 299.05 MWD+IFR2+MS+sag(2) 2,962.28 39.48 38.14 2,749.85 2,693.65 458.39 665.88 6,031,564.09 470,591.61 1.17 339.26 MWD+IFR2+MS+sag(2) 3,056.78 42.54 37.76 2,821.15 2,764.95 507.29 704.00 6,031,612.82 470,629.93 3.25 381.01 MWD+IFR2+MS+sag(2) 3,152.51 44.40 38.36 2,890.62 2,834.42 559.14 744.61 6,031,664.50 470,670.74 1.99 425.25 MWD+IFR2+MS+sag(2) 3,244.56 45.78 38.50 2,955.61 2,899.41 610.20 785.13 6,031,715.40 470,711.46 1.50 468.73 MWD+IFR2+MS+sag(2) 3,339.91 44.52 38.40 3,022.85 2,966.65 663.14 827.16 6,031,768.16 470,753.70 1.32 513.81 MWD+IFR2+MS+sag(2) 3,437.78 44.79 38.83 3,092.47 3,036.27 716.89 870.09 6,031,821.73 470,796.84 0.41 559.52 MWD+IFR2+MS+sag(2) 3,531.82 46.35 36.87 3,158.31 3,102.11 769.92 911.28 6,031,874.59 470,838.24 2.23 604.83 MWD+IFR2+MS+sag(2) 3,628.46 46.31 36.78 3,225.04 3,168.84 825.87 953.18 6,031,930.36 470,880.36 0.08 652.90 MWD+IFR2+MS+sag(2) 3,721.08 49.15 38.54 3,287.33 3,231.13 880.10 995.06 6,031,984.42 470,922.46 3.37 699.27 MWD+IFR2+MS+sag(2) 3,815.98 52.06 38.95 3,347.55 3,291.35 937.29 1,040.96 6,032,041.42 470,968.59 3.08 747.88 MWD+IFR2+MS+sag(2) 3,913.69 53.35 38.96 3,406.76 3,350.56 997.74 1,089.83 6,032,101.66 471,017.70 1.32 799.20 MWD+IFR2+MS+sag(2) 4,007.06 52.27 39.23 3,463.20 3,407.00 1,055.47 1,136.73 6,032,159.19 471,064.83 1.18 848.17 MWD+IFR2+MS+sag(2) 4,093.51 53.19 39.45 3,515.55 3,459.35 1,108.67 1,180.34 6,032,212.22 471,108.65 1.08 893.24 MWD+IFR2+MS+sag(2) 4,193.35 50.77 38.33 3,577.04 3,520.84 1,169.88 1,229.73 6,032,273.22 471,158.28 2.58 945.22 MWD+IFR2+MS+sag(3) 4,235.17 50.22 38.20 3,603.64 3,547.44 1,195.21 1,249.71 6,032,298.47 471,178.36 1.34 966.81 MWD+IFR2+MS+sag(3) 4,329.62 50.67 36.91 3,663.79 3,607.59 1,252.94 1,294.10 6,032,356.01 471,222.97 1.16 1,016.21 MWD+IFR2+MS+sag(3) 4,424.83 50.66 37.77 3,724.14 3,667.94 1,311.49 1,338.76 6,032,414.37 471,267.87 0.70 1,066.37 MWD+IFR2+MS+sag(3) 4,520.03 51.23 38.51 3,784.12 3,727.92 1,369.63 1,384.42 6,032,472.32 471,313.76 0.85 1,115.96 MWD+IFR2+MS+sag(3) 12/14/2012 1:08:21PM Page 3 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB2 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,614.29 51.72 40.80 3,842.84 3,786.64 1,426.40 1,431.48 6,032,528.89 471,361.04 1.97 1,163.95 MWD+IFR2+MS+sag(3) 4,710.58 51.23 38.43 3,902.82 3,846.62 1,484.42 1,479.51 6,032,586.71 471,409.30 1.99 1,213.02 MWD+IFR2+MS+sag(3) 4,805.30 49.64 37.91 3,963.15 3,906.95 1,541.82 1,524.63 6,032,643.92 471,454.66 1.73 1,261.97 MWD+IFR2+MS+sag(3) 4,899.73 49.48 38.02 4,024.40 3,968.20 1,598.48 1,568.85 6,032,700.40 471,499.09 0.19 1,310.34 MWD+IFR2+MS+sag(3) 4,992.80 50.29 38.34 4,084.37 4,028.17 1,654.43 1,612.84 6,032,756.16 471,543.31 0.91 1,358.05 MWD+IFR2+MS+sag(3) 5,090.15 50.44 39.45 4,146.47 4,090.27 1,712.78 1,659.92 6,032,814.31 471,590.61 0.89 1,407.60 MWD+IFR2+MS+sag(3) 5,185.51 51.01 37.43 4,206.84 4,150.64 1,770.59 1,705.80 6,032,871.94 471,636.73 1.75 1,456.83 MWD+IFR2+MS+sag(3) 5,280.47 50.10 37.49 4,267.17 4,210.97 1,828.80 1,750.40 6,032,929.96 471,681.56 0.96 1,506.67 MWD+IFR2+MS+sag(3) 5,375.64 49.67 38.02 4,328.49 4,272.29 1,886.35 1,794.96 6,032,987.32 471,726.35 0.62 1,555.85 MWD+IFR2+MS+sag(3) 5,471.03 51.32 37.62 4,389.17 4,332.97 1,944.48 1,840.09 6,033,045.27 471,771.70 1.76 1,605.53 MWD+IFR2+MS+sag(3) 5,565.75 51.40 38.05 4,448.32 4,392.12 2,002.92 1,885.47 6,033,103.51 471,817.32 0.36 1,655.45 MWD+IFR2+MS+sag(3) 5,661.24 51.07 37.96 4,508.10 4,451.90 2,061.58 1,931.31 6,033,161.98 471,863.39 0.35 1,705.52 MWD+IFR2+MS+sag(3) 5,755.74 50.60 37.62 4,567.79 4,511.59 2,119.48 1,976.21 6,033,219.70 471,908.52 0.57 1,755.00 MWD+IFR2+MS+sag(3) 5,852.58 50.84 37.86 4,629.10 4,572.90 2,178.76 2,022.09 6,033,278.78 471,954.64 0.31 1,805.68 MWD+IFR2+MS+sag(3) 5,948.17 51.25 37.06 4,689.20 4,633.00 2,237.77 2,067.30 6,033,337.60 472,000.08 0.78 1,856.19 MWD+IFR2+MS+sag(3) 6,041.98 50.15 37.38 4,748.61 4,692.41 2,295.57 2,111.21 6,033,395.22 472,044.22 1.20 1,905.75 MWD+IFR2+MS+sag(3) 6,136.90 49.57 37.71 4,809.80 4,753.60 2,353.11 2,155.43 6,033,452.57 472,088.66 0.67 1,954.98 MWD+IFR2+MS+sag(3) 6,233.24 49.87 39.47 4,872.09 4,815.89 2,410.55 2,201.27 6,033,509.82 472,134.73 1.43 2,003.85 MWD+IFR2+MS+sag(3) 6,327.80 50.83 38.16 4,932.43 4,876.23 2,467.28 2,246.90 6,033,566.36 472,180.59 1.47 2,052.05 MWD+IFR2+MS+sag(3) 6,422.21 50.76 37.12 4,992.11 4,935.91 2,525.21 2,291.58 6,033,624.10 472,225.49 0.86 2,101.60 MWD+IFR2+MS+sag(3) 6,517.54 51.12 37.06 5,052.18 4,995.98 2,584.26 2,336.22 6,033,682.96 472,270.37 0.38 2,152.25 MWD+IFR2+MS+sag(3) 6,612.58 50.97 38.58 5,111.93 5,055.73 2,642.64 2,381.53 6,033,741.15 472,315.91 1.25 2,202.13 MWD+IFR2+MS+sag(3) 6,708.03 50.51 38.55 5,172.34 5,116.14 2,700.42 2,427.60 6,033,798.75 472,362.21 0.48 2,251.30 MWD+IFR2+MS+sag(3) 6,803.17 50.84 38.39 5,232.63 5,176.43 2,758.04 2,473.39 6,033,856.18 472,408.23 0.37 2,300.35 MWD+IFR2+MS+sag(3) 6,898.93 51.00 39.16 5,293.00 5,236.80 2,816.00 2,519.94 6,033,913.93 472,455.01 0.65 2,349.60 MWD+IFR2+MS+sag(3) 6,994.31 51.17 38.97 5,352.91 5,296.71 2,873.62 2,566.71 6,033,971.36 472,502.01 0.24 2,398.49 MWD+IFR2+MS+sag(3) 7,089.04 51.17 37.23 5,412.31 5,356.11 2,931.69 2,612.24 6,034,029.24 472,547.77 1.43 2,448.03 MWD+IFR2+MS+sag(3) 7,186.05 50.62 36.84 5,473.50 5,417.30 2,991.78 2,657.58 6,034,089.14 472,593.35 0.65 2,499.59 MWD+IFR2+MS+sag(3) 7,239.97 51.01 37.04 5,507.57 5,451.37 3,025.18 2,682.70 6,034,122.44 472,618.60 0.78 2,528.27 MWD+IFR2+MS+sag(4) 7,253.31 51.20 37.06 5,515.94 5,459.74 3,033.47 2,688.96 6,034,130.70 472,624.89 1.43 2,535.38 MWD+IFR2+MS+sag(4) 7,347.99 51.20 38.68 5,575.27 5,519.07 3,091.71 2,734.25 6,034,188.75 472,670.41 1.33 2,585.14 MWD+IFR2+MS+sag(4) 7,443.25 50.19 38.10 5,635.62 5,579.42 3,149.48 2,780.03 6,034,246.33 472,716.42 1.16 2,634.34 MWD+IFR2+MS+sag(4) 7,538.01 49.51 37.02 5,696.72 5,640.52 3,206.90 2,824.18 6,034,303.56 472,760.80 1.13 2,683.46 MWD+IFR2+MS+sag(4) 7,633.13 50.49 34.29 5,757.86 5,701.66 3,266.10 2,866.64 6,034,362.59 472,803.49 2.43 2,734.64 MWD+IFR2+MS+sag(4) 7,728.76 51.43 30.23 5,818.11 5,761.91 3,328.90 2,906.25 6,034,425.22 472,843.35 3.44 2,789.84 MWD+IFR2+MS+sag(4) 7,822.71 52.22 26.12 5,876.20 5,820.00 3,393.98 2,941.10 6,034,490.15 472,878.46 3.54 2,848.10 MWD+IFR2+MS+sag(4) 7,919.13 51.97 19.97 5,935.47 5,879.27 3,463.93 2,970.86 6,034,559.97 472,908.50 5.04 2,912.01 MWD+IFR2+MS+sag(4) 8,014.10 52.00 15.77 5,993.97 5,937.77 3,535.11 2,993.81 6,034,631.06 472,931.74 3.48 2,978.29 MWD+IFR2+MS+sag(4) 8,109.08 54.08 9.02 6,051.12 5,994.92 3,609.17 3,010.03 6,034,705.04 472,948.25 6.08 3,048.54 MWD+IFR2+MS+sag(4) 8,204.65 55.50 4.49 6,106.24 6,050.04 3,686.68 3,019.18 6,034,782.51 472,957.72 4.15 3,123.39 MWD+IFR2+MS+sag(4) 12/142012 1:08:21 PM Page 4 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB2 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,299.52 56.76 357.64 6,159.15 6,102.95 3,765.36 3,020.61 6,034,861.17 472,959.46 6.14 3,200.70 MWD+IFR2+MS+sag(4) 8,395.04 59.96 354.49 6,209.26 6,153.06 3,846.47 3,014.99 6,034,942.29 472,954.17 4.37 3,281.58 MWD+IFR2+MS+sag(4) 8,490.01 63.54 352.73 6,254.21 6,198.01 3,929.58 3,005.66 6,035,025.43 472,945.18 4.11 3,365.08 MWD+IFR2+MS+sag(4) 8,585.18 68.13 351.60 6,293.16 6,236.96 4,015.58 2,993.81 6,035,111.47 472,933.68 4.94 3,451.84 MWD+IFR2+MS+sag(4) 8,680.70 72.73 351.59 6,325.15 6,268.95 4,104.59 2,980.66 6,035,200.52 472,920.89 4.82 3,541.80 MWD+IFR2+MS+sag(4) 8,775.68 77.59 351.73 6,349.47 6,293.27 4,195.40 2,967.35 6,035,291.38 472,907.95 5.12 3,633.55 MWD+IFR2+MS+sag(4) 8,871.40 81.78 350.38 6,366.60 6,310.40 4,288.40 2,952.70 6,035,384.43 472,893.68 4.59 3,727.69 MWD+IFR2+MS+sag(4) 8,966.20 85.58 350.25 6,377.04 6,320.84 4,381.27 2,936.85 6,035,477.35 472,878.21 4.01 3,821.90 MWD+IFR2+MS+sag(4) 9,017.12 87.31 349.59 6,380.19 6,323.99 4,431.30 2,927.96 6,035,527.41 472,869.52 3.64 3,872.72 MWD+IFR2+MS+sag(4) 9,060.56 87.43 349.78 6,382.19 6,325.99 4,474.00 2,920.19 6,035,570.13 472,861.92 0.52 3,916.11 MWD+IFR2+MS+sag(4) 9,112.53 87.43 349.67 6,384.52 6,328.32 4,525.08 2,910.93 6,035,621.25 472,852.87 0.21 3,968.03 MWD+IFR2+MS+sag(4) 9,156.56 87.01 349.26 6,386.65 6,330.45 4,568.32 2,902.89 6,035,664.52 472,845.00 1.33 4,012.00 MWD+IFR2+MS+sag(4) 9,252.44 87.06 344.00 6,391.62 6,335.42 4,661.44 2,880.75 6,035,757.72 472,823.25 5.48 4,107.53 MWD+IFR2+MS+sag(4) 9,346.04 85.39 339.79 6,397.78 6,341.58 4,750.19 2,851.74 6,035,846.58 472,794.60 4.83 4,199.90 MWD+IFR2+MS+sag(4) 9,442.51 84.96 334.69 6,405.90 6,349.70 4,838.81 2,814.56 6,035,935.33 472,757.78 5.29 4,293.52 MWD+IFR2+MS+sag(4) 9,537.10 85.58 330.13 6,413.70 6,357.50 4,922.33 2,770.91 6,036,019.02 472,714.48 4.85 4,383.22 MWD+IFR2+MS+sag(4) 9,632.57 85.64 324.03 6,421.02 6,364.82 5,002.20 2,719.21 6,036,099.09 472,663.10 6.37 4,470.68 MWD+IFR2+MS+sag(4) 9,663.68 85.70 322.57 6,423.37 6,367.17 5,027.07 2,700.67 6,036,124.03 472,644.66 4.68 4,498.33 MWD+IFR2+MS+sag(4) 9,697.60 85.58 320.58 6,425.95 6,369.75 5,053.56 2,679.65 6,036,150.61 472,623.75 5.86 4,527.99 MWD+IFR2+MS+sag(4) 9,776.75 87.78 318.00 6,430.53 6,374.33 5,113.45 2,628.12 6,036,210.70 472,572.47 4.28 4,595.73 MWD+IFR2+MS+sag(5) 9,862.68 88.58 317.11 6,433.26 6,377.06 5,176.83 2,570.16 6,036,274.30 472,514.77 1.39 4,667.99 MWD+IFR2+MS+sag(5) 9,959.37 88.46 317.67 6,435.76 6,379.56 5,247.97 2,504.72 6,036,345.70 472,449.63 0.59 4,749.16 MWD+IFR2+MS+sag(5) 10,055.30 86.60 317.60 6,439.89 6,383.69 5,318.78 2,440.14 6,036,416.76 472,385.34 1.94 4,829.87 MWD+IFR2+MS+sag(5) 10,152.06 88.21 316.05 6,444.27 6,388.07 5,389.26 2,374.00 6,036,487.51 472,319.50 2.31 4,910.52 MWD+IFR2+MS+sag(5) 10,248.25 90.74 313.95 6,445.15 6,388.95 5,457.27 2,306.00 6,036,555.78 472,251.78 3.42 4,989.04 MWD+IFR2+MS+sag(5) 10,344.58 90.99 313.70 6,443.70 6,387.50 5,523.96 2,236.51 6,036,622.75 472,182.56 0.37 5,066.52 MWD+IFR2+MS+sag(5) 10,441.15 91.67 313.39 6,441.46 6,385.26 5,590.47 2,166.53 6,036,689.54 472,112.86 0.77 5,143.90 MWD+IFR2+MS+sag(5) 10,536.95 92.22 312.87 6,438.21 6,382.01 5,655.93 2,096.66 6,036,755.27 472,043.26 0.79 5,220.22 MWD+IFR2+MS+sag(5) 10,633.35 91.85 314.43 6,434.78 6,378.58 5,722.43 2,026.95 6,036,822.04 471,973.83 1.66 5,297.54 MWD+IFR2+MS+sag(5) 10,729.68 90.56 314.67 6,432.76 6,376.56 5,789.99 1,958.32 6,036,889.87 471,905.48 1.36 5,375.73 MWD+IFR2+MS+sag(5) 10,825.68 91.30 314.76 6,431.20 6,375.00 5,857.52 1,890.11 6,036,957.68 471,837.55 0.78 5,453.82 MWD+IFR2+MS+sag(5) 10,922.06 90.37 313.66 6,429.80 6,373.60 5,924.72 1,821.03 6,037,025.15 471,768.76 1.49 5,531.73 MWD+IFR2+MS+sag(5) 11,018.42 91.17 310.85 6,428.50 6,372.30 5,989.50 1,749.73 6,037,090.21 471,697.72 3.03 5,607.63 MWD+IFR2+MS+sag(5) 11,115.04 92.47 310.17 6,425.43 6,369.23 6,052.23 1,676.31 6,037,153.23 471,624.56 1.52 5,681.87 MWD+IFR2+MS+sag(5) 11,210.97 92.59 309.82 6,421.20 6,365.00 6,113.83 1,602.89 6,037,215.12 471,551.40 0.39 5,754.98 MWD+IFR2+MS+sag(5) 11,307.49 92.29 311.57 6,417.09 6,360.89 6,176.70 1,529.78 6,037,278.28 471,478.55 1.84 5,829.31 MWD+IFR2+MS+sag(5) 11,403.74 91.54 313.13 6,413.87 6,357.67 6,241.50 1,458.69 6,037,343.36 471,407.73 1.80 5,905.19 MWD+IFR2+MS+sag(5) 11,500.65 91.61 314.11 6,411.21 6,355.01 6,308.33 1,388.56 6,037,410.47 471,337.88 1.01 5,982.91 MWD+IFR2+MS+sag(5) 11,595.80 92.16 315.42 6,408.08 6,351.88 6,375.30 1,321.04 6,037,477.70 471,270.64 1.49 6,060.33 MWD+IFR2+MS+sag(5) 11,692.96 89.82 317.05 6,406.40 6,350.20 6,445.45 1,253.85 6,037,548.11 471,203.74 2.93 6,140.82 MWD+IFR2+MS+sag(5) 12/14/2012 1:08:21PM Page 5 COMPASS 2003.16 Build 42 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29 Project: Oooguruk Development TVD Reference: 42.7+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5' 56.20ft(Nabors 19AC) Well: ODSN-29 North Reference: True Wellbore: ODSN-29 PN5 PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-29 PN5 PB2 Database: EDM_Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,787.10 89.75 316.37 6,406.75 6,350.55 6,513.97 1,189.30 6,037,616.89 471,139.47 0.73 6,219.27 MWD+IFR2+MS+sag(5) 11,885.85 90.06 316.41 6,406.92 6,350.72 6,585.47 1,121.19 6,037,688.66 471,071.66 0.32 6,301.25 MWD+IFR2+MS+sag(5) 11,930.00 91.64 315.62 6,406.26 6,350.06 6,617.23 1,090.53 6,037,720.54 471,041.13 4.00 6,337.74 MWD+IFR2+MS+sag(6) 11,982.38 88.70 316.59 6,406.11 6,349.91 6,654.98 1,054.22 6,037,758.42 471,004.98 5.91 6,381.08 MWD+IFR2+MS+sag(6) 12,078.63 90.49 317.22 6,406.79 6,350.59 6,725.25 988.46 6,037,828.96 470,939.51 1.97 6,461.46 MWD+IFR2+MS+sag(6) 12,173.76 89.69 319.77 6,406.64 6,350.44 6,796.49 925.43 6,037,900.44 470,876.77 2.81 6,542.32 MWD+IFR2+MS+sag(6) 12,270.70 88.95 319.99 6,407.79 6,351.59 6,870.61 862.97 6,037,974.81 470,814.62 0.80 6,625.94 MWD+IFR2+MS+sag(6) 12,367.70 90.00 322.34 6,408.68 6,352.48 6,946.16 802.15 6,038,050.60 470,754.11 2.65 6,710.68 MWD+IFR2+MS+sag(6) 12,463.93 90.37 324.79 6,408.36 6,352.16 7,023.58 745.00 6,038,128.24 470,697.28 2.57 6,796.63 MWD+IFR2+MS+sag(6) 12,560.38 87.10 323.14 6,410.49 6,354.29 7,101.54 688.28 6,038,206.42 470,640.89 3.80 6,883.06 MWD+IFR2+MS+sag(6) 12,656.14 88.21 318.40 6,414.41 6,358.21 7,175.63 627.79 6,038,280.75 470,580.70 5.08 6,966.31 MWD+IFR2+MS+sag(6) 12,753.18 88.46 312.81 6,417.24 6,361.04 7,244.91 559.96 6,038,350.30 470,513.16 5.76 7,046.06 MWD+IFR2+MS+sag(6) 12,849.23 92.10 310.33 6,416.77 6,360.57 7,308.63 488.12 6,038,414.30 470,441.58 4.59 7,121.00 MWD+IFR2+MS+sag(6) 12,945.70 91.91 311.58 6,413.39 6,357.19 7,371.82 415.31 6,038,477.78 470,369.03 1.31 7,195.59 MWD+IFR2+MS+sag(6) 13,041.26 92.60 311.23 6,409.63 6,353.43 7,434.97 343.69 6,038,541.21 470,297.68 0.81 7,269.94 MWD+IFR2+MS+sag(6) 13,138.40 92.78 310.74 6,405.07 6,348.87 7,498.61 270.44 6,038,605.14 470,224.70 0.54 7,345.04 MWD+IFR2+MS+sag(6) 13,235.25 92.72 311.27 6,400.43 6,344.23 7,562.09 197.44 6,038,668.90 470,151.96 0.55 7,419.94 MWD+IFR2+MS+sag(6) 13,330.33 92.59 312.55 6,396.02 6,339.82 7,625.53 126.75 6,038,732.62 470,081.54 1.35 7,494.41 MWD+IFR2+MS+sag(6) 13,427.17 92.59 312.94 6,391.65 6,335.45 7,691.19 55.71 6,038,798.56 470,010.77 0.40 7,571.14 MWD+IFR2+MS+sag(6) 13,524.23 91.79 313.29 6,387.94 6,331.74 7,757.48 -15.09 6,038,865.13 469,940.25 0.90 7,648.44 MWD+IFR2+MS+sag(6) 13,619.99 87.90 314.93 6,388.20 6,332.00 7,824.11 -83.83 6,038,932.04 469,871.78 4.41 7,725.73 MWD+IFR2+MS+sag(6) 13,716.44 87.41 312.76 6,392.14 6,335.94 7,890.87 -153.33 6,038,999.06 469,802.56 2.30 7,803.27 MWD+IFR2+MS+sag(6) 13,813.17 87.04 312.38 6,396.83 6,340.63 7,956.23 -224.48 6,039,064.71 469,731.68 0.55 7,879.71 MWD+IFR2+MS+sag(6) 13,908.90 87.22 309.71 6,401.62 6,345.42 8,019.00 -296.58 6,039,127.77 469,659.84 2.79 7,953.77 MWD+IFR2+MS+sag(6) 14,004.48 84.75 311.13 6,408.31 6,352.11 8,080.81 -369.17 6,039,189.87 469,587.52 2.98 8,026.96 MWD+IFR2+MS+sag(6) 14,101.20 86.05 309.21 6,416.07 6,359.87 8,143.00 -442.83 6,039,252.34 469,514.11 2.39 8,100.70 MWD+IFR2+MS+sag(6) 14,196.40 88.21 304.63 6,420.84 6,364.64 8,200.09 -518.82 6,039,309.74 469,438.36 5.31 8,169.82 MWD+IFR2+MS+sag(6) 14,292.19 89.32 305.22 6,422.90 6,366.70 8,254.92 -597.34 6,039,364.87 469,360.07 1.31 8,237.13 MWD+IFR2+MS+sag(6) 14,464.00 89.32 305.22 6,424.94 6,368.74 8,354.00 -737.69 6,039,464.51 469,220.14 0.00 8,358.50 PROJECTED to TD 12/142012 1:08:21PM Page 6 COMPASS 2003.16 Build 42 de PIONEER NATURAL RESOURCES ALASKA Letter of Transmittal Date: December 11, 2012 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Howard Okland 700 G Street, Suite 600 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps ❑ Report X Other— Dry samples ❑ Agreement DETAIL QTY DESCRIPTION Well Name: ODSN-29 (50-703-20661-0000) ODSN-29 PB1 (50-703-20661-7000) 9 Boxes of Well Cuffing Samples ODSN-29 PB2 (50-703-20661-7100) T' i 3 7 V Details on next page We request that all data be treated as confidential information. Thank you. Received by: ADate: U.. D.., � 1,—2- Please Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 907-343-2193 fax 907-343-2128 phone viaH6C r i S c m u ai 0 a C -. c w w v Y2 0 �0 u °u 1 E C o 4, o {A `u o ` U ` H oc r o Z 9 Ev ,i, 1' YC Y W V W r m E m o G 9 U n 8 O 8 O E u 2 N o $ 4+ . a) a 3 8 0 Y O p1 G E N g I- n m o a 5 a L W 1 f 0) CM 01 01 01 Cr) 01 cn V 1 J N N N N N N N N N it Z Z Z Z Z Z Z Z Z W V1 V1 V1 V1 V1 V1 V1 V) V1 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 I- Z n 0 V l0 co l0 l0 N l0 u1 J M N M .--I N M r-1 a 2 Q V1 0 I N 3. 0 0 0 o D o n m W O N u1 N O m cr m r-I a C0 C I4 0 Ol r1 LE •- L l0 1 l0 —I p o 000 0 o v o v m r W N O N 01 N M O a 0 I,n N C1 C1 r� inr� N ci m r-, r-1 ui N r1 Z co 0 i , 00 0 00000 t t I- l0 u1 u1 O 0 r-I O N u1 C a r-I Q1 N r-I NN -1 r l co W C} u1 N Cl dl 3.--I ' E0 1 1 . . I 1 1 1 o a in00 0 X0000 o o In N 0 0 0 0 O v.-I 01 M 0 N 0 01 .-I N u1 N Ql Q1 N r-1' M u1 co %--i c-I 4 r-1 d O O O O Y O O O _ 3 O O T I-O f• - N. i Q1 ' ' .- 0 0 CD CD W CO CD CO LU O N NN N d C1 01 C1 C1 C1 01 01 C1 C1 M M M In +- w d O O O pp 2 O O O O O O O O O E f- I; f� N N 3.--I N M V V1 lO N CO 01 Z to in in O X w 0 QQQQ °° irTN IL Z I j t /'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 Alex Vaughan Senior Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-29 Pioneer Natural Resources Alaska, Inc. Permit No: 212-106 Surface Location: 2992' FSL, 1075' FEL, SEC. 11, T13N, R7E, UM Bottomhole Location: 2462' FSL, 3320' FEL, SEC. 35, T14N, 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, Cathy P. Foerster A49( Chair z DATED this J day of August, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED AL, \OIL AND GAS CONSERVATION COMM' )N PERMIT TO DRILL JUL 31 2012 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil ❑✓ Service- Winj ❑ Single Zone ❑ 1c.SpeciAtQGCCI for Drill Q Rednll ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply El Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp El Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11 Well Name and Number: Pioneer Natural Resources Alaska, Inc. Bond No. 103655283 • ODSN-29 • 3.Address: 700 G Street, Suite 600 6.Proposed Depth: 12.Field/Pool(s): Anchorage,AK 99501 MD: 16,754' • TVD: 6458' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Oooguruk-Nuiqsut Oil Pool, Surface: 2992' FSL, 1075'FEL,Sec. 11,T13N, R7E, UM • ADL 355036./ADL 389958 •_ Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2606'FSL,4069' FEL, Sec. 1,T13N, R7E, UM 417497 August 10,2012 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property' 2462'FSL,3320'FEL,Sec.35,T14N, R7E, UM 5760/2560 1960' 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-469923.95 • y-6031108.44 • Zone-ASP 4 GL Elevation above MSL: 13.5 feet , to Same Pool: ODSN-31 is 1246'away 16.Deviated wells. Kickoff depth: 293 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle: 90.75 degrees Downhole• 3291 • Surface: 2581 • 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 BTC-M& 3836' Surface Surface 3879' - 3369' . 473 sx PF'L';505 sx Class'G' HYD 521 11-3/4" 9-5/8" 40# L-80 HYD 521 3508' 3729' 3237' 7237' • 5511' - 200 sx Class'G' _ — BTC-M 8 8-1/2" 7" 26# L-80 9861' Surface Surface 9904' . 6405'C3,5A)sxClass'G' HYD 511 6-1/8" 4-1/2" 12.6# L-80 HYD 521 7000' 9754' 6402' 16,754'• 6458' . Uncemented 19 PRESENT WELL CONDITION SUMMARY(To be completed for Rednll and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat 2 BOP Sketch 0 Drilling Program 0 Time v Depth Plot 0 Shallow Hazard Analysis Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Alex Vaughan, 343-2186 Prepared By:Kathy Campoamor, 343-2183 Printed Name Alex Vaughan Title Senior Drilling Engineer /. Signature i/ Phone 343-2186 Date 7/31/2012 Commission Use Only Permit to Drill APt Number: Permit ApprQ /•� 1 See cover letter for other Number. 2."z 16‘, 50-7CS" Z�( /- -)-T7�' Date: �1� /lI �. requirements. Conditions of approval: If box is checked,well well may not be used to explore for,test,or produce coalbed me✓thane, as hydrates,or gas contained in shales: [' Other: f_„---0„ r5, j3Or -re..-5-t- Samples req'd: Yes❑ No[ Mud log req'd: Yes ❑ No [Vr iv 2 SOc� r ' Ar)n r � TS k C .,l H2S measures. Yes❑ No[' Directional svy req'd: Yes C7'No ❑ - lit✓e-r-�--r J J is., zg, AAc z.s. 0 3 5 Ch)(2) U OVED BY THE COMMISSION Q DATE: fJ^3 - (Z pi.--9„..e.„4,AaPP i-� COMMISSIONER g•Z•iZlbdeO lZ Form 10-401(Revised 7/2009) This permit is valid for tl jt e e a proval(20 AAC 25.005(g)) Submit in Duplicate T ,,,, 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 July 31st, 2012 RECEIVED JUL 31 2012 State of Alaska �± Alaska Oil and Gas Conservation Commission AOGCC 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Permit to Drill ODSN-29 Surface Location: 2992' FSL, 1075' FEL, Sec. 11, T13N, R7E, UM X = 469923.95, Y = 6031108.44, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill a development well from the Oooguruk Drill Site (ODS) located within the Oooguruk Unit. The well is designed to be a production well in the Oooguruk-Nuiqsut formation. PNRA requests the Permit To Drill based on approved Pool Rules. As indicated in the attachments, the drilling and well construction program includes the following: • Surface Hole: o Drill 14-1/2" to -3,879' MD / 3,369' 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 -7,237' MD / 5,511' TVD. Run and set a 9-5/8" drilling liner. • Intermediate Hole 2: o Drill 8-1/2" and under-ream while drilling (UWD) to 9-1/2" to -9,904' MD / 6,405' TVD and set 7" Intermediate casing into the top of the Oooguruk-Nuiqsut formation. • Lateral Hole: o Drill 6-3/4" horizontally to -16,754' MD / 6,458' TVD and set a 4-1/2" liner with a Baker MultiPoint mechanical diversion frac system. • Fracture Stimulation Completion: o 4-1/2" fracture stimulation string with SSSV & Sliding Sleeves. • Fracture Stimulation: o 2,000,000 lbs of Carboceramics Carbolite proppant pumped in 600,000 gallons of Schlumberger's YF125ST. • ESP Completion: o ESP completion string with SSSV & GLM. Alaska Oil & Gas Conserv,___.on Commission July 31st, 2012 Page 2 of 3 PNRA will implement Managed Pressure Drilling technology (MPD) while drilling both Intermediate sections and the Lateral hole section as outlined below. • Surface shoe to Intermediate 1 section TD. o Use -9.5-10.5 ppg fluid while using MPD to control pressure from the surface to -13.0 ppg EMW at the bottom of the hole during connections and while tripping. • Open formations: • Torok Sands, -8.65 ppg Pore Pressure • Intermediate 1 shoe to Intermediate 2 TD o Use -9.8-10.5 ppg fluid while using MPD to control pressure from the surface to -13.0 ppg EMW at the bottom of the hole. • Open formations: • Kuparuk Sands, -9.8 ppg Pore Pressure • Nuiqsut Sands, -9.8 ppg Pore Pressure • Intermediate 2 shoe to 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. • Open formations: • Nuiqsut Sands, -9.8 ppg Pore Pressure 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. A map showing location of the ODSN-29 Surface Casing Point relative to surrounding wells has been included. 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 Conserv, ..in Commission July 31st, 2012 Page 3of3 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 Alex Vaughan, Senior Drilling Engineer (20 AAC 25.070) 907.343.2186 alex.vaughan@pxd.com 2) Geologic Data and Logs Greg Griffin, Operations Geologist (20 AAC 25.071) 907.343.2141 greg.griffin@pxd.com The anticipated spud date for this well is August 10th, 2012. If you have any questions or require further information, please contact Alex Vaughan at 907.343.2186. Sincerely, Alex Vaughan Senior Drilling Engineer Attachments: Form 10-401 Supporting permit information cc: ODSN-29 Well File Permit to Drill Well Plan Summary ODSN-29 Oooguruk — Nuiqsut Single Lateral Production Well Surface TD @ 3,879' MD / 3,369' TVD Drilling Liner TD @ 7,237' MD / 5,511' TVD Intermediate TD @ 9,904' MD / 6,405' TVD Lateral TD @ 16,754' MD / 6,458' TVD Surface Location: 2992' FSL, 1075' FEL, Sec. 11, T13N, R7E, UM ASP 4 (NAD27) projection X = 469923.95 Y = 6031108.44 Target: Oooguruk-Nuiqsut 2606' FSL, 4069' FEL, Sec. 1, T13N, R7E, Umiat, (ADL355036) X= 472220.20 Y = 6035992.24 6,405' TVDrkb Bottom Hole Location 2462' FSL, 3320' FEL, Sec. 35, T14N, R7E, Umiat, (ADL389958) X = 467710.94 Y = 6041145.84 6,458' TVDrkb AFE Number: TBA Est. Start Date: August 10th, 2012 Rig: Nabors 19AC Operating days: 45 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) Single-Lateral Current Mechanical Condition: Well Bay Footing /ODS Ground Level: Elevation above MSL: 13.5' RKB to Ground Level: 42.66' Rig Elevation: RKB + MSL = 56.16' Conductor: 158' MDrkb Pioneer Natural Resources Last Revised:July 31St, 2012 ODSN-29 Permit To Drill Page 1 of 13 Well Control: Well Section Pressure Depth psi TVD Basis 14-1/2" Surface Section Maximum anticipated BHP 1507 3369 Based on seawater gradient of 0.4472 psi/f Maximum surface pressure (Based on BHP and a full column of gas 1136 Surface from TD @ 0.11 psi/ft) 10-5/8" x 11-3/4" Drilling Liner Hole Section Maximum anticipated BHP (Based on seawater gradient of 0.4472 2465 5511 psi/ft) Maximum surface pressure 1858 Surface Based on BHP and a full column of gas from TD @ 0.11 psi/ft) 8-1/2" x 9-1/2" Intermediate Casing Hole Section Maximum anticipated BHP 3264 6405 Based on 9.8 ppg Oooguruk-Kuparuk pore pressure) Maximum surface pressure 2559 Surface Based on BHP and a full column of gas from TD @ 0.11 psi/ft) 6-1/8" Lateral Hole Section Maximum anticipated BHP 3291 6458 Based on 9.8 ppg Oooguruk-Nuiqsut pore . pressure) Maximum surface pressure 2581 Surface Based on BHP and a full column of gas from TD @ 0.11 psi/ft) Maximum casing pressure: 3500 psi @ surface Planned BOP test pressure: 4500 psi (annular to 2500 psi) Due to required 4500 psi casing pressure test. Planned completion fluid: 10.2 ppg Brine/6.8 ppg Diesel Diverter(see attached schematic)— Note: Requesting Diverter Exemption on a Well by Well Basis): Hydril 21-1/4" 2M annular BOP 1 16"full opening knife gate valve, hydraulically actuated 16" diverter line 5000 psi BOP stack(see attached schematic): Hydril GK 11" 5M annular BOP Hydril 11" 5M single ram BOP w/studded connections Hydril 11" 5M single ram BOP w/studded connections Drilling cross 11" 5M x 11" 5M with 2 ea. 3-1/8" 5M side outlets w/flanged connections 2 ea. 3-1/8" 5M full opening inner manual gate valves mounted on drilling cross 2 ea. 3-1/8" 5M full opening outer remote hydraulic controlled gate valves mounted on inner gate valves. Hydril 11" 5M single ram BOP w/studded connections Pioneer Natural Resources Last Revised:July 31St, 2012 ODSN-29 Permit To Drill Page 2 of 13 Formation Integrity Testing Requirements: Test Point i Depth Test Type Minimum EMW 11-3/4" Surface Shoe Rathole + 20' to 50' from shoe LOT 12.5 ppg _ x- 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 MOBM Interval Density (ppg) Viscosity (secs) YP PV HTHP 0/W Initial to TD 9.5 - 10.5 ppg 55 -80 12 -25 15 - 30 800-2000 <4 (-13.0 ppg via MPD) Intermediate Hole Mud Properties: 8-1/2" x 9-1/2" hole LSND Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial to TD 9.8 - 10.5 ppg - 50-70 15 -25 15 -25 < 10 3-5 (-13.0 ppg via (8-10 MPD) HTHP) Lateral Hole Mud Properties: 6-1/8" hole MOBM Interval Density (ppg) Viscosity (secs) YP PV HTHP - O/W Initial to TD 7.2 - 8.2 ppg - 55 - 80 12 -25 10 -20 <6 94/6 (-9.8 -10.2 ppg via MPD) fA s't) Pioneer Natural Resources Last Revised:July 31st, 2012 ODSN-29 Permit To Drill Page 3 of 13 Formation Markers: Formation Tops MD (ft) TVDrkb (ft) Pore Press. EMW Comments (psi) (PPM Base of Permafrost 1685 1656 Top West Sak 2431 2327 1047 8.65 Base of fluvial sands Tuffaceous Shales 3302 2997 Hue2 tuff 3871 3364 11-3/4" casing point 3879 3369 Brook 2B 5411 4347 Top Torok Sand 6597 5104 2296 8.65 Base Torok Sand 7046 5391 Torok Shale 1 7229 5506 9-5/8" casing point 7237 5511 Top HRZ 7842 5865 Base HRZ (Top Kalubik Sh) 8092 5993 Kalubik Mkr 8271 6075 Top Kuparuk C 8406 6131 3124 9.8 LCU (Top Miluveach Sh) 8451 6149 BCU (Top Kingak Sh) 9168 6346 Top Nuiqsut 9680 6398 3260 9.8 Production Zone Nuiqsut 1 9760 6402 7" casing point 9904 6405 3264 9.8 ODSN-29 TD 16754 - 6458 3291 9.8 Pioneer Natural Resources Last Revised:July 31St, 2012 ODSN-29 Permit To Drill Page 4 of 13 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: Mud Logging Dir/GR/Res Open Hole: N/A Cased Hole: N/A 8-1/2" Section: Drilling: Mud Logging Dir/GR/ Res/AzDens/ Neut Open Hole: N/A Cased Hole: 6-1/8" Section: Drilling: Mud logging Dir/GR/ Res/AzDens/ Neut / PWD Open Hole: N/A Cased Hole: N/A Pioneer Natural Resources Last Revised:July 31St, 2012 ODSN-29 Permit To Drill Page 5 of 13 Casing Program: Hole Casing/ Weight Grade Conn. Casing Csg/Tbg Hole Btm Size Tubing Length TOP MDrkb/TVDrkb MDrkb 24" 16" 109# H-40 Welded 115 Surface 158 158 14-1/2" 11-3/4" 60# L-80 BTC-M & 3836 Surface 3879 3369 Hydril 521 11-3/4" 9-5/8" 40# L-80 Hydril 521 3508 3729 7237 5511 8-1/2" 7" 26# L-80 BTC-M & 9861 Surface 9904 6405 Hydril 511 6-1/8" 4-1/2" 12.6# L-80 Hydril 521 7000 9754 16754 6458 Tubing 4-1/2" 12.6# L-80 Hydril 521 9657 Surface 9700 6399 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 v Hydril 511 7240 5410 604 M 604 M 7" 26# L-80 6.276" 6.151 v 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:July 31st, 2012 ODSN-29 Permit To Drill Page 6 of 13 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: 2,807' MD-500' MD above 3000' TVD Total Cement Volume: Preflush 10 bbl water Spacer 100 bbl 10.0 ppg Tuned Spacer Lead 351 bbls./473 sx of 10.92 ppg Type "L" Permafrost Cement. 4.51 cf/sJsr 20.0 gps water req. Tail T07 bbls/ 50.sx of 15.9 ppg Premium "G" + adds. (..19 cf/sk 5.23 gps water req. Displ 416 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 •L. Ken' i�' Basis: TOC: 6,737' MD-500' MD above casing point 60% excess, plus 85' shoe track Total Cement Volume: Preflush 10 bbl water Spacer 60 bbl 10 ppg.Dual Spacer Primary 42 bbls/ 00 Premium "G" + adds. 1.17 cf/sk Displ 326 bbls mud Temp BHST - 135° F, BHCT-110° F Casing Size: 7" Intermediate 2-single stage Basis: TOC: -7, 905'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 _ 115 bbls(554 sx Premium "G" + adds. .17 cf/s Displ 376 bbls mud Temp BHST- 165° F, BHCT-135° F This well is outside the 1/2 mile radius around ODSN-DW1 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:July 31st, 2012 ODSN-29 Permit To Drill Page 7 of 13 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. Z ..v3 (kx z� "14•1(2. Nipple up spacer spools and riser. I��u"' " L"` " ' etAi_ ` A.�� 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 hours in advance of test. 7. MU 10-5/8" x 11-3/4" RSS, MWD/LWD RUMPD trip nipple. 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. RD MPD trip nipple and RU bearing assembly. 11. Drill 10-5/8" x 11-3/4" Intermediate 1 to casing point. 12. Change one set of pipe rams to 9-5/8" and test BOPE as required. ;., 13. Run 9-5/8" drilling liner on 5" DP. Set liner hanger, release from liner and cement. 14. Bump the plug, increase pressure to 3500 psi and hold pressure for 5 minutes • This will provide a quick integrity test of the 9-5/8" liner • Note the pressure test in the morning report 15. 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 16. 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 17. POOH w/5" DP. 18. ND BOPE, ND Drilling spool, NU Mulitbowt Wellhead, & NU BOPE and test to 250/4500 psi - Notify AOGCC 48 hours in advance of test. • Ensure integrity of the liner and the liner top has been verified by a pressure . test prior to performing this step 19. MU 8-1/2" x 9-1/2" RSS, MWD/LWD on 5" DP. RU MPD trip nipple. X- 20. 20. RIH and cleanout casing to landing collar. 21. 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. 22. Drill through drilling liner shoe + 20' of new hole and perform FIT to 13.5 ppg, 23. RD MPD trip nipple and RU bearing assembly. 24. Drill 8-1/2" Intermediate 2 to casing point. Pioneer Natural Resources Last Revised: July 31st, 2012 ODSN-29 Permit To Drill Page 8 of 13 25. Circulate and condition the well to run 7" intermediate casing. Displace the well over to -12.0 ppg mud for shale stability. RD the MPD bearing assembly and RU MPD trip nipple. POOH. 26. 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 7" tieback string to surface depending on drilling conditions. Both options have been provided below: Option #1: 7" Longstrinq 27. Run and cement the 7"26#L-80 BTC-M intermediate casing. 28. Bump the plug and bring the pressure up to 3500 psi-hold for 5 minute pressure test. Release pressure and ensure floats are holding. 29. LD 5"DP Option #2: 7" Liner with Tie-Back Option 30. 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. 31. 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. 32. 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 4-;L- �f4« • 7"liner and the 9-5/8"drilling liner. • Note the pressure test of the liner top in the morning report 33. Run 7", 26#L-80 BTC intermediate tie-back to 7"liner-hanger seal bore and space out. 34. Displace diesel freeze protection down 7"annulus to 2,000'tvd with annular preventer closed. 35. Strip through annular preventer and sting into 7"liner-hanger seal bore and land tie-back casing. 36. Pressure test seal assembly to 3500 psi-hold&chart for 30 minutes. 37. Pressure test 7"tie back annulus 3500 psi-hold and chart for 30 minutes. \ 38. Set and test 7"pack-off. 39. RU MPD trip nipple & PU 4" DP as needed to TD the lateral hole section. 40. RIH to landing collar and w/4" DP & mill tooth cleanout bit. 41. Change pipe rams to 4" and test BOPE to 250/4500 psi- Notify AOGCC 48 hours in advance of test. 42. Pressure test casing to 3500 psi -chart and hold for 30 minute pressure test unless previously done in Option #2. Send chart to ODE. 43. Drill through Intermediate 2 shoe and POOH w/cleanout assembly. 44. MU 6-1/8" RSS, MWD/LWD drilling assembly on 4" DP and RIH. 45. RD MPD trip nipple and RU bearing assembly. 46. Displace to drill-in-fluid for lateral hole. 47. Drill rathole + 20' of new hole and perform FIT to 12.5 ppg. f I r 48. Drill 6-1/8" lateral lateral hole to TD. Pioneer Natural Resources Last Revised:July 31st, 2012 ODSN-29 Permit To Drill Page 9 of 13 49. Circulate and condition hole to run liner. 50. POH to intermediate shoe and set heavy weight balance brine pill. 51. RD MPD bearing assembly and RU MPD trip nipple. Cont POH to surface. 52. Change one set of pipe rams to 4-1/2" and test BOPE as required. 53. RIH w/4-1/2" production liner w/ Baker MultiPoint frac system from 150' inside the intermediate shoe to TD. 54. Release from the liner and set the liner top packer. Displace the well over to completion brine and POOH. 55. Run 4-1/2" fracture stimulation string to top of 4-1/2" liner seal bore. 56. Reverse circulate corrosion inhibited brine or diesel to freeze protect the well to -2000' TVD. 57. Sting 4-1/2" fracture stimulation string into the 4-1/2" liner seal bore. 58. Pressure test 7-5/8" x 4-1/2" annulus to 3500 psi -chart and hold for 30 minute pressure. Send chart to ODE. QtniS rtr,----Le• --go 6f-4, Pioneer Natural Resources Last Revised:July 31St, 2012 ODSN-29 Permit To Drill Page 10 of 13 PNRA will submit a sundry prior to executing the following program Post Riq Operation: Fracture Stimulation - 1. Fracture stimulate well 2,000,000 lbs of 20/40 Carboceramics Carbolite proppant pumped in 600,000 gallons of Schlumberger's YF125ST. The fluid volume includes a pad stage yet to be determined. The stimulation will target the Torok reservoir in a 9 stage treatment using the Baker MultiPoint mechanical diversion system. The expected surface treating pressure at a planned pump rate of 50 barrels per minute is 7000 psi. Maximum proppant concentration is 10 ppa per gallon. The Schlumberger YF125ST is a water based guar gel system with borate crosslinker. br‘ , The chemical make-up of the YF125ST includes: —983.75gpt 5 Seawaterbase Clay Stabilizer—2 gpt vi Polymer—6.25 gpt Surfactant—2 gpt Crosslinker—6 gpt Oxidative Breaker—0.05 ppt 2. Remove SSSV sleeve and install wireline retrievable SSSV 3. Install live gaslift valves 4. Flowback well with gaslift. 5. RDMO well. Riq Activity: ESP Completion 1. Rig up over well. 2. Install BPV and nipple down tree. 3. Pull 4 1/2" fracture stimulation string. 4. RIH w/ ESP completion w/ Packer&Tubing Retrievable ScSSSV. 5. Space out and land tubing hanger. 6. RILDS and test both the upper and lower tubing hanger body seals to 5000psi. 7. Set BPV, ND BOPE, NU Production Tree 8. Replace BPV w/TWC & Test Production Tree void to 5000psi & recover TWC 9. Reverse circulate corrosion inhibited brine or diesel to freeze protect the well to —2000' TVD 10. Set packer and test annulus to 3500 psi for 30 min. Post Riq Operations: 1. Rig up slickline 2. Retrieve ball/rod assembly from the RHC-M plug body 3. Pull dummy valve from lower GLM, set %" OV in same. 4. Retrieve RHCM plug body 5. Rig down slickline Pioneer Natural Resources Last Revised:July 31st, 2012 ODSN-29 Permit To Drill Page 11 of 13 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 %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: July 31st, 2012 ODSN-29 Permit To Drill Page 12 of 13 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • Prior to drilling into the Kuparuk, hold a pre-reservoir meeting to outline heightened - awareness for kick detection and lost circulation. o Following the Kuparuk penetration, pick up off bottom, shut off the pumps and perform a flow check to verify there isn't any overpressure. Hydrates and Shallow gas • No hydrates are expected in this area. - Lost Circulation/Breathing/Formation Stability/Stuck Pipe Events • Breathing may be seen while drilling the Hue shale. Minimizing swab and surge on the formation is critical to reducing the impact of breathing in the wellbore. Breathing was seen in the ODSN-40 well, but only after substantial time in trying to solve the lost circulation problems in the fault seen in and below the Torok Sands. • Lost Circulation was seen in drilling the ODSN-36 across this same interval. Review the DOB2C pill procedure prior to penetrating the Kuparuk. Follow the Lost Circulation Decision Tree and combat losses accordingly • During the attempt to retrieve a fish from the ODSK-33 well, an un-centralized BHA got stuck from differential sticking across the Torok due to the increase in mud weight needed to hold back the shales below. Differential sticking indications were not noted with the drilling BHA and drill pipe. • There is a small section of formation above the Top of the HRZ that is volcanic in nature (TUFFS) and can either have "glassy" material, swelling clays or both while drilling, which produced a pack off on ODSK-33 and ODSN-45. Kick Tolerance/Integrity Testing Kick Tolerance/ Integrity Testing Summary Table Casing set/ Maximum Mud Weight Exp Pore Min LOT/ FIT Interval Influx Volume Press 11-3/4" Surface/ 532 bbls 9.5 10.5 ppg 2465 12.5 ppg (LOT) 10-5/8" x 11-3/4" (-13.0 ppg via MPD) 9-5/8" Drilling Liner/ Infinite 9.8-10.5 ppg 3264 13.5 ppg (FIT), 8-1/2" x 9-1/2" (13.0 EMW w/MPD) 7" Intermediate/ Infinite 7.2-8.2 ppg 3291 12.5 ppg (FIT) 6-1/8" (9.8-10.2 EMW w/MPD) NOTE: All LOT/ FIT will be taken with a minimum of 20-ft and a maximum of 50-ft of new hole drilled outside of the previous casing string Hydrogen Sulfide • The Oooguruk Drill Site is not designated as an H2S site, however Standard Operating . Procedures for H2S precautions should be followed at all times. Faults • A seismic fault with an expected throw of 15-40' may be encountered around 7,800' MD. Losses may be associated with this fault. • Consult the ODS data sheet for additional information (still in development) Pioneer Natural Resources Last Revised:July 31st, 2012 ODSN-29 Permit To Drill Page 13 of 13 ODSN-29 Nuiqsut Pr 'uction Well Completior Proposed Updated 7/30/2012 i Upper Completion l 1)Tubing Hanger 1 , 16"Conductor 2)4-'/z'12.6#/ft Hydril 521 Tubing(2 jts), 3)4-Y2'12.6#/ft Hydril 521 Tubing 4)4-1/2'Halliburton'XXO'SVLN 9CR w/3.813""X"profile RTS-8 Pacer Fluid mix: with single1/4"x 0.049"s/s control line. Inhib ted Kill weight Cannon Cross-coupling clamps on every joint is Brine 5)4-'/3'12.6#/ft Hydril 521 Tubing 4inwith 2000'TVD 6)4-1/2"x 1"GLM,KBG-2 Hydril 521 w/DCK2 ' '' 7)4-',4 12.6#/ft Hydril 521 Tubing 1 / l diesel cap 8)4-1/ x 1"GLM,KBG-2 Hydril 521 w/DV lin 9)4-'/2'12.6#/ft Hydril 521 Tubing 1.111111 10)4'/z'x 1"GLM,KBG-2 Hydril 521 w/DV 11)4-'A 12.6#/ft Hydril 521 Tubing 12)HES XN 3.813"(3.725"NoGo)-with RHC Plug Set at 68 deg 11-3/4" 60# L-80 13)4-'/z"12.6#/ft Hydril 521 Tubing Hydril 521 & BTC-M 14)4-1/2"Halliburton'ROC'Gauge Carrier w/1/4"x 0.049"s/s control line 15)4-1A"12.6#/ft Hydril 521 Tubing GL Surface Casing 16)Bullet Seal assembly w/Weatherford Ratcheting Mule Shoe @ 3879' MD /3369' TVD cemented to surface i ... GL ithilli I I li 9-5/8" 40# L-80 Hydril 521 Intermediate 1 Casing @ 7237' MD/ 5511' TVD Cemented 500' above shoe 4-1/2" 12.6 ppf P-110 Hydril 521 10 GL ' Tubing 12 ) XNI i 11111 r___ mill 0 TOC Estimated 500'above top of Kuparuk Tiliii0 0 €.1. 'o z1 ., ,‘ ® 4O39C 51 59 67 75 g3 7" 26# L-80 b- ® 2 - - - 2 2 - 2 - - -- :- - 2 2 - 2 2 - -1j1 j 2 BTC-M & Hydril 511 Intermediate 2 Casing @ 9904' MD/6405' TVD - s' 4-W Hydril 521 Liner with Baker Hughes Multi-Point Frac Sleeves (3 per stage) isolated with ECP's 6-1/8" Hole TD @ 16754' MD/6458 - TVD ODSN-29 Nuiqsut Pr luction Well Completio Proposed Updated 7/30/2012 I al Lower Completion iissiiiiii. 16" Conductor 17)Baker 5-W X 7 ZXP Liner Top Packer with Tie Back I extension and Flex Lock Hanger i • •••• 18)4-W12.6#/ft Hydril 521 Liner ariiii Packer Fluid mix: 19)Baker ECP Packer(4-Y2'Hydril 521) Inhibited Kill weight 20)41,4 12.6#/ft Hydril 521 Liner I •ilii"" Brine 21)Baker Multi-Point Frac Sleeve with segmented bat seat(3.000 ball/2.948 Seat) 4 with 2000'TVD 22)4-W 12.6#/ft Hydril 521 Liner ,; ""' 23)Baker Multi-Point Frac Sleeve with segmented bat seat(3.000 ball/2.948 Seat) iiiiiiii 1 .J I / diesel cap 24)4-W 12.6#/ft Hydril 521 Liner I 25)Baker Multi-Point Frac Sleeve with solid ball seat(3.000 ball/2.948 Seat) "' ' 26)4-W 12.6#/ft Hydril 521 Liner 27)Baker ECP Packer(4-'/z"Hydril 521) ilk 11-3/4" 60# L-80 28)4-%"12.6#/ft Hydril 521 Liner Hydril 521 & BTC-M 29)Baker Multi-Point Frac Sleeve with segmented ball seat(2.938 ball/2.885 Seat) Surface Casing 30)4'i"12.6#/ft Hydril 521 Liner 31)Baker Multi-Point Frac Sleeve with segmented ball seat(2.938 ball/2.885 Seat) 0 GLI © 3879' MD/ 3369' TVD 32)a 14"12.6#/ft Hydril 521 Liner cemented to surface 33)Baker Multi-Point Frac Sleeve with solid ball seat(2.938 ball/2.885 Seat) 34)4-Y2"12.6#/ft Hydril 521 Liner 35)Baker ECP Packer(4-'/2"Hydril 521) I 36)4-Y2"12.6#/ft Hydril 521 Liner -i 37)Baker Multi-Point Frac Sleeve with segmented ball seat(2.875 ball/2.823 Seat) O GL qi 38)4-Y2"12.6#/ft Hydril 521 Liner 0 .. 39)Baker Multi-Point Frac Sleeve with segmented ball seat(2.875 ball/2.823 Seat) € 40)4-'/z'12.6#/ft Hydril 521 Liner MI 9 5/8" 40# L-80 Hydril 521 41)Baker Multi-Point Frac Sleeve with solid ball seat(2.875 ball/2.823 Seat) Intermediate 1 Casing 42)4-Y2"12.6#/ft Hydril 521 Liner 43)Baker ECP Packer(4-%'Hydril 521) @ 7237' MD/5511' TVD 44)4-W 12.6#/ft Hydril 521 Liner Cemented 500' above shoe 45)Baker Multi-Point Frac Sleeve with segmented ball seat(2.813 ball/2.760 Seat) 46)4-Y2"12.6#/ft Hydril 521 Liner 47)Baker Multi-Point Frac Sleeve with segmented ball seat(2.813 ball/2.760 Seat) 48)4-'14"12.6#/ft Hydril 521 Liner 49)Baker Multi-Point Frac Sleeve with solid ball seat(2.813 ball/2.760 Seat) 50)4-%"12.6#/ft Hydril 521 Liner I 4-1/2" 12.6 ppf 51)Baker ECP Packer(4-'/"Hydril 521) P-110 Hydril 52)4'/"12.6#/ft Hydril 521 Liner 53)Baker Multi-Point Frac Sleeve with segmented ball seat(2.750 ball/2.698 Seat) 10 GL /z 521 54)4' '12.6#/ft Hydril 521 Liner Tubing 55)Baker Multi-Point Frac Sleeve with segmented ball seat(2.750 ball/2.698 Seat) 56)4-'/z'12.6#/ft Hydril 521 Liner XN I 111111 I 57)Baker Multi-Point Frac Sleeve with solid ball seat(2.750 ball/2.698 Seat) — TOC Estimated 500' above top of Kuparuk 0 0 0 ®' 35 43 51 59 67 75 0 7" 26# L-80 , ®,4 ,® 39 BTC-M & Hydril 511 0-,,, , - _ _ _ _ - _ - _ _ H - _ _ _Intermediate 2 Casing - - - - - - - - �- - - - - �- - - - - - - 9904' MD/6405' TVD - C)-- 4-Y2" Hydril 521 Liner with Baker Hughes Multi-Point Frac 6-1/8" Hole TD Sleeves (3 per stage) isolated with ECP's @ 16754' MD/6458' TVD ODSN-29 Nuiqsut PruJuction Well Completion - Proposed Updated 7/30/2012 I Iiiiiiii Lower Completion , ii I 16"Conductor 58)4'/z'12.6#/ft Hydril 521 Liner 59)Baker ECP Packer(4-'A Hydril 521) Packer luid mix: 60)4-W12.6#/ft Hydril 521 Liner 61)Baker Multi-Point Frac Sleeve with segmented ball seat(2.688 ball/2.635 Seat) I � Inhibited ill weight 62)4-V 12.6#/ft Hydril 521 Liner 1 " Brine 63)Baker Multi-Point Frac Sleeve with segmented ball seat(2.688 ball/2.635 Seat) 4 Iiii€ with 2000'TVD 64)4-'/ 12.6#/ft Hydril 521 Liner diesel cap 65)Baker Multi-Point Frac Sleeve with solid ball seat(2.688 ball/2.635 Seat) liiiiiii 1 ;4!"tifili I / liiiiiii 66)4-'A 12.6#/ft Hydril 521 Liner 1 67)Baker ECP Packer(4-'A Hydril 521) 00111 i iiigii68)4-'A 12.6#/ft Hydril 521 Liner 69)Baker Multi-Point Frac Sleeve with segmented ball seat(2.625 ball/2.573 Seat) I 11-3/4"60# L-80 70)4-'i2'12.6#/ft Hydril 521 Liner Hydril 521 & BTC-M 71)Baker Multi-Point Frac Sleeve with segmented ball seat(2.625 ball/2.573 Seat) 72)4-'/2"12.6#/ft Hydril 521 Liner Surface Casing 73)Baker Multi-Point Frac Sleeve with solid ball seat(2.625 ball/2.573 Seat) O GL .11 @ 3879' MD/3369' TVD 74)4-'/2'12.6#/ft Hydril 521 Liner I cemented to surface 75)Baker ECP Packer(4-'/2'Hydril 521) 76)4'/2'12.6#/ft Hydril 521 Liner 771 Tri,i- 77)Baker Multi-Point Frac Sleeve with segmented ball seat(2.563 ball/2.510 Seat) I iiiii 78)4-V2"12.6#/ft Hydril 521 Liner 79)Baker Multi-Point Frac Sleeve with segmented ball seat(2.563 ball/2.510 Seat) GL .J 80)4-'/2"12.6#/ft Hydril 521 Liner 1'.�/ 81)Baker Multi-Point Frac Sleeve with solid ball seat(2.563 ball/2.510 Seat) I iiiii 82)4-V2"12.6#/ft Hydril 521 Liner 1 . 9-5/8"40# L-80 Hydril 521 83)Baker ECP Packer(4-'A"Hydril 521) I Intermediate 1 Casing 84)4-"1/2"12.6#/ft Hydril 521 Liner 85)Pressure Activated Sleeve"B"5,800 psi I @ 7237' MD / 5511' TVD 86)4-'/2"12.6#/ft Hydril 521 Liner I Cemented 500' above shoe 87)Pressure Activated Sleeve"A"5,800 psi 88)4-''A"12.6#/ft Hydril 521 Liner I 89)Wellbore Isolation Valve"WIV' I 90)4-'/4"12.6#/ft Hydril 521 Liner 91)Baker 5-3/1"EZ Ream Shoe I I 4-1/2" 12.6 ppf 1 P-110 Hydril 0. GL J 521 10 I 'ii Tubing iii 0 . iiiiii iiiii ___ TOC Estimated €is 500'above top of Kuparuk 1i:.� :. :. '4. ..,„„„,: .,,,„„„..,... . \ Ilo z, ® 35 43 51 59 67 75 63 7" 26# L-80 ®,®, 3s BTC M & Hydril 511 z3 :_ _ r III Intermediate 2 Casing --- @ 9904' MD/6405' TVD - II CD 4-W Hydril 521 Liner with Baker Hughes Multi-Point Frac 6-1/8" Hole TD Sleeves (3 per stage) isolated with ECP's @ 16754' MD 16458' . TVD The following map shows the planned ODSN-29 surface casing point surrounded by a multitude of - existing wells. Surface Casing Points rJili Hue 2 Surface Casing Points LiSurface Casing Points ,*N25 *11261 .NO1PR1 "1,1127i 2750' O 182 p, 1tic J29_PN5_wp02 401(11 PR? N s .u1 1 O s Nit N18111 010 O 3p N15a WICIi 31 11 1 �N1u .N h R1 Based on the preceding information and a good understanding of the formations gathered from drilling vec 25+ wells in this area since 2008 PNRA requests an exemption from 20 AAC 25.035 (c) which requires a C144- diverter system be installed on the well while drilling the surface interval. Zv AAc_Z>.035 (k)(Z) nv ^I iI TI ❑ a 3 ' 3 - 3g . 3o m i� m3aaa mm > > > CO o pp > > <m a2 a am .i .mai < c < J .y Y J a J J p ^� V ..., r-1 a m > a 6 a O m Y ; Y .-4 Y p 3 Z a f z a a a a Za 3 z z 7 - O .-I m m J Y �Y[ u, Y m X ,- Y J a .y r..0- _ ti ii Y Y Y j m a + m m m a7 m .-I 7 Y. m Z'i.-Im in -• a a vT �Nrv 'i a,,,o # Y O a a J ^n m m co.W m W Z 3 i� N N vs 7 o a o 0 0 0. B o o z . 7.g '7.a ,000, 007.0,,, 0000 .-;' O 0N all00000 �'c g000Yo ..-m0,-.400^ro�' 00�00000000mm000000 ,.1,0,4r.,`,4,4,0 .r Y Y n.+ 0 .- O .a O n m m 6 m m O a a 0 m m m ma o 0 m y m a nyy Oyy �Y[[n[[ g yy_ x n y a y_`r'T - J a O. 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' - O 1-4-14 0 - O ® _ al _ 1 0 nl El o [ii] (+)141Jo (-)g1noS Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-29 - Slot ODS-29 ODSN-29 PN5 Plan: ODSN-29 PN5 wp02 Standard Proposal Report 30 July, 2012 HALLIBURTON Sperry Drilling Services • \ .4:.: HALLIBURTON REFERENCE INFORMATION Co-ordinate ME)Reference:Well ODSN-29-Sbt ODS-29 True North '� 1.1 Sperry Drilling Vertical(TVD)Reference:42.7'+13.5'(g 5&208(Nabors 19AC) . }.,A ._.=, Measured Depth Reference:42.7'+13.5'a 5E205(Nabors 19AC) Calculation Method:Minimum Curvature COMPANY DETAILS: Well Planning-Pioneer-Oooguruk SECTION DETAILS Calculation Method:Minimum Curvature Error System'ISCWSA Sec MD Inc Azi ND +N/-S +E/-W DLeg TFace VSec Target Scan Method: Tray.Cylinder North 1 42.70 0.00 0.00 42.70 0.00 0.00 0.00 0.00 0.00 Error Surface: Elliptical Conic 2 292.70 0.00 0.00 292.70 0.00 0.00 0.00 0.00 0.00 Warning Method:Rules Based 3 559.37 8.00 140.00 558.50 -14.24 11.95 3.00 140.8(1 -16.51 - 4 3496.49 50.32 45.53 3124.83 667.35 1018.33 1.75 -100.94 427.84 5 6760.97 50.32 45.53 520904 2427.49 2811.32 0.00 0.00 1752.03 6 9359.56 85.00 318.59 6370.05 4485.78 2635.92 3.29 1.90 3798. 9 Project: Oooguruk Development 7 9659.56 85.00 318.59 6396.20 4709.94 2438.26 0.00 X0.00 4060.73 N29 PN5 v2 t1 Site: Oooguruk Drill Site 8 9801.72 89.26 318.68 6403.31 4816.47 2344.46 3.00 1.11 4185.24 Well: 9 10791.62 89.26 318.68 6416.03 5559.83 1690.88 0.00 0.00 5053.81 ODSN-29 10 10802.48 88.95 318.60 6416.20 5567.98 1683.71 3.00 -166.64 5063.34 N29 PN5 v212 Wellbore:ODSN-29 PN5 11 10802.54 88.94 318.60 6416.20 5568.02 1663.67 3.00 0.00 5063.39 Plan:ODSN-29 PN5 w 02 12 12691.42 88.94 318.60 6450.98 6984.70 434.79 0.00 0.00 6719.42 p 13 12706.54 89.40 318.60 6451.20 6996.04 424.79 3.00 -0.36 6732.67 N29 PN5 v2 t3 10800- 14 12707.04 89.41 318.60 6451.21 6996.41 424.47 3.00 2.51 6733.11 15 13628.55 89.41 318.60 6460.64 7687.81 -184.91 0.00 0.00 7541.10 ODSN-29/0DSN-29 PN5 wp02 16 13659.17 88.50 318.56 6461.20 7710.57 -205.17 3.00 -177.49 7567.94 N29 PN5 v2 t4 ' 17 13662.41 88.40 318.56 6461.29 7713.00 -207.31 3.00 179.26 7570.78 10200- 4 1/2" X46 18 14532.87 88.40 318.56 648582 8365.29 -783.18 0.00 0.00 8333.46 19 14611.35 90.75 318.53 6486.20 8424.10 -835.12 3.00 -0.74 8402.23 N29 PN5 v2 t5 1 - , -Total Depth:16753.9'MD,6458.1'TVD 20 15753.88 90.75 318.53 6471.20 9280.13 -1591.67 0.00 0.00 9403.31 N29 PN5 v2 t6 21 16753.88 90.75 318.53 4468.0710029.38 -2253.83 0.00 0.00 10279.50 End Dir 14611.3'MD,6486.2'TVD 9600 I WELLBORE TARGET DETAILS(MAP CO-ORDINATES) I 1 • Start Air 3°/100':14532.9'MD,6485.6'TVD Name TVD +N/S +E/-W Northing Easting Shape 9000- N29 PNS v2 teil 1 N29 PN5 v2 t1 6396.20 4709.94 2438.26 6035808.00 472381.00 Point _ 1 N29 PN5 v2 t2 6416.20 5567.98 1683.71 6036669.00 471630.00 Point 1 N229 PN5 v2 t3 6451.20 8996.04 424.79 6038102.00 470377.00 Point i ' N29 PN5 v2 t4 6461.20 7710.57 -205.17 6038819.00 469750.00 Point End Dir:13662.4'MD,6461.3'TVD N29 P1145 v2 t6 6471.20 9280.13 -1591.67 6040394.00 468370.00 Point 8400- i- N29 PN5 v2 t5 6488.20 8424.10 -835.12 6039535.00 469123.00 Point IN29 PN5 v2 t51 ' 6 Start Dir3/100':13628.5'MD,6460.6TVD SURVEY PROGRAM 7800- I'. End Dir:12707 MD,6451.2TVD Dale:2012-07-30T00:00:00 Validated:Yes Version: N29 PN5 v2 t' Start Dir V/100':12691.4'MD,64517VD Depth From Depth To Survey/Plan Tool 42.70 1300.00 ODSN-29 PN5 wp02 SR-Gyro-SS 7200- I - 1300.00 3879.00 ODSN-29PN5wp02 MWD+IFR2+MS+sag _ 3879.00 7236.00 ODSN-29PN5wp02 MWD+IFR2+MS+sag 7236.00 9904.00 ODSN-29 PN5 wp02 MWD+IFR2+MS+sag _ 9904.0016753.88 ODSN-29PN5wp02 MWD+IFR2+MS+sag 6600- IN29 PN5 v2 t3l C _ End Dir.106025'MD,6416.2'TVD o 6000- vn - ,'Start Dir 3°/100':10791.6'MD,64I6'TVD } - -. -- End Dir 9801.7'MD,6403.3'TVD s 5400- - N29 PN5 v2 t21 T' 0 , Start Dir 3°/100':9659.6'MD,6396.211 s 4800- '\ I -, DDI=6.73 C - IN29PNSv2tl--- _____End Dir:9359.6'MD,6370.1'TVD Vi - 4200- 3600- - 6000 3000- y _9-5/8" Start Dir 3.25°/100':6761'MD,5209'TVD / Aso, ____ ,r2 1800- v �b .7% CASING DETAILS End Dir:3496.5'MD,3124.8'TVD ND MD Name Size 3368.97 3878.88 11-3/4" 11.750 1200- _ 11-3/4" 5510.60 7236.50 9-5/8" 9.625 Stat Dir 3°/100':292.7 MD,292.7TVD:140°RT TE __--- 6404.63 9904.35 7" 7.000 s ,,>, 6458.07 16753.88 41/2" 4.500 600- _ \ a WELL DETAIIS: ODSN-29 Start Dir 1.75°/100':5594'MD,558.5'TVD 'b Ground Level: 13.50 - 1$ +N/-S +E/-W Northing Easting Latittude Longitude Slot 0- q, 0.00 0.00 603110844 469923.95 70°29'45.820 N 150°14'45.357 W ODS-29 lI ill 11llli IIIliiiiiilill imI i i i III I III III III II 1111111111111 IIIli III : ! 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Q1 C.. z MN 0091)LOKI IBOIWA enil 8 Pioneer Natural Resources HALLIBURTDrt Standard Proposal Report Database: EDM Alaska Local Co-ordinate Reference: Well ODSN-29-Slot ODS-29 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) • Site: Oooguruk Drill Site North Reference: True Well: ODSN-29 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-29 PN5 Design: ODSN-29 PN5 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 lL'sing geodetic scale factor Site Oooguruk Drill Site Site Position: Northing: 6,031,151.32ft Latitude: 70.496 From: Map Easting: 469,920.45ft Longitude: -150.246 Position Uncertainty: 0.0 ft Slot Radius: Grid Convergence: -0.23? Well ODSN-29-Slot ODS-29 Well Position +N/-S 0.0 ft Northing: 6,031,108.44 ft - Latitude: 70.496 +El-W 0.0 ft Easting: 469,923.95 ft - Longitude: -150.246 Position Uncertainty 0.0 ft Wellhead Elevation: ft Sround Level: 13.5ft Wellbore ODSN-29 PN5 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (2) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-29 PN5 wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 42.7 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (bearing) 42.7 0.0 0.0 347.33 7/302012 2:27:16PM Page 2 COMPASS 2003.16 Build 42 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDM Alaska Local Co-ordinate Reference: Well ODSN-29-Slot ODS-29 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'©56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-29 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-29 PN5 Design: ODSN-29 PN5 wp02 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +NI-S +E/-W Rate Rate Rate Tool Face (ft) (?) (bearin (ft) ft (ft) (ft) (?/100ft) (?/100ft) (?100ft) (?) 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 0.00 0.00 0.00 0.00 292.7 0.00 0.00 292.7 236.5 0.0 0.0 0.00 0.00 0.00 0.00 559.4 8.00 140.00 558.5 502.3 -14.2 11.9 3.00 3.00 0.00 140.00 3,496.5 50.32 45.53 3,124.8 3,068.6 667.3 1,01t3 1.75 1.44 -3.22 -100.94 6,761.0 50.32 45.53 5,209.0 5,152.8 2,427.5 2,811.3 0.00 0.00 0.00 0.00 9,359.6 85.00 318.59 6,370.1 6,313.9 4,485.8 2,635.9 3.25 1.33 -3.35 -91.90 9,659.6 85.00 318.59 6,396.2 6,340.0 4,709.9 2,438.3 0.00 0.00 0.00 0.00 9,801.7 89.26 318.68 6,403.3 6,347.1 4,816.5 2,344.5 3.00 3.00 0.06 1.11 10,791.6 89.26 318.68 6,416.0 6,359.8 5,55 .8 1,696.9 0.00 0.00 0.00 0.00 10,802.5 88.95 318.60 6,416.2 6,360.0 5,568.0 1,683.7 3.00 -2.92 -0.69 -166.64 10,802.5 88.94 318.60 6,416.2 6,360.0 5,568.0 1,683.7 3.00 -3.00 0.02 0.00 12,691.4 88.94 318.60 6,451.0 6,394.8 6,984.7 434.8 0.00 0.00 0.00 0.00 12,706.5 89.40 318.60 6,451.2 6,395.0 6,996.0 424.8 3.00 3.00 -0.02 -0.36 12,707.0 89.41 318.60 6,451.2 6,395.0 6,996.4 424.5 3.00 3.00 0.13 2.51 13,628.5 89.41 318.60 6,460.6 6,404.4 7,687.6 -184.9 0.00 0.00 0.00 0.00 13,659.2 88.50 318.56 6,461.2 6,405.0 7,710.6 -205.2 3.00 -3.00 -0.13 -177.49 13,662.4 88.40 318.56 6,461.3 6,405.1 7,713.0 -207.3 3.00 -3.00 0.04 179.26 14,532.9 88.40 318.56 6,485.6 6,429.4 8,165.3 -783.2 0.00 0.00 0.00 0.00 14,611.3 90.75 318.53 6,486.2 6,430.0 8,424.1 -835.1 3.00 3.00 -0.04 -0.74 15,753.9 90.75 318.53 6,471.2 6,415.0 9,280.1 -1,591.7 0.00 0.00 0.00 0.00 16,753.9 90.75 318.53 6,458.1 6,401.9 10,029.4 -2,253.8 0.00 0.00 0.00 0.00 I 7/30/2012 2:27:16PM Page 3 COMPASS 2003.16 Build 42 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDM Alaska Local Co-ordinate Reference: Well ODSN-29-Slot ODS-29 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-29 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-29 PN5 Design: ODSN-29 PN5 wp02 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section , (ft) (?) (bearing) (ft) ft (ft) (ft) (ft) (ft) -13.50 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 6,031,108.44 469,923.95 0.00 0.00 100.0 0.00 0.00 100.0 43.8 0.0 0.0 6,031,108.44 469,923.95 0.00 0.00 200.0 0.00 0.00 200.0 143.8 0.0 0.0 6,031,108.44 469,923.95 0.0G 0.00 292.7 0.00 0.00 292.7 236.5 0.0 0.0 6,031,108.44 469,923.95 0.00 0.00 Start Dir 3°1100':292.7'MD,292.7'TVD:140°RT TF 300.0 0.22 140.00 300.0 243.8 0.0 0.0 6,031,108.43 469,923.96 3.00 -0.01 400.0 3.22 140.00 399.9 343.7 -2.3 1.9 6,031,106.12 469,925.88 3.00 -2.68 500.0 6.22 140.00 499.6 443.4 -8.6 7.2 6,031,099.80 469,931.14 3.00 -9.98 559.4 8.00 140.00 558.5 502.3 -14.2 12.0 6,031,094.15 469,935.84 3.00 -16.52 Start Dir 1.75°/100':559.4'MD,558.57VD 600.0 7.90 134.91 598.7 542.5 -18.4 15.7 6,031,090.00 469,939.62 1.75 -21.38 700.0 7.91 122.16 697.8 641.6 -26.9 26.4 6,031,081.45 469,950.27 1.75 -32.03 800.0 8.30 110.03 796.8 740.6 -33.0 39.0 6,031,075.27 469,962.85 1.75 -40.77 900.0 9.01 99.39 895.7 839.5 -36.8 53.5 6,031,071.46 469,977.34 1.75 -47.61 1,000.0 9.98 90.55 994.3 938.1 -38.1 69.9 6,031,070.03 469,993.73 1.75 -52.53 1,100.0 11.15 83.40 1,092.6 1,036.4 -37.1 88.2 6,031,070.99 470,012.00 1.75 -55.54 1,200.0 12.44 77.65 1,190.5 1,134.3 -33.7 108.3 6,031,074.32 470,032.14 1.75 -56.62 1,300.0 13.84 73.00 1,287.9 1,231.7 -27.5 130.3 6,031,080.04 470,054.13 1.75 -55.77 1,400.0 15.31 69.22 1,384.7 1,328.5 -19.7 154.1 6,031,088.12 470,077.94 1.75 -53.00 1,500.0 16.83 66.00 1,480.8 1,424.6 -9.1 179.7 6,031,098.57 470,103.56 1.75 -48.31 1,600.0 18.39 63.47 1,576.1 1,19.9 3.8 207.0 6,031,111.38 470,130.96 1.75 -41.71 1,684.8 19.74 61.57 1,656.2 1,600.0 16.6 231.6 6,031,124.07 470,155.57 1.75 -34.61 Base Permafrost 1,700.0 19.98 61.25 1,670.5 1,614.3 19.0 236.1 6,031,126.52 470,160.12 1.75 -33.19 1,800.0 21.60 59.35 1,764.0 1,707.8 36.6 266.9 6,031,144.00 470,191.01 1.75 -22.78 1,900.0 23.23 57.70 1,856.4 1,800.2 56.6 299.4 6,031,163.79 470,223.59 1.75 -10.47 2,000.0 24.88 56.26 1,947.8 1,891.6 78.8 333.6 6,031,185.87 470,257.85 1.75 3.72 2,100.0 26.54 54.99 2,037.9 1,981.7 103.3 369.4 6,031,210.22 470,293.74 1.75 19.78 2,200.0 28.21 53.86 2,126.7 2,070.5 130.1 406.8 6,031,236.83 470,331.23 1.75 37.69 2,300.0 29.89 52.84 2,214.1 2,157.9 159.0 445.8 6,031,265.66 470,370.30 1.75 57.44 2,400.0 31.58 51.93 2,300.0 2,243.8 190.2 486.2 6,031,296.69 470,410.89 1.75 79.01 2,431.2 32.10 51.66 2,326.5 2,270.3 200.4 499.1 6,031,306.81 470,423.85 1.75 86.10 Top West Sak 2,500.0 33.27 51.10 2,384.4 2,328.2 223.6 528.2 6,031,329.90 470,452.98 1.75 102.37 2,600.0 34.97 50.33 2,467.2 2,411.0 259.1 571.6 6,031,365.24 470,496.53 1.75 127.51 2,700.0 36.67 49.64 2,548.3 2,492.1 296.8 616.4 6,031,402.68 470,541.49 1.75 154.40 2,800.0 38.37 48.99 2,627.6 2,571.4 336.5 662.6 6,031,442.20 470,587.82 1.75 183.02 2,900.0 40.08 48.39 2,705.1 2,648.9 378.2 710.1 6,031,483.75 470,635.49 1.75 213.33 3,000.0 41.75 47.84 2,780.6 2,724.4 422.0 758.9 6,031,527.30 470,684.43 1.75 245.32 3,100.0 43.51 47.31 2,854.2 2,798.0 467.7 808.9 6,031,572.80 470,734.62 1.75 278.96 ' 3,200.0 45.22 46.83 2,925.6 2,869.4 515.3 860.1 6,031,620.22 470,786.00 1.75 314.20 3,300.0 46.94 46.36 2,995.0 2,938.8 564.8 912.4 6,031,669.50 470,838.52 1.75 351.02 3,302.2 46.98 46.35 2,996.5 2,940.3 565.9 913.6 6,031,670.60 470,839.69 1.75 351.85 Cret tuffs 3,400.0 48.66 45.93 3,062.2 3,006.0 616.1 965.8 6,031,720.60 470,892.14 1.75 389.39 7/30/2012 2:27:16PM Page 4 COMPASS 2003.16 Build 42 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDM Alaska Local Co-ordinate Reference: Well ODSN-29-Slot ODS-29 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-29 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-29 PN5 Design: ODSN-29 PN5 wp02 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 3,068.64 3,496.5 50.32 45.53 3,124.8 3,068.6 667.4 1,018.3 6,031,771.60 470,944.88 1.75 427.84 End Dir:3496.5'MD,3124.8'TVD 3,500.0 50.32 45.53 3,127.1 3,070.9 669.2 1,020.3 6,031,773.48 470,946.81 0.00 429.26 1 3,600.0 50.32 45.53 3,190.9 3,134.7 723.2 1,075.2 6,031,827.17 471,001.95 0.00 469.82 3,700.0 50.32 45.53 3,254.8 3,198.6 777.1 1,130.1 6,031,880.86 471,057.08 0.00 510.39 3,800.0 50.32 45.53 3,318.6 3,262.4 831.0 1,145.0 6,031,934.55 471,112.22 0.00 550.95 3,871.1 50.32 45.53 3,364.0 3,307.8 869.3 1,224.1 6,031,972.72 471,151.42 0.00 579.79 Hue 2 shale 3,878.9 50.32 45.53 3,369.0 3,312.8 873.5 1,228.4 6,031,976.90 471,155.71 0.00 582.95 11-3/4" 3,900.0 50.32 45.53 3,382.5 3,326.3 884.9 1,240.0 6,031,988.24 471,167.36 0.00 591.52 4,000.0 50.32 45.53 3,446.3 3,390.1 938.8 1,294.9 6,032,041.93 471,222.49 0.00 632.08 4,100.0 50.32 45.53 3,510.1 3,453.9 992.8 1,349.8 6,032,095.62 471,277.63 0.00 672.64 4,200.0 50.32 45.53 3,574.0 3,517.8 1,046.7 1,404.7 6,032,149.31 471,332.76 0.00 713.21 4,300.0 50.32 45.53 3,637.8 3,581.6 1,100.6 1,459.7 6,032,203.00 471,387.90 0.00 753.77 4,400.0 50.32 45.53 3,701.7 3,645.5 1,154.5 1,514.6 6,032,256.69 471,443.04 0.00 794.33 4,500.0 50.32 45.53 3,765.5 3,709.3 1,208.4 1,569.5 6,032,310.38 471,498.17 0.00 834.90 4,600.0 50.32 45.53 3,829.4 3,773.2 1,262.3 1,624.4 6,032,364.07 471,553.31 0.00 875.46 4,700.0 50.32 45.53 3,893.2 3,837.0 1,316.3 1,679.4 6,032,417.76 471,608.45 0.00 916.02 4,800.0 50.32 45.56 3,957.1 3,900.9 1,370.2 1,734.3 6,032,471.45 471,663.58 0.00 956.59 4,900.0 50.32 45.53 4,020.9 3064.7 1,424.1 1,789.2 6,032,525.14 471,718.72 0.00 997.15 5,000.0 50.32 45.53 4,084.7 4,028.5 1,478.0 1,844.1 6,032,578.83 471,773.86 0.00 1,037.72 5,100.0 50.32 45.53 4,148.6 4,092.4 1,531.9 1,899.1 6,032,632.52 471,828.99 0.00 1,078.28 5,200.0 50.32 45.53 4,212.4 4,156.2 1,585.8 1,954.0 6,032,686.21 471,884.13 0.00 1,118.84 5,300.0 50.32 45.53 4,276.3 4,220.1 1,639.8 2,008.9 6,032,739.90 471,939.26 0.00 1,159.41 5,400.0 50.32 45.53 4,340.1 4,283.9 1,693.7 2,063.8 6,032,793.59 471,994.40 0.00 1,199.97 5,411.2 50.32 45.53 4,347.3 4,291.1 1,699.7 2,070.0 6,032,799.62 472,000.59 0.00 1,204.53 Brooklan 2B 5,500.0 50.32 45.53 4,404.6 4,347.8 1,747.6 2,118.7 6,032,847.28 472,049.54 0.00 1,240.53 5,600.0 50.32 45.53 4,467.8 4,411.6 1,801.5 2,173.7 6,032,900.97 472,104.67 0.00 1,281.10 5,700.0 50.32 45.53 4,531.7 4,475.5 1,855.4 2,228.6 6,032,954.66 472,159.81 0.00 1,321.66 5,800.0 50.32 45.53 4,595.5 4,539.3 1,909.4 2,283.5 6,033,008.35 472,214.95 0.00 1,362.22 5,900.0 50.32 45.53 4,659.4 4,603.2 1,963.3 2,338.4 6,033,062.04 472,270.08 0.00 1,402.79 6,1100.0 50.32 45.53 4,723.2 4,667.0 2,017.2 2,393.4 6,033,115.73 472,325.22 0.00 1,443.35 6,100.0 50.32 45.53 4,787.0 4,730.8 2,071.1 2,448.3 6,033,169.42 472,380.36 0.00 1,483.92 6,200.0 50.32 45.53 4,850.9 4,794.7 2,125.0 2,503.2 6,033,223.11 472,435.49 0.00 1,524.48 6,300.0 50.32 45.53 4,914.7 4,858.5 2,178.9 2,558.1 6,033,276.80 472,490.63 0.00 1,565.04 6,400.0 56.32 45.53 4,978.6 4,922.4 2,232.9 2,613.1 6,033,330.49 472,545.76 0.00 1,605.61 6,500.0 50.32 45.53 5,042.4 4,986.2 2,286.8 2,668.0 6,033,384.18 472,600.90 0.00 1,646.17 6,596.6 50.32 45.53 5,104.1 5,047.9 2,338.9 2,721.1 6,033,436.05 472,654.17 0.00 1,685.36 Top Torok Sand 6,600.0 50.32 45.53 5,106.3 5,050.1 2,340.7 2,722.9 6,033,437.87 472,656.04 0.00 1,686.73 6,700.0 50.32 45.53 5,170.1 5,113.9 2,394.6 2,777.8 6,033,491.56 472,711.17 0.00 1,727.30 6,761.0 50.32 45.53 5,209.1 5,152.9 2,427.5 2,811.3 6,033,524.31 472,744.81 0.00 1,752.04 Start Dir 3.25°I100':6761'MD,5209'TVD 7/30/2012 2:27:16PM Page 5 COMPASS 2003.16 Build 42 Pioneer Natural Resources H O,LLIBURTON Standard Proposal Report Database: EDM Alaska Local Co-ordinate Reference: Well ODSN-29-Slot ODS-29 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-29 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-29 PN5 Design: ODSN-29 PN5 wp02 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 5,177.77 6,800.0 50.29 43.88 5,234.0 5,177.8 2,448.8 2,832.5 6,033,545.55 472,766.00 3.25 1,768.22 6,900.0 50.32 39.66 5,297.9 5,241.7 2,506.2 2,883.7 6,033,602.71 472,817.46 3.25 1,812.96 7,000.0 50.50 35.45 5,361.6 5,305.4 2,567.3 2,930.6 6,033,663.58 472,864.65 3.25 1,862.25 7,045.8 50.64 33.53 5,390.7 5,334.5 2,596.5 2,950.7 6,033,692.67 472,884.81 3.25 1,886.32 Base Torok Sand 7,100.0 50.83 31.27 5,425.0 5,368.8 2,631.9 2,973.1 6,033,727.99 472,907.42 3.25 1,915.95 7,200.0 51.31 27.13 5,487.8 5,431.6 2,699.8 3,011.1 6,033,795.72 472,945.62 3.25 1,973.87 7,228.5 51.48 25.97 5,505.6 5,449.4 2,719.6 3,021.0 6,033,815.57 472,955.64 3.25 1,991.10 Torok 1 Shale 7,236.5 51.52 25.64 5,510.6 5,454.4 2,725.3 3,023.8 6,033,821.22 472,958.40 3.25 1,996.02 9-5/8" 7,300.0 51.94 23.07 5,549.9 5,493.7 2,770.7 3,044.3 6,033,866.54 472,979.13 3.25 2,035.82 7,400.0 52.70 19.07 5,611.1 5,554.9 2,844.6 3,072.7 6,033,940.25 473,007.86 3.25 2,101.62 7,500.0 53.59 15.17 5,671.1 5,614.9 2,921.0 3,096.3 6,034,016.59 473,031.69 3.25 2,171.05 7,600.0 54.60 11.35 5,729.7 5,673.5 2,699.8 3,114.8 6,034,095.33 473,050.56 3.25 2,243.89 7,700.0 55.74 7.64 5,786.9 5,730.7 3,090.8 3,128.3 6,034,176.20 473,064.41 3.25 2,319.89 7,800.0 56.98 4.03 5,842.3 5,786.1 3,163.6 3,136.8 6,034,258.96 473,073.20 3.25 2,398.82 7,841.1 57.52 2.58 5,864.5 5,808.3 3,198.1 3,138.8 6,034,293.45 473,075.33 3.25 2,432.04 Top HRZ 7,900.0 58.32 0.53 5,895.8 5,839.6 3,247.9 3,140.1 6,034,343.33 473,076.88 3.25 2,480.42 8,000.0 59.76 357.13 5,947.2 5,591.0 3,333.7 3,138.4 6,034,429.04 473,075.46 3.25 2,564.44 8,092.2 61.15 354.08 5,992.7 5,936.5 3,413.6 3,132.2 6,034,508.98 473,069.63 3.25 2,643.77 Base HRZ 8,100.0 61.28 353.83 5,996.E 5,940.3 3,420.4 3,131.5 6,034,515.81 473,068.93 3.25 2,650.59 8,200.0 62.87 350.63 6,043.3 5,987.1 3,507.9 3,119.5 6,034,603.37 473,057.32 3.25 2,738.61 8,270.5 64.04 348.43 6,074.8 6,018.6 3,569.9 3,108.1 6,034,665.39 473,046.11 3.25 2,801.59 Kalubik Marker 8,300.0 64.54 347.52 6,087.6 6,031.4 3,595.9 3,102.5 6,034,691.44 473,040.67 3.25 2,828.20 9,400.0 66.28 344.49 6,129.2 6,073.0 3,684.2 3,080.5 6,034,779.73 473,019.03 3.25 2,919.09 8,405.4 66.37 34433 6,131.4 6,075.2 3,688.9 3,079.2 6,034,784.50 473,017.72 3.25 2,924.03 Top Kuparuk C 8,449.5 67.16 343.02 6,148.8 6,092.6 3,727.8 3,067.8 6,034,823.43 473,006.48 3.25 2,964.47 Base Kuparuk(LCU) 8,500.0 68.07 341.55 6,168.0 6,111.8 3,772.3 3,053.6 6,034,867.96 472,992.46 3.25 3,010.98 8,606.0 69.91 338.64 6,203.9 6,147.7 3,860.0 3,021.8 6,034,955.84 472,961.06 3.25 3,103.57 8,700.0 71.79 335.88 6,236.7 6,180.5 3,947.2 2,985.3 6,035,043.09 472,924.92 3.25 3,196.57 8,800.0 73.72 333.14 6,266.4 6,210.2 4,033.3 2,944.2 6,035,129.43 472,884.16 3.25 3,289.67 8,900.0 75.68 330.45 6,292.8 6,236.6 4,118.3 2,898.6 6,035,214.59 472,838.91 3.25 3,382.58 9,000.0 77.67 327.81 6,315.8 6,259.6 4,201.8 2,848.7 6,035,298.29 472,789.32 3.25 3,475.00 9,100.0 79.68 325.21 6,335.4 6,279.2 4,283.6 2,794.6 6,035,380.25 472,735.55 3.25 3,566.63 9,164.7 81.00 323.54 6,346.3 6,290.1 4,335.5 2,757.4 6,035,432.27 472,698.59 3.25 3,625.39 BCU 9,200.0 81.72 322.64 6,351.6 6,295.4 4,363.3 2,736.5 6,035,460.22 472,677.77 3.25 3,657.18 9,300.0 83.77 320.10 6,364.2 6,308.0 4,440.8 2,674.5 6,035,537.95 472,616.16 3.25 3,746.35 7/30/2012 2:27:16PM Page 6 COMPASS 2003.16 Build 42 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDM Alaska Local Co-ordinate Reference: Well ODSN-29-Slot ODS-29 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'©56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'©56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-29 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-29 PN5 Design: ODSN-29 PN5 wp02 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 6,313.86 9,359.6 85.00 318.59 6,370.1 6,313.9 4,485.8 2,635.9 6,035,583.09 472,577.71 3.25 3,798.72 End Dir:9359.6'MD,6370.1'TVD 9,400.0 85.00 318.59 6,373.6 6,317.4 4,516.0 2,609.3 6,035,613.38 472,551.21 0.00 3,834.01 9,500.0 85.00 318.59 6,382.3 6,326.1 4,590.7 2,543.4 6,035,688.36 472,485.64 0.00 3,921.36 9,600.0 85.00 318.59 6,391.0 6,334.8 4,665.4 2,477.5 6,035,763.34 472,420.06 0.00 4,008.70 9,659.6 85.00 318.59 6,396.2 6,340.0 4,709.9 2,438.3 6,035,808.00 472,381.00 0.00 4,060.73 Start Dir 3°/100':9659.6'MD,6396.2'TVD-N29 PN5 v2 t1 9,679.1 85.58 318.61 6,397.8 6,341.6 4,724.5 2,425.4 6,035,822.62 472,368.21 3.00 4,077.77 Top Nuiqsut 9,700.0 86.21 318.62 6,399.3 6,343.1 4,740.2 2,411.6 6,035,838.35 472,354.47 3.00 4,096.09 9,741.8 87.47 318.64 6,401.6 6,345.4 4,771.5 2,384.0 6,035,869.74 472,327.04 3.00 4,132.65 Nuiqsut 1 9,800.0 89.21 318.68 6,403.3 6,347.4 4,815.2 2,345.6 6,035,913.61 472,288.77 3.00 4,183.73 9,801.7 89.26 318.68 6,403.3 6,347.1 4,816.5 2,344.5 6,035,914.89 472,287.65 3.00 4,185.22 End Dir:9801.7'MD,6403.3'TVD 9,900.0 89.26 318.68 6,404.6 6,348.4 4,8E0.3 2,279.6 6,035,988.96 472,223.06 0.00 4,271.47 9,904.4 89.26 318.68 6,404.6 6,348.4 4,893.5 2,276.7 6,035,992.24 472,220.20 0.00 4,275.29 7" 10,000.0 89.26 318.68 6,405.9 6,349.7 4,965.4 2,213.5 6,036,064.31 472,157.34 0.00 4,359.22 10,100.0 89.26 318.68 6,407.1 6,350.9 5,040.5 2,147.5 6,036,139.66 472,091.63 0.00 4,446.96 10,200.0 89.26 314.68 6,408.4 6,352.2 5,115.6 2,081.5 6,036,215.02 472,025.92 0.00 4,534.70 10,300.0 89.26 318.68 6,409.7 8,353.5 5,190.7 2,015.5 6,036,290.37 471,960.20 0.00 4,622.45 10,400.0 89.26 318.68 6,411.0 6,354.8 5,265.7 1,949.4 6,036,365.72 471,894.49 0.00 4,710.19 10,500.0 89.26 318.68 6,412.3 6,356.1 5,340.8 1,883.4 6,036,441.08 471,828.78 0.00 4,797.93 10,600.0 89.26 318.68 6,413.6 6,357.4 5,415.9 1,817.4 6,036,516.43 471,763.06 0.00 4,885.68 10,700.0 89.26 318.68 6,414.9 6,358.7 5,491.0 1,751.4 6,036,591.78 471,697.35 0.00 4,973.42 10,791.6 89.26 318.68 6,416.0 6,359.8 5,559.8 1,690.9 6,036,660.81 471,637.16 0.00 5,053.79 Start Dir 3°/100':10791.6'MD,6416'TVD 10,800.0 89.02 318.62 6,416.2 6,360.0 5,566.1 1,685.3 6,036,667.13 471,631.63 2.99 5,061.16 10,802.5 88.95 318.60 6,416.2 6,360.0 5,568.0 1,683.7 6,036,669.00 471,630.00 2.98 5,063.34 End Dir.10802.5'MD,6416.2'TVD-N29 PN5 v2 t2 10,802.5 88.94 318.60 6,416.2 6,360.0 5,568.0 1,683.7 6,036,669.05 471,629.96 3.94 5,063.39 10,900.0 88.94 318.60 6,418.0 6,361.8 5,641.1 1,619.2 6,036,742.39 471,565.83 0.00 5,148.83 11,000.0 88.94 318.60 6,419.8 6,363.6 5,716.1 1,553.1 6,036,817.65 471,500.02 0.00 5,236.51 11,1001.0 88.94 318.6ft 6,421.7 6,365.5 5,791.1 1,487.0 6,036,892.91 471,434.21 0.00 5,324.18 11,200.0 88.94 318.60 6,423.5 6,367.3 5,866.1 1,420.9 6,036,968.17 471,368.41 0.00 5,411.85 11,300.0 88.94 318.60 6,425.4 6,369.2 5,941.1 1,354.8 6,037,043.43 471,302.60 0.00 5,499.52 11,400.0 if8.94 318.60 6,427.2 6,371.0 6,016.1 1,288.6 6,037,118.69 471,236.79 0.00 5,587.19 11,500.0 88.94 318.60 6,429.0 6,372.8 6,091.1 1,222.5 6,037,193.95 471,170.99 0.00 5,674.87 11,600.0 88.94 318.60 6,430.9 6,374.7 6,166.1 1,156.4 6,037,269.21 471,105.18 0.00 5,762.54 11,700.0 88.94 318.60 6,432.7 6,376.5 6,241.1 1,090.3 6,037,344.47 471,039.37 0.00 5,850.21 11,800.0 88.94 318.60 6,434.6 6,378.4 6,316.1 1,024.2 6,037,419.73 470,973.57 0.00 5,937.88 11,900.0 88.94 318.60 6,436.4 6,380.2 6,391.1 958.1 6,037,494.99 470,907.76 0.00 6,025.56 12,000.0 88.94 318.60 6,438.3 6,382.1 6,466.1 891.9 6,037,570.25 470,841.95 0.00 6,113.23 12,100.0 88.94 318.60 6,440.1 6,383.9 6,541.1 825.8 6,037,645.51 470,776.15 0.00 6,200.90 7/30/2012 2:27:16PM Page 7 COMPASS 2003.16 Build 42 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDM_Alaska Local Co-ordinate Reference: Well ODSN-29-Slot ODS-29 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-29 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-29 PN5 Design: ODSN-29 PN5 wp02 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 6,385.73 12,200.0 88.94 318.60 6,441.9 6,385.7 6,616.1 759.7 6,037,720.77 470,710.34 0.00 6,288.57 12,300.0 88.94 318.60 6.443.8 6,387.6 6,691.1 693.6 6,037,796.03 470,644.53 0.00 6,376.25 12,400.0 88.94 318.60 6,445.6 6,389.4 6,766.1 627.5 6,037,871.29 470,578.73 0.0G 6,463.92 12,500.0 88.94 318.60 6,447.5 6,391.3 6,841.1 561.4 6,037,946.55 470,512.92 0.00 6,551.59 12,600.0 88.94 318.60 6,449.3 6,393.1 6,916.1 495.2 6,038,021.81 470,447.11 0.00 6,639.26 12,691.4 88.94 318.60 6,451.0 6,394.8 6,984.7 434.8 6,038,090.60 470,386.97 0.00 6,719.40 Start Dir 3°/100':12691.4'MD,6451'TVD 12,700.0 89.20 318.60 6,451.1 6,394.9 6,991.1 429.1 6,038,097.08 470,381.31 2.99 6,726.94 12,706.5 89.40 318.60 6,451.2 6,395.0 6,996.0 424.8 6,038,102.00 470,377.00 3.00 6,732.67 N29 PN5 v2 t3 12,707.0 89.41 318.60 6,451.2 6,395.0 6,996.4 424.5 6,038,102.34 470,376.70 3.00 6,733.07 End Dir:12707'MD,6451.2'TVD 12,800.0 89.41 318.60 6,452.2 6,396.0 7,066.1 363.0 6,038,172.34 470,315.49 0.00 6,814.62 12,900.0 89.41 318.60 6,453.2 6,397.0 7,141.1 296.9 6,038,247.61 470,249.67 0.00 6,902.30 13,000.0 89.41 318.60 6,454.2 6,398.0 7,x16.2 230.7 6,038,322.87 470,183.86 0.00 6,989.98 13,100.0 89.41 318.60 6,455.2 6,399.0 7,251.2 164.6 6,038,398.14 470,118.04 0.00 7,077.66 13,200.0 89.41 318.60 6,456.3 6,400.1 7,366.2 98.5 6,038,473.41 470,052.22 0.00 7,165.34 13,300.0 89.41 318.60 6,457.3 6,401.1 7,441.2 32.4 6,038,548.67 469,986.40 0.00 7,253.02 13,400.0 89.41 318.60 6,458.3 6,402.1 7,516.2 -33.8 6,038,623.94 469,920.59 0.00 7,340.70 13,500.0 89.41 318.66 6,459.3 6,403.1 7,591.2 -99.9 6,038,699.21 469,854.77 0.00 7,428.38 13,600.0 89.41 318.60 6,460.3 6,404.1 7,666.2 -166.0 6,038,774.47 469,788.95 0.00 7,516.06 ' 1 13,628.5 89.41 318.60 6,460.6 6,404.4 7,687.6 -184.9 6,038,795.92 469,770.19 0.00 7,541.05 Start Dir 3°l100':13628.5'MD,6460.6'TVD 13,659.2 88.50 318.56 6,461.9 6,405.0 7,710.6 -205.2 6,038,819.00 469,750.00 3.00 7,567.94 N29 PN5 v2 t4 13,662.4 88.40 318.56 6,461.3 6,405.1 7,713.0 -207.3 6,038,821.43 469,747.88 3.00 7,570.77 End Dir:13662.4'MD,6461.3'TVD 13,790.0 88.40 318.56 6,462.3 6,406.1 7,741.2 -232.2 6,038,849.70 469,723.12 0.00 7,603.71 13,800.0 88.40 318.56 6,465.1 6,408.9 7,816.1 -298.3 6,038,924.90 469,657.27 0.00 7,691.33 13,900.0 88.40 318.56 6,467.9 6,411.7 7,891.0 -364.5 6,039,000.09 469,591.42 0.00 7,778.95 14,000.0 88.40 318.56 6,470.7 8,414.5 7,966.0 -430.6 6,039,075.29 469,525.58 0.00 7,866.57 14,100.0 88.40 318.56 6,473.5 6,417.3 8,040.9 -496.8 6,039,150.48 469,459.73 0.00 7,954.18 14,200.0 88.40 318.56 6,476.3 6,420.1 8,115.8 -563.0 6,039,225.68 469,393.89 0.00 8,041.80 14,300.0 88.40 318.56 6,479.1 6,422.9 8,190.8 -629.1 6,039,300.88 469,328.04 0.00 8,129.42 14,400.0 88.40 318.56 6,481.9 6,425.7 8,265.7 -695.3 6,039,376.07 469,262.19 0.00 8,217.04 14,500.0 88.40 318.56 6,484.7 6,428.5 8,340.7 -761.4 6,039,451.27 469,196.35 0.00 8,304.66 14,532.9 88.40 318.56 6,485.6 6,429.4 8,365.3 -783.2 6,039,476.01 469,174.68 0.00 8,333.48 ' Start Dir 3°/100':14532.9'MD,6485.6'TVD 14,600.0 90.41 318.53 6,486.3 6,430.1 8,415.6 -827.6 6,039,526.47 469,130.48 3.00 8,392.29 14,611.3 90.75 318.53 6,486.2 6,430.0 8,424.1 -835.1 6,039,535.00 469,123.00 2.99 8,402.23 End Dir:14611.3'MD,6486.2'TVD-N29 PN5 v2 t5 14,700.0 90.75 318.53 6,485.0 6,428.8 8,490.5 -893.8 6,039,601.65 469,064.57 0.00 8,479.91 14,800.0 90.75 318.53 6,483.7 6,427.5 8,565.4 -960.0 6,039,676.84 468,998.67 0.00 8,567.52 14,900.0 90.75 318.53 6,482.4 6,426.2 8,640.4 -1,026.3 6,039,752.02 468,932.76 0.00 8,655.14 15,000.0 90.75 318.53 6,481.1 6,424.9 8,715.3 -1,092.5 6,039,827.21 468,866.85 0.00 8,742.76 7/30/2012 2:27:16PM Page 8 COMPASS 2003.16 Build 42 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDM Alaska Local Co-ordinate Reference: Well ODSN-29-Slot ODS-29 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-29 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-29 PN5 Design: ODSN-29 PN5 wp02 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 6,423.58 15,100.0 90.75 318.53 6,479.8 6,423.6 8,790.2 -1,158.7 6,039,902.39 468,800.95 0.00 8,830.38 15,200.0 90.75 318.53 6,478.5 6,422.3 8,865.1 -1,224.9 6,039,977.57 468,735.04 0.00 8,918.00 15,300.0 90.75 318.53 6,477.2 6,421.0 8,940.1 -1,291.1 8,040,052.76 468,669.13 0.0G 9,005.62 15,400.0 90.75 318.53 6,475.8 6,419.6 9,015.0 -1,357.3 6,040,127.94 468,603.23 0.00 9,093.24 15,500.0 90.75 318.53 6,474.5 6,418.3 9,089.9 -1,423.6 6,040,203.13 468,537.32 0.00 9,180.86 15,600.0 90.75 318.53 6,473.2 6,417.0 9,164.8 -1,489.8 6,040,278.31 468,471.41 0.00 9,268.48 15,700.0 90.75 318.53 6,471.9 6,415.7 9,239.8 -1,556.0 6,040,353.49 468,405.51 0.00 9,356.10 15,753.9 90.75 318.53 6,471.2 6,415.0 9,280.1 -1,591.7 6,040,394.00 468,370.00 0.00 9,403.31 N29 PN5 v2 t6 15,800.0 90.75 318.53 6,470.6 6,414.4 9,314.7 -1,622.2 6,040,428.68 468,339.60 0.00 9,443.72 15,900.0 90.75 318.53 6,469.3 6,413.1 9,389.6 -1,688.4 6,040,503.86 468,273.70 0.00 9,531.34 16,000.0 90.75 318.53 6,468.0 6,411.8 9,464.5 -1,754.6 6,040,579.04 468,207.79 0.00 9,618.96 16,100.0 90.75 318.53 6,466.7 6,410.5 9,539.5 -1,820.9 6,040,654.23 468,141.88 0.00 9,706.58 16,200.0 90.75 318.53 6,465.3 6,409.1 9,614.4 -1,887.1 6,040,729.41 468,075.98 0.00 9,794.20 16,300.0 90.75 318.53 6,464.0 6,407.8 9,689.3 -1,953.3 6,040,804.60 468,010.07 0.00 9,881.82 16,400.0 90.75 318.53 6,462.7 6,406.5 9,784.2 -2,019.5 6,040,879.78 467,944.16 0.00 9,969.44 16,500.0 90.75 318.53 6,481.4 6,405.2 9,839.2 -2,085.7 6,040,954.96 467,878.26 0.00 10,057.06 16,600.0 90.75 318.53 6,460.1 6,403.9 9,914.1 -2,151.9 6,041,030.15 467,812.35 0.00 10,144.67 16,700.0 90.75 318.53 6,458.8 6,402.6 9,989.0 -2,218.2 6,041,105.33 467,746.45 0.00 10,232.29 16,753.8 90.75 318.93 6,458.1 6,401.9 10,029.3 -2,253.8 6,041,145.78 467,710.99 0.00 10,279.43 Total Depth: 16753.9'MD,6458.1'TVD 16,753.9 90.75 318.53 6,458.1 6,401.9 10,029.4 -2,253.8 6,041,145.84 467,710.94 0.00 10,279.50 Targets Target Name -hit/miss target flip Angle Dip Dir. ND +NI-S +EI-W Northing Easting -Shape (?) (bearing (ft) (ft) (ft) (ft) (ft) N29 PIM5 0.00 0.00 6,416.2 5,568.0 1,683.7 6,036,669.00 471,630.00 -plan hits target -Point 1A29 PN5 v2 t4 0.00 0.00 6,461.2 7,710.6 -205.2 6,038,819.00 469,750.00 -plan hits target -Point N29 PNb v2 t: 0.00 0.00 6,486.2 8,424.1 -835.1 6,039,535.00 469,123.00 -plan hits target -Point N29 PN5 v2 t3 0.00 0.00 6,451.2 6,996.0 424.8 6,038,102.00 470,377.00 -plan hits target -Point N29 PN5 v2 t1 0.00 0.00 6,396.2 4,709.9 2,438.3 6,035,808.00 472,381.00 -plan hits target -Point N29 PN5 v2 t6 0.00 0.00 6,471.2 9,280.1 -1,591.7 6,040,394.00 468,370.00 -plan hits target -Point 7/30/2012 2:27:16PM Page 9 COMPASS 2003.16 Build 42 Pioneer Natural Resources HALLIBURTDN Standard Proposal Report Database: EDM Alaska Local Co-ordinate Reference: Well ODSN-29-Slot ODS-29 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-29 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-29 PN5 Design: ODSN-29 PN5 wp02 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") r) 3,878.9 3,369.0 11-3/4" 11-3/4 14-1/2 7,236.5 5,510.6 9-5/8" 9-5/8 11-3/4 9,904.4 6,404.6 7" 7 7-1/2 16,753.9 6,458.1 4 1/2" 4-1/2 6-1/8 ,,..Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (1) (bearing) 2,431.2 2,326.5 Top West Sak 0.00 8,449.5 6,148.8 Base Kuparuk(LCU) 0.00 3,871.1 3,364.0 Hue 2 shale 0.00 7,228.5 5,505.6 Torok 1 Shale 0.00 7,841.1 5,864.5 lop HRZ 0.00 9,679.1 6,397.8 Top Nuiqsut 0.00 7,045.8 5,390.7 Base Torok°;and 0.00 8,405.4 6,131.4 Top Kuparuk(C 0.00 3,302.2 2,996.5 Cret tuffs 0.00 1,684.8 1,656.2 Base Permafrost 0.00 9,164.7 6,346.3 BCU 0.00 9,741.8 6,401.6 Nuiqsut 1 0.00 8,270.5 6,374.8 Kalubik Marker 0.00 8,092.2 5,992.7 Base HRZ 0.00 5,411.2 4,347.3 Brookian 2B 0.00 6,596.6 5,104.1 Top Torok Sand 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 292.7 292.7 0.0 0.0 Start Dir 3°/100':292.7'MD,292.7'TVD:140°RT TF 559.4 558.5 -14.2 12.0 Start Dir 1.75°/100':559.4'MD,558.5'TVD 3,496.5 3,124.8 667.4 1,018.3 End Dir:3496.5'MD,3124.8'TVD 6,761.0 5,209.1 2,427.5 2,811.3 Start Dir 3.25°/100':6761'MD,5209'TVD 9,359.6 6,370.1 4,485.8 2,635.9 End Dir:9359.6'MD,6370.1'TVD 9,659.6 6,396.2 4,710.0 2,438.2 Start Dir 3°/100':9659.6'MD,6396.2'TVD 9,801.7 6,403.3 4,816.5 2,344.5 End Dir:9801.7'MD,6403.3'TVD 10,391.6 6,416.0 5,559.8 1,690.9 Start Dir 3°/100':10791.6'MD,6416'TVD 10,803.5 6,416.2 5,568.0 1,683.7 End Dir: 10802.5'MD,6416.2'TVD 12,691.4 6,451.0 6,984.7 434.8 Start Dir 3°/100': 12691.4'MD,6451'TVD 12,707.0 6,451.2 6,996.4 424.5 End Dir:12707'MD,6451.2'TVD 13,628.5 6,460.6 7,687.6 -184.9 Start Dir 3°/100':13628.5'MD,6460.6'TVD 13,662.4 6,461.3 7,713.0 -207.3 End Dir:13662.4'MD,6461.3'TVD 14,532.9 6,485.6 8,365.3 -783.2 Start Dir 3°/100': 14532.9'MD,6485.6'TVD 14,611.3 6,486.2 8,424.1 -835.1 End Dir:14611.3'MD,6486.2'TVD 16,753.8 6,458.1 10,029.3 -2,253.8 Total Depth: 16753.9'MD,6458.1'TVD 7/30/2012 2:27:16PM Page 10 COMPASS 2003.16 Build 42 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-29 ODSN-29 PN5 ODSN-29 PN5 wp02 Anticollision Summary Report 30 July, 2012 N I' A N Off/ C a N N PA22 s2 s2 2 22 Z T1 V 2 ������`- g , , ,,,,, hLu Z p om$8®^n4A7e'�a8�3y: o �i,IITl�r �� , irt / , `; � pse88eass$8sn'68, 8,18 ooo8vo4 Pegeeg p o; wa ' I 'r Z.:10 ii ' ` � Ja _ / • . ` i -� Y; - g!!,1!$q$8as8seaa $seaa O o c of - -' \; . tillgall,'''yy $Lo▪ 2 : Z888RFSR;Sz6;;..-n--GAa lla o r '',',•.,,,,;;;::,,,,,7ro fls^84,aoaas�asm�8,,,_, ¢ 4 « � \ ooes 0. aoEW o -F.e.3 .00,_'` I , .k0.1 ! �� aeaaRsaR8ru0411 s •• • , ` V I ". .V888PCIaas888a88a�xaa0. •',47..•. , ,, 0 es8RPIg88anxsss5IR.W . o .oagg88ma8s8g1asa88ag `�1��1 ►'Q_ __..m o B �R�Pri;SNRm93:33Yt�:m833 M a...= • �►-••, N 2 y i- to y .• @: pG a ns.R1a .o, 1$.,rr, .2TRe O A_ a a a--'U=PS.-.i - r" y y O o0 0 y 0 o cT' • -o ..---- - -- - O 7;§ y y Z a N Z Z A O f o p O - YE Lo c O o rn '� z v o 0 0 0 0 0 0 0 0 0 0 0 Z 00000000009000000000000000000 0 O O 9 0 9 o 2 8 0 8 N N ` 8 N N A 8 N A O N 8 8 8 8 8 .2 N M O N 2 P. 000 8 8 .2 N O U C IJ N F N . h r N N N N M M W , of M co Try m y` coU - p c E3 i au p 'o . a m!- w R oo0000000 cn •• •• •• •• •'p E V a s• £ � •14 ... .b8 - 0 - - '48r, - - § 0 N A 000000000000000000000000 ' 888888888888 0 0 0 0 0 0 0 0 0 0 0 sssssssssss IIhIe M u 3 eo Z syn O s �` Z 8 T 1�� nH I .0.•: __�` o III/ N .1g3116� a! 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'� - • .,iZ1 +.� pO 1 \`, ,Z y Z ci 0 '�' '• -ge,,..---i'' �; - • rtK^ I.`' N 111\ \\ Q L e r g g g g O � /y' Si-t'.\"-- ' w J r ,r, h ' p p, y I ''\ �, -- rNge;egp� / eQ; d J-NL 'o o a ` r9 r O, 1 g ',z - Q z N J 'f `•F D Z Ne Y Z Z Z v a eb e § A p O O 0 Y p n 3 tYn Y y Z Z 7 I.; Q O O O ,O O G p O O 0 O O a O Pioneer Natural Resources Anticollision Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29-Slot ODS-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site Error: 0.00ft North Reference: True Reference Well: ODSN-29 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 2.00 sigma Reference Wellbore ODSN-29 PN5 Database: EDM Alaska Reference Design: ODSN-29 PN5 wp02 Offset TVD Reference: Offset Datum Reference ODSN-29 PN5 wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,871.12ft Error Surface: Elliptical Conic Survey Tool Program Date 7/30/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 42.70 1,300.00 ODSN-29 PN5 wp02(ODSN-29 PN5) 3R-Gyro-SS Fixed:v2:surface readout gyro single shot 1,300.00 3,879.00 ODSN-29 PN5 wp02(ODSN-29 PN5) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 3,879.00 7,236.00 ODSN-29 PN5 wp02(ODSN-29 PN5) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 7,236.00 9,904.00 ODSN-29 PN5 wp02(ODSN-29 PN5) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 9,904.00 16,753.88 ODSN-29 PN5 wp02(ODSN-29 BRI6) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 7/30/2012 3:43:32PM Page 2 of 5 COMPASS 2003.16 Build 42 Pioneer Natural Resources Anticollision Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29-Slot ODS-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site Error: 0.00ft North Reference: True Reference Well: ODSN-29 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 2.00 sigma Reference Wellbore ODSN-29 PN5 Database: EDM_Alaska Reference Design: ODSN-29 PN5 wp02 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-t o Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Oooguruk Drill Site ODSDW1-44-ODSDW1-44 Disposal-ODSDW1 549.63 550.00 140.71 9.26 131.44 Pass-Wajor Risk ODSDW2-19-ODSDW2-19 Disposal-ODSDW2 349.10 350.00 135.72 6.40 129.33 Pass-Major Risk ODSK-13-ODSK-13-ODSK-13 349.27 350.00 85.52 6.29 79.24 Pass-Major Risk ODSK-13-ODSK-13PB1 -ODSK-13PB1 349.27 350.00 85.52 6.29 79.24 Pass-Major Risk ODSK-13-ODSK-13PB2-ODSK-13PB2 349.27 350.00 85.52 6.29 79.24 Pass-Major Risk ODSK-14-ODSK-14-ODSK-14 KupB 324.49 325.00 93.70 6.02 87.69 Pass-Major Risk ODSK-14-ODSK-14 PB1 -ODSK-14 PB1 KupB 324.49 325.00 93.70 6.02 87.69 Pass-Major Risk ODSK-14-ODSK-14 PB2-ODSK-14 PB2 KupB 324.49 325.00 93.70 6.02 87.69 Pass-Major Risk ODSK-33-ODSK-33 KupA-ODSK-33 KupA 42.70 42.70 39.95 1.09 37.96 Pass-Major Risk ODSK-33-ODSK-33 PB1 KupA-ODSK-33 PB1 F 473.44 475.00 40.05 8.09 31.97 Pass-Major Risk ODSK-35Ai-ODSK-35 KupB-ODSK-35 KupB St 524.42 525.00 52.96 8.96 44.01 Pass-Major Risk ODSK-35Ai-ODSK-35Ai-ODSK-35Ai KupH Sur 524.42 525.00 52.96 8.96 44.01 Pass-Major Risk ODSK-38i-ODSK-38i KupD-ODSK-38i KupD Sr. 548.37 550.00 88.72 9.58 79.14 Pass-Major Risk ODSK-41 -ODSK-41 KupF-ODSK-41 KupF Sur% 621.114 625.00 106.87 10.58 96.29 Pass-Major Risk ODSK-41 -ODSK-41 PB1 KupF-ODSK-41 PB1 F 621.34 625.00 106.87 10.67 96.20 Pass-Major Risk ODSK-42i-ODSK-42Ai-ODSK-42Ai 400.40 400.00 116.14 7.12 109.04 Pass-Major Risk ODSK-42i-ODSK-42i KupG-ODSK-42i KupG 400.40 400.00 116.14 7.16 108.99 Pass-Major Risk ODSK-7i-ODSN-7i Ivik Kup-ODSN-7i Ivik Iii in a 324.49 325.00 41.40 5.78 35.62 Pass-Major Risk ODSN-1 -ODSN-1 KE3-ODSN-1 KE3 299.86 300.00 43.09 5.41 37.68 Pass-Major Risk ODSN-1 -ODSN-1 KE3 PB1 -ODSN-1 KE3 PB1 299.86 300.00 43.09 5.41 37.68 Pass-Major Risk ODSN-10-ODSN-10 PS12-ODSN-10 PS12 wp1 349.15 350.00 56.85 6.43 50.42 Pass-Major Risk ODSN-11 i-ODSN-11 i IS11 -ODSN-11i IS11 wp1 225.00 225.00 62.65 4.15 58.50 Pass-Major Risk ODSN-12-ODSN-12 PS10-ODSN-12 PS10 wp1 373.81 37i5.00 69.05 6.75 62.32 Pass-Major Risk ODSN-15i-ODSN-15i-ODSN-15i IN12 249.97 25(.00 99.94 4.76 95.18 Pass-Major Risk ODSN-16-ODSN-16-ODSN-16 PN13 Surveys 299.88 300.00 105.87 5.52 100.35 Pass-Major Risk ODSN-16-ODSN-16L1-ODSN-16L1 PN13 299.88 300.00 105.87 5.52 100.35 Pass-Major Risk ODSN-17-ODSN-17-ODSN-17 PN13 Mid Surve 496.92 500.00 108.73 8.75 99.98 Pass-Major Risk ODSN-17-ODSN-17 L1 -ODSN-17 L1 PN13 496.92 500.00 108.73 8.75 99.98 Pass-Major Risk ODSN-18-ODSN-18-ODSN-18 PIN11 349.27 350.00 118.31 6.33 111.99 Pass-Major Risk ODSN-18-ODSN-18 PB5-ODSN-18 PN11 PB5 349.27 350.00 118.31 6.33 111.99 Pass-Major Risk ODSN-18-ODSN-18 PB1-ODSN-18 PN11 PB1 349.27 350.00 118.31 6.33 111.99 Pass-Major Risk ODSN-18-ODSN-18 PB2-ODSN-18 PN11 PB2 349.27 350.00 118.31 6.33 111.99 Pass-Major Risk OCSN-18-ODSN-18 PB2-ODSN-18_PB2 349.27 350.00 118.31 6.33 111.99 Pass-Major Risk ODSN-18-ODSN-18 PB3-ODSN-18 PN11 PB3 349.27 350.00 118.31 6.33 111.99 Pass-Major Risk ODSN-18-ODSN-18 PB4-ODSN-18 PN11 PB4 349.27 350.00 118.31 6.33 111.99 Pass-Major Risk ODSN-2-ODSN-2 PN3 ext-ODSN-2 PN3 ext wp 349.00 350.00 37.98 6.25 31.73 Pass-Major Risk ODSN-20-ODSK-20 KE4-ODSN-20 KE4 wp05 t 324.47 325.00 142.59 6.04 136.56 Pass-Major Risk J OTiSN-21 -ODSN-21 PS13-ODSN-21 PS13 wp0 224.97 225.00 149.45 4.23 145.22 Pass-Major Risk ODSN-22i-ODSN-22i 1814-ODSN-22i 1814 wp0 349.45 350.00 155.91 6.35 149.56 Pass-Major Risk ODSN-23i-ODSN-23i-ODSN-23i IN14 125.00 125.00 162.62 2.38 160.25 Pass-Major Risk ODSN-23i-ODSN-23i PB1 -ODSN-23i 1N14 PB1 125.00 125.00 162.62 2.38 160.25 Pass-Major Risk ODSN-23i-aDSN-23i PB2-ODSN-23i IN14 PB2 125.00 125.00 162.62 2.38 160.25 Pass-Major Risk ODSN-24-OD5N-24 KE5-ODSN-24 KE5 wp04 273.67 275.00 169.62 4.96 164.67 Pass-Major Risk ODSN-25-ODSN-25-ODSN-25 KE1 199.99 200.00 28.42 3.66 24.76 Pass-Major Risk ODSN-25-ODSN-29 PB1-ODSN-25 PB1 199.99 200.00 28.42 3.66 24.76 Pass-Major Risk ODSN-25-ODSN-25 PB2-ODSN-25 KE1 PB2 199.99 200.00 28.42 3.66 24.76 Pass-Major Risk ODSN-25-ODSN-25 PB3-ODSN-25 KE1 PB3 199.99 200.00 28.42 3.66 24.76 Pass-Major Risk ODSN-25-ODSN-25 PB4-ODSN-25 KE1 PB4 199.99 200.00 28.42 3.66 24.76 Pass-Major Risk ODSN-26i-ODSN-26 KE2 PB2-ODSN-26 KE2 P 299.99 300.00 21.67 5.60 16.07 Pass-Major Risk ODSN-26i-ODSN-26i KE2-ODSN-26i KE2 299.99 300.00 21.67 5.60 16.07 Pass-Major Risk ODSN-26i-ODSN-26i KE2 PB1 -ODSN-26i KE2 299.99 300.00 21.67 5.60 16.07 Pass-Major Risk ODSN-27i-ODSN-27i IN4-ODSN-27i IN4 449.78 450.00 12.56 8.01 4.56 Pass-Major Risk ODSN-27i-ODSN-27i IN4-ODSN-27i IN4 wp 15 449.78 450.00 12.56 7.82 4.75 Pass-Major Risk 7/30/2012 3:43:32PM Page 3 of 5 COMPASS 2003.16 Build 42 Pioneer Natural Resources Anticollision Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-29-Slot ODS-29 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site Error: 0.00ft North Reference: True Reference Well: ODSN-29 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 2.00 sigma Reference Wellbore ODSN-29 PN5 Database: EDM_Alaska Reference Design: ODSN-29 PN5 wp02 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-CEo Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Oooguruk Drill Site ODSN-28-ODSN-28 PN3-ODSN-28 PN3 wp08 424.99 425.00 8.04 7.39 0.65 Pass-Major Risk ODSN-30-ODSN-30 PS5-ODSN-30 PS5 wp02 374.96 375.00 7.33 6.56 0.78 Pass-Major Risk ODSN-31 -ODSN-31 -ODSN-31 PN6 Surveys 524.39 525.00 25.39 8.94 16.47 Pass-Major Risk ODSN-31 -ODSN-31 PB1 -ODSN-31PB1 PN6 Si 524.39 525.00 25.39 9.03 16.38 Pass-Major Risk ODSN-32i-ODSN-32i IN7-ODSN-32i IN7 Surve, 549.83 550.00 35.44 9.71 25.73 Pass-Major Risk ODSN-32i-ODSN-32iPB1 IN7-ODSN-32iPB1 IN 549.83 550.00 35.44 9.71 25.73 Pass-Major Risk ODSN-34i-ODSN-34 IN9-ODSN-34i IN9 Survey 549.29 550.00 47.59 9.42 38.18 Pass-Major Risk ODSN-34i-ODSN-34i PB2-ODSN-34iPB2 IN9 549.29 550.00 47.59 9.42 38.18 Pass-Major Risk ODSN-34i-ODSN-34i PB3-ODSN-34iPB3 IN9 549.29 550.00 47.59 9.42 38.18 Pass-Major Risk ODSN-34i-ODSN-34iPB1 -ODSN-34iPB1 IN9 549.711 550.00 47.59 9.42 38.18 Pass-Major Risk ODSN-36-ODSN-36 L1 -ODSN-36 L1 wp01 697.82 700.00 56.56 11.89 44.69 Pass-Major Risk ODSN-36-ODSN-36 PB1 -ODSN-36 PB1 PN10 697.82 700.00 56.56 11.89 44.69 Pass-Major Risk ODSN-36-ODSN-36 PB2-ODSN-36 PB2 PN10 697.82 700.00 56.56 11.89 44.69 Pass-Major Risk ODSN-36-ODSN-36 PN10-ODSN-36 PN10 Sur 697.62 700.00 56.56 11.89 44.69 Pass-Major Risk ODSN-37-ODSN-37-ODSN-37 PN8 573.7E 575.00 79.12 9.86 69.26 Pass-Major Risk ODSN-37-ODSN-37 L1 -ODSN-37 L1 wp01 573.78 575.00 79.12 9.86 69.26 Pass-Major Risk ODSN-3i-ODSN-3i IN4 ext-ODSN-3i IN4 wp02 324.43 325.00 35.86 6.03 29.83 Pass-Major Risk ODSN-4-ODSN-4 PN5 ext-ODSN-4 PN5 aY1 wp 275.00 275.00 33.62 4.92 28.70 Pass-Major Risk ODSN-40-ODSN-40 PN12-ODSN-40 PN12 Sur 598.30 600.00 103.40 10.73 92.67 Pass-Major Risk ODSN-40-ODSN-40PB1 PN12-OCISN-4OPB1 P 598.30 600.00 103.40 10.73 92.67 Pass-Major Risk ODSN-40-ODSN-40PB2 PN12-CDSN-40PB2 P 598.30 600.00 103.40 10.82 92.58 Pass-Major Risk ODSN-43-ODSN-43 PS15-ODSN-43 PS15 wp0 476.00 475.00 133.27 8.13 125.15 Pass-Major Risk ODSN-48-ODSN-48i IS16-ODSN-48i IS16 wp0: 225.00 225.00 166.19 4.22 161.98 Pass-Major Risk ODSN-5i-ODSN-5i IS3-ODSN-5i IS3 wp09 299.88 30(.00 32.82 5.64 27.19 Pass-Major Risk ODSN-6-ODSN-6 PS4-ODSN-6 PS4 wp01 324.47 325.00 33.66 5.73 27.93 Pass-Major Risk ODSN-8-ODSN-8 FIS8-ODSN-8 PS8 wp08-8K 349.11 350.00 46.30 6.35 39.95 Pass-Major Risk j,` ODSN-9i-ODSN-9i IS9-ODSN-9i IS9 wp11-8K 349.12 350.00 51.54 7.03 44.51 Pass-Major Risk ODST-39-OD3N-39i IN11-ODSN-39i!Nil 623.64 625.00 97.53 11.34 86.20 Pass-Major Risk ODST-39-ODST-39 Torok D-ODST-39 Torok D 623.61 625.00 97.53 11.42 86.11 Pass-Major Risk ODST-39-ODST-39 Torok D PB1 -ODST-39 Tor 623.61 625.00 97.53 11.42 86.11 Pass-Major Risk ODST-45-ODSN-45i PB1 IN13-ODSN-45i PB1 425.98 425.00 147.55 7.79 139.77 Pass-Major Risk ODST-45-ODST-45A-ODST-45A Surveys 425.98 425.00 147.55 7.79 139.77 Pass-Major Risk O fST-46i-ODST-46i-ODST-46i Torok C 174.98 175.00 152.93 3.21 149.72 Pass-Major Risk ODST-46i-ODST-46i PB1 -ODST-46i Torok C P 174.98 175.00 152.93 3.21 149.72 Pass-Major Risk ODST-46i-ODST-46i PB2-ODST-46i Torok C P 174.98 175.00 152.93 3.21 149.72 Pass-Major Risk ODST-46i-ODST-46i Torok C PB3-ODST-46i P 174.98 175.00 152.93 3.21 149.72 Pass-Major Risk ODST-47-ODST-47-ODST-47 wp09.a 350.44 350.00 159.49 6.32 153.17 Pass-Major Risk 7/30/2012 3:43:32PM Page 4 of 5 COMPASS 2003.16 Build 42 z 10 — _ic tfr �=: ;AD A . I -"' ...1 p.4.44c.* • 1 1 1-!.., i � 1 Z �,� •jWa. ; NO `- z . i CO ArzIul l / o Ocs VA.\ It\I sibieg. ° 0 o cis O O , 0 r ° !f O r 0 ° tr c a Y 0 °. + " :t o 41, s ^x ° • 15 7 O18's « s v 0 a, `• " z o �'Y W F0 ° O 0 d A, • m r • • AA q _, c ` o 436 A, o 0 OA • ° s, 0 di o ° Y oe o n 0 rr ° �� �-` o • _ �m •I 1N -°^ ' 1 oN W O ' rg oz —0 to Is S3- 2 0< . i I • wADIstrict iBoumdry ( 1 / ; I SE Corner of -I \ 1 4. "~ RUK SIIE Protracted Section 11 ¢ 40' n 7 t a n t 14 >r� Coordinates al 4 N 6028111.04 P: i i\ E 70989.01 ` I • P�25 I \ Ref. AK BLM ' ! . ' �i •• `\ f Harrison Bay Tract "A" '��24\•q, f_ .LReCard Prawi(ig n a a� �l• .s0. I z a 11� 4. • .\ {y r.-- _r x� lofh lwood=S99 \• "-� Q' . shw'1 LI . eo to Doogurole Sits 1s a a ao� N. :/ aa 'St • . \ ! .• v / PI-15 r '� _a. ♦% pi. n Road. to Lob r Iia.,=/ Ph. g 1P-19 -.: s it �y1. 1 Pier - BU.� - ,..a,6. .t' a r'� Basis of Location DS-3H West Monument 24. ',R • , 34_ Coordinates Abell II N 6001016.61 •` �'�. I n a'z'1 E 498081.23 STAKED PI INFORMATION ONLY p �' ` '' r Y i U Q b :. : �' ,. Ref. Lownsbury & Assoc. D - < Drawing No. cc= -----"r NSK 6.01-d672 i1P��G- OF 44.44%11 '�.......,. s, ��ij, -- ir......6tsr ,% r flip G.Davis Je • iPl No.41145 . '`' Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 East DATE: 7-12-07 Umiat Meridian NANUQ JOB NO. SHEET DESCRIPTION: Basis of Location 05204 2 of 4 - Alaska State Plane -----,-$-e l4nLine 4 f _. . __- Well No, x Latitude (M Longitude (W) --FSL FEL Pad Lev, 1 6,001,151.32 469,920,45 7019'46724160 15-0-14 446466 -3035 1077 13,50 2 -6,031;7[4:67:35--46-9;91-5.52 29 6,1X252--150114 45,609 3030 1082 13,50 6,031,141,39 469, _ 910.59 --7-0-2R0:1-4354 46;14354 15014 .45,75375 -3025 1087 13,50 4 6,031,1 36.46 469,905 67 70 29 46 09485 15014 45 89799 3020 . 1092 13.50 5 6,031,131,45 469,900,74 • 70 29 46.04539-T50--14-46.,04252---3015 -1097---13,50 6 6,03'1,126 51 469,895,80 70 29 45_99660_ 15014 46,18735__3010 1102 13,50 - __-_-y__,0 _3, _-.�469,883,13 70 29 45,87039 T 5014.48.55879 2997 1115 13,50 7 6,031,113,73 6,031,108.73 469,878.21 70 29 45,62102 15014 46,70303 2992 1120 13.50 9 6,031,103.75 469,873,26 70 29 45.7/184 150 14 46.84814 2907 1125 13.50 106,031,098,79 469,868,36 70 29 45,72286 150 14 446,99179 2982 1130 13.50 --- 6,03),093.84-' 46030,3-9---n 29 46:67856-`-150-14.47,13750'- 2977 1135 13,5Q 12 0,031,088,87 469,858,47 70_29 45,62490 15014 47,28174 2972 1140 _ 13,50 ---T3----6,031,076,06---469,845,81 70 29 45.49840 15014 47.65258 2960 1152 13,50 14_ 6,031,071,09 -469, 469,840,81 70 29 45.4493215014_ 47.797702955 1157 s 13,50_m -15 6,031,066.15 -469,835,96 _. 70 29 15.40053 `150 1447.94165_47,94165-2950-116-2 13-.50-- 16 6,031,061.16 469,831,04 70 29 45.35145 15014 4808568 2945 1167 13.50 17 6,031,056.25 469,826,11 70 29 45,30277 150-14 48,23042 2940 1172 13,50 18 6,031,051.2/--459,02-17i8 _-70 a-46726159 150-W4673-7415---2-935 48,37495_-2935 1177 13,50_ 19 6,031,038.52 469,808,50 70 29 45.12765 150 48,74668 2922 1189 13,50 20 6,031,033,50 469,803.59 70 29 45.07811 15014 48,89061 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 1501449,18144 2907 _ 1204 13,50 23 6:0-31,018,57.018,57-469,758,76 70 2944,93067 -150 14 49,32537 2902 1209 13,50 24 6,031,013.60 469,783,84 70 29 44,88159 150 14 49,46960 289 1214 13,50 11, ..••••-•.. 4s'�ti �►ca '•fi Philip G.Dave o/-4-1 - a f�sj�ti•• No.4110.5 •••P-i a Ase '' 1f Notes: 1, Elevotiens ore bosed on 8P Mean Seo Level. 2. Coordinates ore bosed on Alaska State Plane Nod 27, Zone 4, 3, All conductors ore within Protracted Section 11. Pioneer Netur-el Reapuoes JOB NAME: Qooguruk Drill Site Conductors DRAWN BY: 9L CHECKED BY: MJ0 LOCATION: Protracted Section 11 SCALE: N/A Township 13 North z Rance 7 cost DATE; 7-12-07 Umiot Meridian _ __ __�__ NANUQ JOB NO. SHEET DESCRIPTION: As-built coordinates 05204 3 of 4 Alaska State Plane Section Line Offset Well No. X Latitude (N) Longitude (W) FSL FEL Pad Elev. 25 6,031,128.32 469,943.64 _ 70 29 46.01630 150 14 44.77930 3013 1055 13.50 26 6,031,123.35 469,938.69 70 29 45.96722 150 14 44.92442 3008 1060 13.50 27 6,031,118.33 469,933.76 70 29 45.91765 150 14 45.06895 300 3 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 6,030,995.50 469,811.9870 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 OfASURVEYOR'S CERTIFICATE ��•...... 4 11 "4"* 1 • I HEREBY CERTIFY THAT I AM v / 4 •�17 PROPERLY REGISTERED AND °I*,14. / '" %. 0 LICENSED TO PRACTICE LAND j'°' Ti "'° i SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT �` _ `J-A, • ilii G.Davis 7/ REPRESENTS A SURVEY DONE BY `o s'► No.4110-5 :��i ME OR UNDER MY SUPERVISION r f fF9 '• ,. 5oQ AND THAT I BELIEVE THAT ALL 1 o' ......1,c,‘' r' ' DIMENSIONS AND OTHER DETAILS 5 ' a �*��� � + ARE CORRECT AS SUBMITTED TO `�:'% ME BY NANUQ, INC. AS OF JULY 12TH, 2007. Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD, LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 East DATE: 7-12-07 Umiat Meridian NANUQ JOB NO. SHEET DESCRIPTION: As-built Coordinates 05204 4 of 4 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. TRANSMITTAL LETTER CHECKLIST WELL NAME (---206+) PTD# 2 J 2_ l�� Development Service Exploratory Stratigraphic Test Non-Conventional Well / FIELD: 'L� r G i POOL: O C.0 V C��l� - Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/ inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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No special effort has been made to chronologically organize this category of information. Technical Report Title Date Client: Pioneer Natural Resources Field: Oooguruk Development Rig: Nabors 19AC Date: December 8, 2012 Surface Data Logging End of Well Report ODSN-29 ODSN-29 PB1 ODSN-29 PB2 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 GENERAL WELL INFORMATION Company: Pioneer Natural Resources AK Rig: Nabors 19AC Well: ODSN-29, ODSN-29 PB1, & ODSN-29 PB2 Field: Oooguruk Borough: North Slope Borough State: Alaska Country: United States API Number: 50-703-20661-00-00 (ODSN-29) 50-703-20661-70-00 (ODSN-29 PB1) 50-703-20661-71-00 (ODSN-29 PB2) Sperry Job Number: AK-AM-0009650310 Job Start Date: 16 Oct 2012 Spud Date: 15 Oct 2012 Total Depth: 15716’ MD, 6429’ TVD North Reference: True Declination: 20.189 Dip Angle: 80.988 Total Field Strength: 57607 nT Date Of Magnetic Data: 20 Aug 2012 Wellhead Coordinates N: North 70° 29’ 44.71” Wellhead Coordinates W: West 150° 14’ 48.64“ Drill Floor Elevation 56.2’ Ground Elevation: 13.5’ Permanent Datum: Mean Sea Level SDL Engineers: David Mckechnie, Jessica Munsell, Andrew Bongard, Timothy Collins Todd Wilson, Kerry Garner Company Geologist: England Flecther, Paul Cozma Mindaugas Kuzminskas, James Stewart Company Representatives: Rod Klepzig, Joey Cortez, Joe Polya, Jerry Haberthur SSDS Unit Number: 123 DAILY SUMMARY 10/16/2012 SDL arrived on location to rig up equipment. Personnel calibrated gas equipment and installed a new CVE pump and panel. Began drilling 14.5" surface interval from 537' to 2,152'. Trip in hole with gyro every stand to 815'. Pumped 55 bbl Hi-vis sweep at 1,771'- minimal increase in cuttings. Gas: The max gas was 47 units. Fluids: Lost 68 barrels down hole. Geology: No samples taken during surface hole section. 10/17/2012 Rotary drilling and sliding to 2,437’ pump a 40 bbl hi vis sweep. Circulate two bottoms up and begin tripping out of hole to BHA, laid down and clean BHA. Change motor bend to 1.5 degrees, pick-up BHA #2. Download MWD change-out pulser. Trip in hole shallow test MWD and continued trip in hole to 1,880'. Ream and wash to 2,437'. Drilling and sliding to 3,300' at midnight. Gas: The max gas was 47 units. Fluids: No losses. Geology: No samples taken during surface hole section. 10/18/2012 Rotary drilling and sliding to 4,145’ pump 40 bbl pill and chase with carbide pill. Pumped 60 bbl Hi Vis sweep no increase in cuttings upon return. Carbide pill back 1800 strokes early, pump second carbide pill with same result. Trip out of hole to 2,537' tight spots notice begin back reaming to 2,492'. Trip out of hole on elevators laid down BHA, download MWD tool and clean rig floor. Rig-up to run 11.75" casing at midnight. Gas: The max gas was 132 units. Fluids: No losses. Geology: No samples taken during surface hole section. 10/19/2012 Rig-up to run 11 3/4" casing with Tesco tool. Begin tripping in hole with casing to 790'. Casing was worked past the ledge and tripped into the hole to 2,533'. Step pumps to 12 bpm. Casing was washed, rotated and worked to 2,536'. Casing would not go past 2,536'. A dry job was pumped. Tripped out of the hole with 11 3/4" casing to 727' at midnight. Gas: The max gas was 54 units. Fluids: Lost 62 barrels down hole. Geology: No geology. 10/20/2012 11 ¾’ casing was tripped out of the hole and laid down. BHA#3 was picked up. MWD Shallow Tested. Drill string was tripped into the hole to 2,536', washed and reamed to 4,145'. Fluid was circulated to condition the hole. A carbide pill was pumped at 4,055' and chased with a 90 bbl SAPP pill. The SAPP was chased with a 60 bbl high viscosity sweep. The carbide came back 1,682 strokes early with a 20% increase in cuttings upon sweep return. A second carbide pill was pumped at 3,960' and chased a with 60 bbl high viscosity sweep. The carbide came back 1,753 strokes early with a 5% increase in cuttings upon sweep return. A dry job was pumped and the drill string was tripped out of the hole, wiping tight spots to 3,420'. Drill string was tripped back into the hole to 3,774' and was back reamed out from 3,774' to 3,410'. Gas: The max gas was 103 units. Fluids: Lost 12 barrels down hole. Geology: No geology. 10/21/2012 Backream to 3,410'. Pump 60 bbl Hi Vis sweep. Backream to 2,442'. Circulate one bottoms-up. Backream to 2,061'. Circulate two bottoms-up. Backream to 1,870'. Trip out on elevator to BHA. Lay down BHA. Rig-up to run casing. Run in hole with 11 3/4" casing to 1,988'. Step pumps to 8 bpm. Circulate two bottoms-up. Run in hole with casing to 2,715'. Break circulation. Step pumps to 4 bpm. Run in hole to 3,119'. Break circulation. Step pumps to 6.5 bpm. Run in hole with casing to 3,278' at report time. Gas: The max gas was 50 units. Fluids: Lost 25 barrels down hole. Geology: No geology. 10/22/2012 Run in hole to 4,139' with casing. Make-up landing joint and hanger. Pump carbide pill- came up 489 strokes early (14.05" hole). Rig down Tesco. Rig-up Halliburton cement head and lines. Stage pumps to 60 strokes/834 psi. Pump cement per Halliburton program. Lost returns at 65 bbls pumped. Good returns at 100 bbls pumped. Bumped plug on calculated strokes. Monitored well for 30 minutes. Rig down cement head. Nipple down, nipple up BOPs. Testing BOPs at report time. Gas: The max gas was 55 units. Fluids: No losses seen. Geology: No geology. 10/23/2012 Test BOPS. Trip in hole with BHA #4 Clean Out Assembly. Trip in hole while picking up 5" drill pipe to 4,030'. Ream and wash/tag cement stringers at 4,050'. Circulate bottoms-up. Pressure test casing shoe at 4,045' to 3500 psi. Drill cement/shoe track and rat hole to 4,145'. Displace to 10.55 ppg MOBM. Drill to 4,165'. Circulate bottoms-up. Perform FIT to 12.5 ppg EMW. Pump slug. Trip out of hole. Lay down BHA at report time. Gas: The max gas was 56 units. Fluids: No losses seen Geology: No geology. 10/24/2012 Lay down BHA #4. Pick-up Geo-Pilot/MWD BHA #5 with Weatherford Rip Tide Under-reamer. Trip in hole. Shallow test MWD. Trip in hole to 3,029. Shallow test MWD. Break in Geo-Pilot. Trip in hole to 4,074'. Wash down to 4,165'. Drill ahead to 4,225'. Activate reamer per Weatherford representative. Drill ahead at 100 ft/hr to 5,045' at report time. Gas: The max gas was 193 units. Fluids: No losses seen. Geology: 90% Shale; 10% Tuff 10/25/2012 Drilling continued ahead from 5000’ to 5999’MD. Circulated and reciprocated while servicing a rig pump, then drilled ahead to 6420’MD. Gas: The max gas was 363 units. Fluids: No losses seen. Geology: 80% Shale; 20% Tuff. 10/26/2012 Drilling continued to TD of the 1st intermediate section at 7270’MD, 5527’TVD. The bit was off bottom at 16:49hrs. A sixty barrel sweep yielded an over 100% increase in cuttings. A high viscosity sweep was then pumped with a 15% increase in returns. Gas: The max gas was 363 units. Fluids: Lost 48 barrels down hole. Geology: 90% Shale; 10% Tuff. 10/27/2012 Commenced tripping out of the hole to just past the shoe then tripped back in for a wiper run. A sweep was pumped that came back 500 strokes early with over 300% increases in cuttings. Gas: The max gas was 186 units. Fluids: Lost 171 barrels down hole. Geology: 90% Shale; 10% Tuff. 10/28/2012 Tripped out of the hole to 4580’ and pumped a high viscosity sweep at 08:41hrs. The sweep came back right on time with a 100% increase in cuttings. Tripping out of the hole re-commenced. Gas: The max gas was 33 units. Fluids: Lost 54 barrels down hole. Geology: 90% Shale; 10% Tuff. 10/29/2012 Rigged up for casing of 1st intermediate section with 9 5/8” Hydril 521 40#L-80 Liner. Casing was ran to 3333’MD. From then on the casing was ran using 5” drill pipe to 4053’ where the stage pumps were set to pump at 4 barrels/minute due to partial returns. 60-70% losses experienced while pumping. 20 rotations/minute commenced as casing was ran into the hole to 7237’. Gas: The max gas was 19 units. Fluids: Lost 603 barrels down hole. Geology: 90% Shale; 10% Tuff. 10/30/2012 The WTF ball was pumped down and seated in 1847 strokes. Cement was pumped and was chased with 10.6 lbs/gal MOBM. Pressure test was performed at 3500 psi for 5 minutes. Packer was set. A bottoms up was circulated and drill string was tripped out of the hole. The BHA was laid down and preparations were made to test the BOPs. Gas: The max gas was 71 units. Fluids: Lost 103 barrels down hole. Geology: 90% Shale; 10% Tuff. 10/31/2012 The BOPs were tested. Drill string was tripped into the hole to test the casing and to drill the rat hole. The casing tested at 3500 psi. Cement, shoe track and rat hole were drilled. Rat hole stopped at 7270’. The 10.6 lb/gallon ENVIROMUL mud was displaced with 10.2 lb/gallon LSND mud. Drilling continued to 7290’ where a bottoms up was circulated and a FIT test was performed to 13.5 lb/gallon. After the pipe was slugged, it was tripped out of the hole with an 8.5’ Clean-out BHA. Gas: The max gas was 59 units. Fluids: No losses seen. Geology: 90% Shale; 10% Tuff. 11/1/2012 MPD equipment was tested and drilling of the second intermediate section began at 7290’MD. Heavy fluid losses began at approximately 7353’MD. Drilling continued to 7365’ Gas: The max gas was 283 units. Fluids: Lost 334 barrels down hole. Geology: 90% Shale; 10% Tuff. 11/2/2012 Drilling of 2nd intermediate section continued with heavy losses. A 55 barrel LCM Pill was pumped and the drill string was tripped out of the hole to 7233’ where the MPD was used to sqeeze the LCM into the formation. Drilling commenced to a depth of 8279’. Gas: The max gas was 1170 units. Fluids: Lost 597 barrels down hole. Geology: 90% Shale; 10% Tuff. 11/3/2012 Drilling of 2nd intermediate section continued with heavy losses beginning at 00:30, 8280’MD. Drilling continued to 8321’, where an LCM Pill was pumped. The drill string was then tripped back to the shoe where MPD squeezed the pill into the formation, slowing losses. The drill string was then tripped back to the bottom of the hole where drilling continued to 8552’ with losses ranging from 70 to 129 barrels per hour. Eleven Geotaps were attempted from 8470’ to 8392’MD. Nine were successful. Drilling of 2nd intermediate section continued to 8556’MD. Gas: The max gas was 2232 units. Fluids: Lost 1540 barrels down hole. Geology: 90% Shale; 10% Siltstone. 11/4/2012 Continue drilling the 2nd intermediate from 8556’MD to 9612’MD with average losses of 50 barrels per hour. Gas: The max gas was 238 units. Fluids: Lost 1222 barrels down hole. Geology: 70% Shale; 30% Siltstone. 11/5/2012 TD intermediate 2 at 9774’MD circulated high viscosity sweep with minimal increase in returns. Circulated three bottoms up, and begin pulling out of hole and packed off at 8706’. Increased pump rate and back reamed from 8706’ to 8390’. Performed Madd Pass from 8390’ to 8228’, packed off again and began back reaming. Gas: The max gas was 238 units. Fluids: Lost 1220 barrels down hole. Geology: 90% Siltstone; 10% Shale. 11/6/2012 The Reamer was cycled. The hole was back reamed from 8370’ to 8279’, 25’ above the loss zone. A 2:1 DOB2C pill was pumped and chased with mud. Three bottoms up were circulated with no losses at the beginning but 35 barrels/hour by the finish. The drill string was pulled out of the hole to 7708’, pumping 2.36 barrels per stand. Three more bottoms ups were circulated and pulled out of the hole to 7233 with losses of 35 barrels per hour with MPD holding 12.8 lbs/gallon. Drill string was tripped back into the hole to 7601’ then washing and reaming to 8565’, pumping 600 gallons/min and rotating at 80 rpm. 35 barrel per hour losses still occurring. The drill string was tripped out of the hole to 7233’ with MPD maintaining 12.8 lbs/gallon and experiencing 20-60 barrels per hour. Gas: The max gas was 1160 units. Fluids: Lost 969 barrels down hole. Geology: 90% Siltstone; 10% Shale. 11/7/2012 Second DOB2C Pill was prepared. The drill string was tripped into the hole to 8300’MD. The pill was pumped and then chased with mud. The drill string was tripped out of the hole from 8300’ to 7740’ and three bottoms up were circulated. The drill string was tripped out to 7233’ where issues with MPD pumps led to the use of the cement pump for MPD purposes unit repairs could be complete. Drill string was tripped back into the hole, washing and reaming, to 8565’ with intermittent tight spots and pumping 600 gallons per minute and rotating at 80 rotations per minute. The tripping into the hole continued to 8941’, pumping at 500 gallons per minute and 80 rotations per minute. The trip in continued to 9774’ without pumping and rotation at 30 rotations per minute. Circulated 50 barrels of high viscosity sweep. Only losses experiences were seepage losses. Gas: The max gas was 2177 units. Fluids: Lost 390 barrels down hole. Geology: 90% Siltstone; 10% Shale. 11/8/2012 A sweep was pumped that yielded no increases. Three bottoms up were circulated. The pumps were cycled for the reamer. The drill string was tripped into the hole to 9774’. A 50 barrel high viscosity sweep was pumped that yielded slight increases. The well was displaced to 12.0 pounds per gallon LSND with added NXS-LUBE. Drill string was tripped out of the hole while lubricating from 9774’ to 7238, then tripped out without lubricating from 7238’ to 3924’. Preparations were made to displace with 13.5 pounds per gallon mud. Gas: The max gas was 642 units. Fluids: Lost 234 barrels down hole. Geology: 90% Siltstone; 10% Shale. 11/9/2012 56 barrels of high viscosity, 13.5 pounds per gallon Pill was spotted and chased with 50 barrels of 13.5 pounds per gallon LSND. The drill string was tripped out of the hole to 3498’ and the 13.5 pounds per gallon LSND was displaced. There was a total loss of 6 barrels to the hole during displacement. The drill string was tripped out of the hole and the BHA was laid down. Preparations to run 7” casing were made and the casing run began at approximately 19:00 hours. Gas: No gas data. Fluids: Lost 241 barrels down hole. Geology: 90% Siltstone; 10% Shale 11/10/2012 The running of the 7” 26# casing continued from 3444’ to 9759’, where it was landed. The casing was filled with 11.2 pounds per gallon LDSN. The laying down of the heavy weight pipe began. Gas: No gas data. Fluids: No losses seen. Geology: 90% Siltstone; 10% Shale. 11/11/2012 The remainder of the 5” drill pipe was laid down into the mouse hole and over 2 barrels of 11.2 pound per gallon LSND was put into the 11 ¾” by 7” annulus every 30 minutes. An additional 100 barrels of 11.2 pounds per gallon LSND were bullheaded down the annulus. The top rams were changed to 2 7/8” by 5” VBR’s. There was a safety stand down. Gas: No gas data. Fluids: No losses seen. Geology: 90% Siltstone; 10% Shale. 11/12/2012 Safety Stand down. Gas: No gas data. Fluids: No losses seen. Geology: 90% Siltstone; 10% Shale. 11/13/2012 Safety Stand down until approximately 18:00. A BOP test was performed. Gas: No gas data. Fluids: No losses seen. Geology: 90% Siltstone; 10% Shale. 11/14/2012 Safety Stand down until approximately 03:00. Picked up BHA and stage on rig. Pick up and run in hole with 105 joint of 4 inch drill pipe. Flush top of hole. Pressure test 7 inch casing shoe to 3,500 psi for 30 minutes. Pick up clean out BHA. Trip in hole while picking up 4 inch drill pipe to 9,055’. Trip in hole on stands to 9,473’ MD. Gas: The max gas was 8 units. Fluids: No losses seen. Geology: No geology. 11/15/2012 Trip in hole to 9,503’. Tag cement stringers. Ream and wash from 9,503’ to 9,634’. Downtime for top drive PLC communication problem. Circulate at 0.5 barrels per minute. Troubleshoot top drive PLC. Repair bad cable. Drill cement and float to 9,774’. Circulate bottoms up three times. Shakers clean. Monitor well for 10 minutes. Pump dry job. Trip out of hole to 2,900’ MD. Gas: The max gas was 29 units. Fluids: No losses seen. Geology: No geology. 11/16/2012 Trip out of hole to clean BHA. Lay down BHA . Pick up BHA number 9 and trip in hole. Shallow test MWD. Trip in hole to 9,746’. Cut and slip drill line. Pull trip nipple. Install MPD RCD bearing. Pump 40 barrels Hi Vis MOBM spacer. Displace active system to 7.65 ppg Environmul. Dump spacer on return to surface. Dump 15 barrels of WBM / MOBM interface. Drill to 9,774’. Perform F.I.T. 12.5 ppg EMW. Rotary and slide drilling to 9,987’ MD, holding 9.8 ppg EMW with MPD. Gas: The max gas was 270 units. Fluids: No losses seen. Geology: 50% Sand; 30% Siltstone; 20% Shale 11/17/2012 Rotary drilling and sliding to 10,227’ holding 9.85 ppg EMW with MPD. Perform Static Pore Pressure test with MPD. Pore pressure = 9.5 ppg EMW. Drilling and sliding to 10,665’ holding 9.85 EMW with MPD at report time. MADD pass all slide areas. Gas: The max gas was 846 units. Fluids: No losses seen. Geology: 60% Sand; 40% Siltstone 11/18/2012 Rotary drilling at 150’ per hour and sliding to 11,672’ holding 9.9 EMW with MPD. MAD pass all slide areas. Gas: The max gas was 926 units. Fluids: No losses seen. Geology: 30% Sand; 70% Siltstone 11/19/2012 Rotary drilling and sliding to 12,269’ holding 10.0 ppg EMW with MPD. Repair wash out in rig bleed off line. Drill to 12,387’. Circulate while Geologist reviews hole data. Drill ahead to 12,464’. Pack off. Circulate and condition hole. Attempt to clean up hole. No go. Trip out of hole to 11,900’. Decision was made to open hole sidetrack. Trough at 11,931’ MD Gas: The max gas was 1440 units. Fluids: No losses seen. Geology: 20% Sand; 80% Siltstone 11/20/2012 Time drilling and sliding to 11,961’, holding 10.0 EMW with MPD. Rotary drilling to 12,250’ at 150 feet per hour. Check trip to side track point at 11,900’. Trip in hole to 12,250’. Rotary drill and slide to 12,346’ at 150’ per hour. Gas: The max gas was 2151 units. Fluids: No losses seen. Geology: 20% Sand; 80% Siltstone 11/21/2012 Rotary drilling and sliding to 12,469’. MADD Pass all slide areas. Change out MPC RCD bearing. Drill and slide to 12,800’ MD. Gas: The max gas was 2141 units. Fluids: No losses seen. Geology: 30% Sand; 70% Siltstone 11/22/2012 Rotary drilling and sliding to 13,763’ holding 9.8 ppg EMW at shoe with MPD. Gas: The max gas was 883 units. Fluids: No losses seen. Geology: 20% Sand; 80% Siltstone 11/23/2012 Rotary drilling and sliding to 13,887’ holding 9.8 ppg EMW at shoe with MPD. Change out MPD RCD bearing. Rotary time drill and slide to 14,358’ MD, holding 9.8 ppg EMW at shoe with MPD. Gas: The max gas was 896 units. Fluids: No losses seen. Geology: 20% Sand; 80% Siltstone 11/24/2012 Rotary drilling and sliding to 14,404’ holding 9.8 ppg EMW at shoe with MPD. Working thru multiple intermittent pack offs. Circulate bottoms up 4 times with intermittent pack offs. Drill to 14,464’. Pack off & lost circulation. Stage pumps and rotate to full rate. Trip out of hole to 13,374’. Tight from 14,394’ to 13,500’. Circulate bottoms up. Change out MPD RCD bearing. Gas: The max gas was 6458 units. Fluids: No losses seen. Geology: 20% Sand; 80% Siltstone 11/25/2012 Change out MPD RCD bearing. Change out Saver sub. Trip out of hole to 13,117’ and circulate. Trip in hole and begin open hole troughing sidetrack number 2 from 13,130’ to 13,160’. Time drill and slide to 13,300’ MD. Gas: The max gas was 295 units. Fluids: No losses seen. Geology: 20% Sand; 80% Siltstone 11/26/2012 Time drilling and sliding to 13,309’. MAD pass slide areas. Time drilling and sliding to 13,330’. Circulate bottoms up. Pump 18 barrels 10.0 ppg Hi Vis spacer. Chase with 10.0 ppg KWM. Pump out to 9,746’. Displace active system from 7.9 ppg MOBM to 10.0 ppg KWM. Remove RCD bearing. Install trip nipple. Pump out of hole to 6,857’. Pump slug and trip out of hole, laying down bad 4” drill pipe. Trip out of hole to BHA. Remove nukes. Gas: The max gas was 284 units. Fluids: No losses seen. Geology: 20% Sand; 80% Siltstone 11/27/2012 Lay down BHA #9. Pick up drill pipe to 2,112’. Circulate 1.5 times drill pipe volume. Trip out of hole and rack back stands. Remove wear bushing. Test BOP’s. Bottom ram door test failed. Change out seal. Retest same. Good test. Install wear bushing. Rig down test equipment. Pick up drill pipe to 1,163’. Rack back stands. Pick up BHA #10 and run in hole. Shallow test MWD. Gas: No gas data. Fluids: No losses seen. Geology: 20% Sand; 80% Siltstone 11/28/2012 Trip in hole to 9,746’. Slip and cut drill line. Install MPD RCD bearing. Pump 18 barrels of 10.0 ppg Hi Vis spacer. Chase and displace active system to 7.9 ppg MOBM. Trip in hole to 11,900’. Circulate bottoms up. Trip in hole to 13,110’. Perform directional check shots. MADD PASS from 12,775’ to 12,268’ and 13,190’ to 13,110’. Time slide drilling at report time to 13,334’. Gas: The max gas was 838 units. Fluids: Lost 50 barrels down hole. Geology: 20% Sand; 80% Siltstone 11/29/2012 Continue drilling 6 1/8" Production Lateral. Time drill from 13,333' to 13,368'. Directional drill from 13,368' MD to 13,488' MD. Gas: The max gas was 285 units. Fluids: No losses seen. Geology: 20% Sand; 80% Siltstone 11/30/2012 Continue drilling 6 1/8" Production Lateral. Directional drill from 13,480' to 13,774'. Trough from 13,774' to 14,458' maintaining 9.8 ppg EMW at shoe with MPD. MADD Pass all slide areas. Drill ahead. Gas: The max gas was 3481 units. Fluids: No losses seen. Geology: 90% Sand; 10% Siltstone 12/1/2012 Continue drilling 6 1/8" Production Lateral from 14,458' to 15,716' (TD). Circulate 2.5 times Open Hole volume. Change out MPD bearing. Maintaining 9.8 ppg EMW at shoe with MPD. Backream from 15,716' to 13,984'. EMW at 7" shoe increased to 10.1 ppg. Slight losses were encountered. Decreased EMW to 9.9 ppg. Continue to backream to shoe at report time. Gas: The max gas was 2651 units. Fluids: Lost 15 barrels down hole. Geology: 100% Sand 12/2/2012 Finish back reaming from 13,984' to 9,746' running HIS log 240 gpm 50 rpm ( packed off at 11,820' ). Decreased EMW to 9.8 ppg while back reaming out of hole. Circulate bottoms ups. Change out swivel packing. Trip in hole at report time Gas: The max gas was 841 units. Fluids: No losses seen. Geology: 100% Sand 12/3/2012 Continue tripping in hole to TD at 15,716'. Break circulation and displace wellbore from 8.0 ppg ENVIROMUL to 10.0 ppg KWM ENVIROMUL (pumped 50 bbls Hi-Vis 10 ppg spacer). 10000 units gas while circulating bottoms up. MPD maintained 9.8 ppg EMW at shoe. Rig down MPD. Pull out of hole from 15,716' to 15,139'-swabbing. Pump out from 15,139' to 9,746' 3 bpm. Circulate bottoms up 2 times. Pull out of from 9,746' to 9,170'-swabbing. Circulate bottoms up. Pull out of hole from 9,170' to 6,664' -some swabbing. Circulate bottoms up. Pump out from 6,664' to 5,314' at 3 bpm. Pull out of hole from 5,314' to 3,677' at report time. Gas: The max gas was 10000 units. Fluids: Lost 35 barrels down hole. Geology: 100% Sand 12/4/2012 Pulled out of the hole from 3,677' to surface and laid down 6 1/8" BHA. Picked up and flushed 24 joints of 4" heavy weight drill pipe. Rigged up to run 4 1/2" Liner. Run in to 6,318' MD. Gas: No significant gas data. Fluids: Lost 6 barrels of down hole. Geology: No geology. 12/5/2012 Continued to run in the hole with 4 1/2" lower completion. Circulated bottoms up at 6,188' at 3 bbls per minute. Continued running in to 15706, filling pipe every 10 stands. Circulated, stepping up to 2 bbls per minute. Rigged up cement line and inflating ECP's (10 in total) with cement at report time. Gas: The max gas was 32 units. Fluids: Lost 26 barrels down hole. Geology: No geology. 12/6/2012 Rigged down Cement line. Set liner top packer. Test liner top packer/annulus. Displaced the well to 10.00 ppg brine. Slip and cut drill line. Pulled out of the hole and laid down 4" drill pipe and liner running tool. Rigged up to run 4 1/5" tubing. Run in the hole to 1415' MD. Gas: The max gas was 270 units. Fluids: No losses seen. Geology: No geology. 12/7/2012 Continued to run 4 1/2" tubing until the hanger was landed. Tested top and bottom hanger seals to 10,000 PSI for 30 minutes and tested tubing to 3500 PSI for 30 minutes. Lay down landing joint. Gas: No gas data. Fluids: No losses seen. Geology: No geology. 12/8/2012 Installed and tested BPV. Nippled down blow out preventer equipment. Nippled up and tested tree. Laid down 4" drill pipe. Rigged down gas equipment and prepare to move to ODSN-24. Gas: No gas data. Fluids: No losses seen. Geology: No geology. Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 0Avg: C3 C2 N/A % 24 hr Max YP AgNO3 N/A (lb/100ft 2) 3.144 N/A N/A 32 ASG David Mckechnie/ Andrew Bongard C5i C4i C5n Tuff 0 Grvl Coal Max: 2.0/91.8 MXL-1V 2152'16 9.45 9.40 65 100 Sst Silt Siltst Clyst Cht Gas Breakdown Sd Lst Sh Nabors 19AC N/A AK-AM-0009650310 14.5 0.700 cP PV Size NAP/Water N/A North Slope Daily Charges Avg 68.1 283.2 Pioneer Natural Resources ODSN-29 Oooguruk 1 10/16/2012 2,152' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 4.9 N/A N/A N/A Avg 605 143 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 1605 3.517 1,615' Drilling 14.5" Surface R. Klepzig / J. Cortez 47 2096' Flow In (gpm) Current Pump & Flow Data: N/A 8 2059' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 21 25.0 Depth Gas (units) H2S Data Sample Line Avg: 0 C1 Hole Condition On Bot Hrs 2152'N/A 24 hr Recap: Directionally drill 14.5" surface interval from 537' to 2,152'. Ran Gyro every stand to 815'. Pumped 55 bbl Hi-vis sweep at 1,771'- minimal increase in cuttings. Max Gas = 47 U , 68 bbls lost down hole PWD Drilling All Circ Avg Diam 10 bbls 14.500 Max: Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) PWD Drilling All Circ Avg Diam 10 bbls 14.500 Max: Hole Condition On Bot Hrs 3300'8.97 Depth Gas (units) H2S Data Sample Line Avg: 0 C1 19 2587' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 19 50.0 1148' Drilling 14.5" Surface R. Klepzig / J. Cortez 43 2648' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 2937 3.517 N/A N/A N/A Avg 803 190 Total Charges: Min Max Max THTS Cor Solids 6.8 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODSN-29 Oooguruk 2 10/17/2012 3300' North Slope Daily Charges Avg 57.0 271.3 N/A Nabors 19AC N/A AK-AM-0009650310 14.5 0.700 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 2.5/88.8 MXL-1V 3300'14 9.40 9.50 59 200 C5i C4i C5n Tuff 0 Grvl Coal Max: (lb/100ft 2) 2.682 N/A N/A 32 ASG N/A % 24 hr Max YP AgNO3 N/A 0Avg: C3 C2 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… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Rotary drilling and sliding to 2,437'. Pump 40 bbl hi vis sweep. Circulate two bottoms up. Trip out of hole to BHA. Lay down and clean BHA. Change motor bend to 1.5 degrees. Pick-up BHA #2. Download MWD. Change-out pulser. Trip in hole. Shallow test MWD. Trip in hole to 1,880'. Ream and wash to 2,437'. Drilling and sliding to 3,300' at midnight. Max Gas = 43 U , 0 bbls lost down hole David Mckechnie/ Andrew Bongard Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) PWD Drilling All Circ Avg Diam 10 bbls 14.500 Max: Hole Condition On Bot Hrs 4145'9.11 Depth Gas (units) H2S Data Sample Line Avg: 0 C1 46 3397' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 3 0.0 845' Run 11 3/4" Casing R. Klepzig / J. Cortez 132 4021' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 8 3.517 N/A N/A N/A Avg 0 0 Total Charges: Min Max Max THTS Cor Solids 8.1 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODSN-29 Oooguruk 3 10/18/2012 4145' North Slope Daily Charges Avg 38.2 341.5 N/A Nabors 19AC N/A AK-AM-0009650310 14.5 0.700 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 2.5/88.2 MXL-1V 4145'13 9.55 9.60 53 200 C5i C4i C5n Tuff 0 Grvl Coal Max: (lb/100ft 2) 2.624 N/A N/A 28 ASG N/A % 24 hr Max YP AgNO3 N/A 0Avg: C3 C2 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… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: R otary drilling and sliding to 4,145'. Pump 40 bbl pill. Chase with carbide pill. Chase with 60 bbl Hi Vis sweep. No increase in cuttings upon return. Carbide pill back 1800 strokes early. Pump second carbide pill. Same result. Trip out of hole to 2,537'. Tight. Backream to 2,492'. Trip out of hole on elevators. Lay down BHA. Download MWD. Clear rig floor. Rig-up to run 11.75" casing at midnight. Max Gas = 132 U , 0 bbls lost down hole David Mckechnie/ Andrew Bongard Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) 0Avg: C3 C2 N/A % 24 hr Max YP AgNO3 N/A (lb/100ft 2) 2.628 N/A N/A 26 ASG C5i C4i C5n Tuff 0 Grvl Coal Max: 2.0/89.5 4145'69.60 9.50 46 Sst Silt Siltst Clyst Cht Gas Breakdown Sd Lst Sh Nabors 19AC N/A AK-AM-0009650310 cP PV Size NAP/Water N/A North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODSN-29 Oooguruk 4 10/19/2012 4145' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 7.3 N/A N/A N/A Avg 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 1 3.517 0' TOOH w/ 11 3/4" Csg R. Klepzig / J. Cortez 54 2459' Flow In (gpm) Current Pump & Flow Data: N/A 7 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 3 N/A Depth Gas (units) H2S Data Sample Line Avg: 0 C1 Hole Condition On Bot Hrs 4145'0 PWD Drilling All Circ Avg Diam 10 bbls 14.500 Max: 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… Logging Engineers: * 10000 units = 100% Gas In Air David Mckechnie/ Andrew Bongard 24 hr Recap: Rig-up to run 11 3/4" casing with Tesco tool. Run in hole with casing to 790'. Work casing past ledge. Run in hole with casing to 2,533'. Step pumps to 12 bpm. Wash, rotate, and work casing to 2,536'. Casing would not go past 2,536'. Pump dry job. Pull out of hole with 11 3/4" casing to 727' at midnight. Plan forward is to perform a clean-out run. Max Gas = 54 U , 62 bbls lost down hole Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) PWD Drilling All Circ Avg Diam 10 bbls 14.500 Max: Hole Condition On Bot Hrs 4145'0 Depth Gas (units) H2S Data Sample Line Avg: 0 C1 15 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 22 N/A 0' Backreaming R. Klepzig / J. Cortez 103 4055' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 49 3.517 N/A N/A N/A Avg 0 0 Total Charges: Min Max Max THTS Cor Solids 6.9 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODSN-29 Oooguruk 5 10/20/2012 4145' North Slope Daily Charges Avg N/A N/A N/A Nabors 19AC N/A AK-AM-0009650310 14.5 0.700 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 1.5/90.3 MXL-1V 4145'99.40 9.45 45 300 C5i C4i C5n Tuff 0 Grvl Coal Max: (lb/100ft 2) 2.601 N/A N/A 21 ASG N/A % 24 hr Max YP AgNO3 N/A 0Avg: C3 C2 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… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Pull out of hole with 11 3/4" casing. Lay down 11 3/4" casing. Pick-up BHA #3. Shallow test MWD. Trip in hole to 2,536'. Ream and wash to 4,145'. Circulate and condition. Pump carbide pill at 4,055' / chase with 90 bbl SAPP pill / chase with 60 bbl Hi Vis sweep. Carbide back 1,682 strokes early. 20% increase in cuttings upon sweep return. Pump second carbide pill at 3,960' / chase with 60 bbl Hi Vis sweep. Carbide back 1,753 strokes early. 5% increase in cuttings upon sweep return. Pump dry job. Trip out of hole wiping tight spots to 3,420'. Run in hole to 3,774'. Backreaming out from 3,774' to 3,410' at report time. Max Gas = 103 U , 12 bbls lost down hole David Mckechnie/ Andrew Bongard Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) 0Avg: C3 C2 N/A % 24 hr Max YP AgNO3 N/A (lb/100ft 2) 2.628 N/A N/A 21 ASG C5i C4i C5n Tuff 0 Grvl Coal Max: 1.5/90.0 4145'11 9.40 9.50 46 Sst Silt Siltst Clyst Cht Gas Breakdown Sd Lst Sh Nabors 19AC N/A AK-AM-0009650310 cP PV Size NAP/Water N/A North Slope Daily Charges Avg N/A N/A Pioneer Natural Resources ODSN-29 Oooguruk 6 10/21/2012 4145' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 7.4 N/A N/A N/A Avg 187 45 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 153 3.517 0' Run 11 3/4" Casing R. Klepzig / J. Cortez 50 298' Flow In (gpm) Current Pump & Flow Data: N/A 7 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 17 N/A Depth Gas (units) H2S Data Sample Line Avg: 0 C1 Hole Condition On Bot Hrs 4145'0 PWD Drilling All Circ Avg Diam 10 bbls 14.500 Max: 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… Logging Engineers: * 10000 units = 100% Gas In Air Jessica Munsell/ Andrew Bongard 24 hr Recap: Backream to 3,410'. Pump 60 bbl Hi Vis sweep. Backream to 2,442'. Circulate one bottoms-up. Backream to 2,061'. Circulate two bottoms-up. Backream to 1,870'. Trip out on elevator to BHA. Lay down BHA. Rig-up to run casing. Run in hole with 11 3/4" casing to 1,988'. Step pumps to 8 bpm. Circulate two bottoms-up. Run in hole with casing to 2,715'. Break circulation. Step pumps to 4 bpm. Run in hole to 3,119'. Break circulation. Step pumps to 6.5 bpm. Run in hole with casing to 3,278' at report time. Max Gas = 50 U , 25 bbls lost down hole Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) PWD Drilling All Circ Avg Diam 10 bbls 14.500 Max: Hole Condition On Bot Hrs 4145'0 Depth Gas (units) H2S Data Sample Line Avg: 0 C1 5 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 0 N/A 0' Testing BOPs R. Klepzig / D. Maskell 55 4140' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 0 3.517 N/A N/A N/A Avg 0 0 Total Charges: Min Max Max THTS Cor Solids 7.4 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODSN-29 Oooguruk 7 10/22/2012 4145' North Slope Daily Charges Avg N/A N/A N/A Nabors 19AC N/A AK-AM-0009650310 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 1.0/90.5 4145'89.45 9.50 47 C5i C4i C5n Tuff 0 Grvl Coal Max: (lb/100ft 2) 2.621 N/A N/A 20 ASG N/A % 24 hr Max YP AgNO3 N/A 0Avg: C3 C2 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… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Run in hole to 4,139' with casing. Make-up landing joint and hanger. Pump carbide pill- came up 489 strokes early (14.05" hole). Rig down Tesco. Rig-up Halliburton cement head and lines. Stage pumps to 60 strokes/834 psi. Pump cement per Halliburton program. Lost returns at 65 bbls pumped. Good returns at 100 bbls pumped. Bumped plug on calculated strokes. Monitor well 30 min. Rig down cement head. Nipple down, nipple up BOPs. Testing BOPs at report time. Max Gas = 55 U , 0 bbls lost down hole Jessica Munsell/ Andrew Bongard Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) 0Avg: C3 C2 N/A % 24 hr Max YP AgNO3 0.40 (lb/100ft 2) 3.046 0.7 N/A 18 ASG C5i C4i C5n Tuff 0 Grvl Coal Max: 64.5/17.5 GT-C1 4165'33 10.55 10.55 85 4 Sst Silt Siltst Clyst Cht Gas Breakdown Sd Lst Sh Nabors 19AC N/A AK-AM-0009650310 10.625 0.856 cP PV Size NAP/Water N/A North Slope Daily Charges Avg 0.8 89.7 Pioneer Natural Resources ODSN-29 Oooguruk 8 10/23/2012 4165' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids 17.0 N/A N/A N/A Avg 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 8 3.517 20' Lay Down BHA R. Klepzig / D. Maskell 56 946' Flow In (gpm) Current Pump & Flow Data: N/A 4 4164' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 6 0.0 Depth Gas (units) H2S Data Sample Line Avg: 0 C1 Hole Condition On Bot Hrs 4165'1.79 PWD Drilling All Circ Avg Diam 10 bbls 10.625 Max: 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… Logging Engineers: * 10000 units = 100% Gas In Air Jessica Munsell/ Andrew Bongard 24 hr Recap: Test BOPS. Trip in hole with BHA #4 Clean Out Assembly. Trip in hole while picking up 5" drill pipe to 4,030'. Ream and wash/tag cement stringers at 4,050'. Circulate bottoms-up. Pressure test casing shoe at 4,045' to 3500 psi. Drill cement/shoe track and rat hole to 4,145'. Displace to 10.55 ppg MOBM. Drill to 4,165'. Circulate bottoms-up. Perform FIT to 12.5 ppg EMW. Pump slug. Trip out of hole. Lay down BHA at report time. Max Gas = 56 U , 0 bbls lost down hole Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) PWD Drilling All Circ Avg Diam 10 bbls 10.625 Max: Hole Condition On Bot Hrs 5000'9.43 193 Depth Gas (units) H2S Data Sample Line Avg: 0 C1 61 4837' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 11 0.0 835' Drilling Intermediate 1 R. Klepzig / D. Maskell 193 4831' Flow In (gpm) Current Pump & Flow Data: 11.89 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3663 3.517 N/A 11.89 11.01 Avg 793 124 Total Charges: Min Max Max THTS Cor Solids New 17.4 0 Ambient Air Pit Room 530 Chromatograph (ppm) 144 C4n 29 0 18 Pioneer Natural Resources ODSN-29 Oooguruk 9 10/24/2012 5000' North Slope 4831 Daily Charges Avg 32.8 166.0 10.72 Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 4165' 64.4/17.3 FXG65s 5000'33 10.60 10.55 77 5 C5i C4i C5n Tuff 10 0 Grvl Coal Max: (lb/100ft 2) 3.008 0.7 Min 10.99 Avg 20 ASG 10.73 % 24 hr Max YP AgNO3 0.42 0Avg: 90 22961 C3 C2 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… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Lay down BHA #4. Pick-up Geo-Pilot/MWD BHA #5 with Weatherford Rip Tide Under-reamer. Trip in hole. Shallow test MWD. Trip in hole to 3,029. Shallow test MWD. Break in Geo-Pilot. Trip in hole to 4,074'. Wash down to 4,165'. Drill ahead to 4,225'. Activate reamer per Weatherford representative. Drill ahead at 100 ft/hr to 5,045' at report time. Max Gas = 193 U , 0 bbls lost down hole 193 530 144 29 0 018 4831 Jessica Munsell/ Andrew Bongard 22961 Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) PWD Drilling All Circ Avg Diam 10 bbls 10.625 Max: Hole Condition On Bot Hrs 6307'22.94 193 Depth Gas (units) H2S Data Sample Line Avg: 0 C1 75 5025' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 58 101.1 1307' Drilling Intermediate 1 R. Klepzig / D. Maskell 283 5088' Flow In (gpm) Current Pump & Flow Data: 11.63 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 4221 3.554 N/A 11.63 11.12 Avg 824 120 Total Charges: Min Max Max THTS Cor Solids New 19.7 0 Ambient Air Pit Room 1233 Chromatograph (ppm) 647 C4n 268 11 85 Pioneer Natural Resources ODSN-29 Oooguruk 9 10/25/2012 6307' North Slope 6307 Daily Charges Avg 107.0 168.2 10.72 Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 4165' 64.7/15.0 FXG65s 6307'39 10.65 10.65 70 5 C5i C4i C5n Tuff 10 0 Grvl Coal Max: (lb/100ft 2) 2.871 0.4 Min 11.11 Avg 22 ASG 10.74 % 24 hr Max YP AgNO3 0.25 5000 0Avg: 90 30835 C3 C2 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… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Drilling ahead from 5000' MD. Serviced rig pump @ 6122' Current formation is mostly darkbrown to darkgray, silty shale with traces of tuff. Max gas: 283u. 0 bbls lost down hole. 193 1233 647 268 11 41 85 6307 Jessica Munsell / Tim Collins / Andrew Bongard 5000 30835 Customer:Report #: Well:Date: Area:24:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:*10000 units = 100% Gas In Air 7270 0Avg: 100 21583 C3C2 N/A % 24 hr Max YP AgNO3 0.35 (lb/100ft2) 2.7940.3 Min 11.05 Avg 18 ASG Tim Collins / Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 67.6/11.4 FXG65s 7270'3010.60 10.60 74 5 7270' 3105'4165' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water 10.74 North Slope WTG Daily Charges Avg N/A N/A Pioneer Natural Resources ODSN-29 Oooguruk 12 10/27/2012 7270.2' 5 1123 0 Ambient Air Pit Room 601 Chromatograph (ppm) 182 C4n 42 Min Max Max THTS Cor Solids New 20.6 N/A N/AN/A Avg 770 109 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 4094 3.554 963' TD Intermediate 1/Circ R. Klepzig / D. Maskell 186 Trip Gas Flow In (gpm) Current Pump & Flow Data: 11.28 22 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)13 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 7270'73 186 24 hr Recap: TOOH to 3577' (111bbls lost down hole). TIH for wiper run (26bbls lost down hole). Circulate on bottom (32bbls lost over shakers and to centrifuge). Total fluid losses: 172bbls. PWD Drilling All Circ Avg Diam 10 bbls 10.625 Max: Customer:Report #: Well:Date: Area:24:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:*10000 units = 100% Gas In Air 7270 0Avg: 100 1010 C3C2 N/A % 24 hr Max YP AgNO3 0.40 (lb/100ft2) 2.8030.4 Min 10.96 Avg 18 ASG Tim Collins / Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 66.7/12.5 FXG65s 7270'3010.60 10.60 87 5 7270' 3105'4165' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water 10.72 North Slope WTG Daily Charges Avg N/A N/A Pioneer Natural Resources ODSN-29 Oooguruk 13 10/28/2012 7270.2' 0 06 0 Ambient Air Pit Room 48 Chromatograph (ppm) 26 C4n 13 Min Max Max THTS Cor Solids New 20.3 N/A N/AN/A Avg 89 13 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 388 3.554 0' TOOH R. Klepzig / J. Haberthur 33 Trip Gas Flow In (gpm) Current Pump & Flow Data: 11.04 5 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)6 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 7270'73 33 24 hr Recap: Continued to circulate 7x BU until shakers were clean. TOOH. Packed off @ 4580'. Circulated and pumped high visc sweep. 100% increase in cuttings. Sweep came back on time. TOOH to BHA. Rig up for 9 5/8' casing. Max gas: 33u. Avg gas: 5u. Total fluid losses: 54bbls. PWD Drilling All Circ Avg Diam 10 bbls 10.625 Max: Customer:Report #: Well:Date: Area:24:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:*10000 units = 100% Gas In Air 24 hr Recap: Rigged up to run 9 5/8" casing. Ran 9 5/8" Hydril 521 40#L-80 Liner in hole to 3333'. Partial returns. Ran in hole with Liner on 5" DP to 4053'. Partial returns. Stage pumps to 4 bpm. 60-70% losses while pumping. Rotated 20 rpm. Ran in hole to 7237'. Max gas: 19u. Avg gas: 7u. Total fluid losses: 603bbls. PWD Drilling All Circ Avg Diam 10 bbls 10.625 Max: Hole Condition On Bot Hrs 7270'73 19 Depth Gas (units) H2S Data Sample Line Avg:0 C1 7 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)8 N/A 0' 9 5/8" Casing run R. Klepzig / J. Haberthur 19 Trip Gas Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 103 3.517 N/A N/AN/A Avg 20 2 Total Charges: Min Max Max THTS Cor Solids New 21.5 0 Ambient Air Pit Room 14 Chromatograph (ppm) 5 C4n 0 0 00 Pioneer Natural Resources ODSN-29 Oooguruk 14 10/29/2012 7270.2' North Slope T-POG Daily Charges Avg N/A N/A N/A Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water Gas Breakdown Sd LstShSstSiltSiltstClystCht 7270' 3105'4165' 66.0/12.0 FXG65s 7270'4310.60 10.60 90 5 C5iC4iC5n Tuff 0 GrvlCoal Max: Tim Collins / Andrew Bongard (lb/100ft2) 2.6970.4 Min N/A Avg 17 ASG N/A % 24 hr Max YP AgNO3 0.40 7270 0Avg: 100 674 C3C2 Customer:Report #: Well:Date: Area:24:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:*10000 units = 100% Gas In Air 7270 0Avg: 100 10341 C3C2 N/A % 24 hr Max YP AgNO3 0.46 (lb/100ft2) 2.6940.4 Min N/A Avg 19 ASG Tim Collins / Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 66.0/12.0 FXG65s 7270'4110.60 10.60 93 5 7270' 3105'4165' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water N/A North Slope T-POG Daily Charges Avg N/A N/A Pioneer Natural Resources ODSN-29 Oooguruk 14 10/30/2012 7270.2' 1042 10222517 0 Ambient Air Pit Room 5021 Chromatograph (ppm) 2517 C4n 2519 Min Max Max THTS Cor Solids New 21.5 N/A N/AN/A Avg 31 4 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 275 3.517 0' 9 5/8" Casing run R. Klepzig / J. Haberthur 71 Trip Gas Flow In (gpm) Current Pump & Flow Data: N/A 12 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)0 N/A Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 7270'73 71 24 hr Recap: Pumped WTF ball down. Seated ball 1874 strokes. Set Hrg per WTF. Pumped cement. Chases cement w/ 10.6 ppg MOBM. Bmp plug w. 3283 strokes. Psi test 3500 psi/5 min. Set Pkr per WTF rep. Circulated BU. Pumped dry job. TOOH. Laid down BHA. Prepaired for test BOPs. Max gas: 71u. Avg gas: 12u. Total fluid losses to hole: 103bbls. PWD Drilling All Circ Avg Diam 10 bbls 10.625 Max: Customer:Report #: Well:Date: Area:24:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:*10000 units = 100% Gas In Air 24 hr Recap: Finished testing BOP. TIH to test casing and drill rat hole. Tested casing at 3500psi. Drilled cement, shoe track and rathole to 7270'. Displaced well from 10.6 lg/gal ENVIROMUL to 10.2 lb/gal LSND. Drilled to 7290'. CBU. Performed FIT to 13.5 lb/gal. Slug pipe. TOOH with 8.5 Clean-out BHA. Max gas: 59u. Avg gas: 8u. Total fluid losses to hole: 0bbls. PWD Drilling All Circ Avg Diam 10 bbls 10.625 Max: Hole Condition On Bot Hrs 7290'0.44 59 Depth Gas (units) H2S Data Sample Line Avg:0 C1 7 7275' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)8 N/A 0' 9 5/8" Casing run R. Klepzig / J. Haberthur 59 Trip Gas Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft N/A N/A N/A N/AN/A Avg N/A N/A Total Charges: Min Max Max THTS Cor Solids New 7.7 0 Ambient Air Pit Room 141 Chromatograph (ppm) 59 C4n 50 16 1855 Pioneer Natural Resources ODSN-29 Oooguruk 14 10/30/2012 7270.2' North Slope 7290 Daily Charges Avg 20.9 102.9 N/A Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water Gas Breakdown Sd LstShSstSiltSiltstClystCht 7270' 3105'4165' 1.0/90.5 FXG65s 7270'1010.20 10.20 46 5 C5iC4iC5n Tuff 0 GrvlCoal Max: Tim Collins / Andrew Bongard (lb/100ft2) 3.733N/A Min N/A Avg 24 ASG N/A % 24 hr Max YP AgNO3 N/A 7270 0Avg: 100 2363 C3C2 Customer:Report #: Well:Date: Area:24:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:*10000 units = 100% Gas In Air 7290 0Avg: 95 19136 C3C2 10.57 % 24 hr Max YP AgNO3 N/A (lb/100ft2) 3.731N/A Min 14.26 Avg 23 ASG Tim Collins / Andrew Bongard C5iC4iC5n Tuff 5 0 GrvlCoal Max: 2.5/89.0 FXG65s 7270'810.18 10.18 45 5 7270' 3105'4165' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water 10.35 North Slope 7365 Daily Charges Avg 36.1 88.0 Pioneer Natural Resources ODSN-29 Oooguruk 15 11/1/2012 7365' 1035 10282523 0 Ambient Air Pit Room 5015 Chromatograph (ppm) 2532 C4n 2545 Min Max Max THTS Cor Solids New 7.7 N/A 13.8212.95 Avg 142 40 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 767 3.554 83' 9 5/8" Casing run R. Klepzig / J. Haberthur 283 7291' Flow In (gpm) Current Pump & Flow Data: ##### 104 7344' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)28 0.0 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 7365'2.41 283 24 hr Recap: Tested MPD equipment. Drilled from 7290' to 7365'. Began seeing heavy losses to the hole at ~7353'MD. Max gas: 283u. Avg gas: 104u. Total fluid losses to hole: 334 bbls. PWD Drilling All Circ Avg Diam 47.8 bbls 9.500 Max: Customer:Report #: Well:Date: Area:24:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:*10000 units = 100% Gas In Air 24 hr Recap: Drilled 2nd intermediate seeing heavy losses. Pumped 55 bbl LCM Pill. POOH to 7233'MD. Squeezed LCM w/ MPD. Drilled to 8279' MD. Total 24hr losses to hole: -601 bbls. Max gas: 1170 units. Avg gas: 225 units. PWD Drilling All Circ Avg Diam 47.8 bbls 9.500 Max: Hole Condition On Bot Hrs 13'2.41 283 Depth Gas (units) H2S Data Sample Line Avg:0 C1 104 8186' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)28 1.5 914' Drilling Intermediate 2 J. Polya / J. Haberthur 283 7291' Flow In (gpm) Current Pump & Flow Data: 13.30 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 767 3.554 N/A 13.1412.99 Avg 142 40 Total Charges: Min Max Max THTS Cor Solids New 9.3 0 Ambient Air Pit Room 5107 Chromatograph (ppm) 2549 C4n 965 300 268365 Pioneer Natural Resources ODSN-29 Oooguruk 16 11/2/2012 8279' North Slope 8279 Daily Charges Avg 72.0 159.5 12.62 Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water Gas Breakdown Sd LstShSstSiltSiltstClystCht 1009'7270' 4.0/86.0 FXG65s 7270'1110.22 10.22 44 5 C5iC4iC5n Tuff 0 GrvlCoal Max: Tim Collins / Andrew Bongard (lb/100ft2) 3.363N/A Min 12.98 Avg 33 ASG 12.66 % 24 hr Max YP AgNO3 N/A 7365 0Avg: 100 104414 C3C2 Customer:Report #: Well:Date: Area:24:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:*10000 units = 100% Gas In Air 8279 0Avg: 100 229851 C3C2 12.68 % 24 hr Max YP AgNO3 N/A (lb/100ft2) 3.436N/A Min 11.44 Avg 17 ASG Tim Collins / Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 2.0/88.5 FXG65s 8469'710.20 10.15 35 5 1286'7270' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water 0.01 North Slope 8556 Daily Charges Avg 62.2 179.2 Pioneer Natural Resources ODSN-29 Oooguruk 17 11/3/2012 8559.16' 212 180316 0 Ambient Air Pit Room 8851 Chromatograph (ppm) 2953 C4n 781 Min Max Max THTS Cor Solids New 8.7 N/A 13.0812.82 Avg 579 52 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3417 3.554 227' Drilling Intermediate 2 J. Polya / J. Haberthur 2232 8431' Flow In (gpm) Current Pump & Flow Data: 14.03 84 8314' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)38 1.7 Depth Gas (units) H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 8556'24.01 2232 24 hr Recap: Drilling intermediate 2 from 8321’MD. Started losing fluid at 350+bbls/hr. Stopped drilling due to low ROP and mud volume. Pumped LCM pill. Pulled out of hole to the shoe. Squeezed pill. Losses ceased. Ran in hole. Drilled from 8321’ to 8556’ with losses between 70 and 120 bbls/hr. Performed Geotap from 8470’ to 8392’. Continued drilling intermediate 2. Total 24hr losses to hole: -1540 bbls. Max gas: 2232 units. Avg gas: 225 units. PWD Drilling All Circ Avg Diam 47.8 bbls 9.500 Max: Customer:Report #: Well:Date: Area:24:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:*10000 units = 100% Gas In Air 24 hr Recap: Drilling intermediate 2 with average losses of 50bbls/hr. Total 24hr losses to hole: -1220 bbls. Max gas: 238 units. Avg gas: 95 units. PWD Drilling All Circ Avg Diam 47.8 bbls 9.500 Max: Hole Condition On Bot Hrs 8556'24.01 290 Depth Gas (units) H2S Data Sample Line Avg:0 C1 95 8568' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)275 76.3 1053' Drilling Intermediate 2 J. Polya / J. Haberthur 290 9481' Flow In (gpm) Current Pump & Flow Data: 12.96 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3278 3.100 N/A 12.9012.82 Avg 603 74 Total Charges: Min Max Max THTS Cor Solids New 8.6 0 Ambient Air Pit Room 1036 Chromatograph (ppm) 453 C4n 164 55 4964 Pioneer Natural Resources ODSN-29 Oooguruk 18 11/4/2012 9612' North Slope 9612 Daily Charges Avg 63.5 170.5 12.67 Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water Gas Breakdown Sd LstShSstSiltSiltstClystCht 2342'7270' 2.5/88.0 FXG65s 8469'1010.20 10.20 39 5 C5iC4iC5n Tuff 0 GrvlCoal Max: Tim Collins / Andrew Bongard (lb/100ft2) 3.447N/A Min 12.82 Avg 22 ASG 12.73 % 24 hr Max YP AgNO3 N/A 8556 0Avg: 100 24128 C3C2 Customer:Report #: Well:Date: Area:24:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:*10000 units = 100% Gas In Air 6912 0Avg: 10 72224 C3C2 70 12.74 % 24 hr Max YP AgNO3 N/A (lb/100ft2) 3.378N/A Min 12.80 Avg 16 ASG Tim Collins / Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 1.8/88.5 FXG65s 8469'910.20 10.20 40 5 9774' 2342'7270' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water 11.82 North Slope 9774 Daily Charges Avg 82.5 182.5 Pioneer Natural Resources ODSN-29 Oooguruk 19 11/5/2012 9774' 259 236308 0 Ambient Air Pit Room 3793 Chromatograph (ppm) 1922 C4n 767 Min Max Max THTS Cor Solids New 8.9 N/A 12.8812.81 Avg 602 57 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3278 3.554 162' TD Intermediate 2/TOOH J. Polya / J. Haberthur 781 9666' Flow In (gpm) Current Pump & Flow Data: 13.47 386 9615' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)65 N/A Depth Gas (units) 20 H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 8556'24.01 781 24 hr Recap: Drilled from 9612' to TD of intermediate 2 at 9774'MD, off bottom at 03:21. Circulated 50 bbls high visc sweep with minimal increase in returns. Circulated 3 BU. POOH to 8706' and packed off. Stepped up rate to 600 g/min backream from 8706' to 8390'. Mad Pass from 8390' to 8279. BR from 8279' to 8228'. Pack off. Losses increased to 190+bbls/hr. RIH to 8365'. Pumped 90bbls of 60lb/bbl LCM Pill. Total 24hr losses to hole: -1104 bbls. Max gas: 781 units. Avg gas: 386 units. PWD Drilling All Circ Avg Diam 47.8 bbls 9.500 Max: Customer:Report #: Well:Date: Area:24:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:*10000 units = 100% Gas In Air 0Avg: 10 107700 C3C2 70 N/A % 24 hr Max YP AgNO3 N/A (lb/100ft2) 3.595N/A Min 12.39 Avg 22 ASG Tim Collins / Andrew Bongard C5iC4iC5n Tuff 0 GrvlCoal Max: 2.5/88.5 FXG65s 8469'1010.20 10.20 40 5 9774' 2342'7270' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water 12.81 North Slope 9774 Daily Charges Avg N/A N/A Pioneer Natural Resources ODSN-29 Oooguruk 20 11/6/2012 9774' 136 121225 0 Ambient Air Pit Room 5517 Chromatograph (ppm) 2147 C4n 582 Min Max Max THTS Cor Solids New 8.2 N/A N/AN/A Avg 137 19 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 874 3.554 0' TD Intermediate 2/TOOH J. Polya / J. Haberthur 1160 Trip Gas Flow In (gpm) Current Pump & Flow Data: 13.15 74 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)7 N/A Depth Gas (units) 20 H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 8556'24.01 1160 24 hr Recap: Reamer was cycled. The hole was back reamed from 8370’ to 8279’, 25’ above the loss zone. A 2:1 DOB2C pill was pumped and chased with mud. Three bottoms up were circulated with no losses at the beginning but 35 barrels/hour by the finish. The drill string was pulled out of the hole to 7708’, pumping 2.36 barrels per stand. Three more bottoms ups were circulated and pulled out of the hole to 7233 with losses of 35 barrels per hour with MPD holding 12.8 lbs/gallon. Drill string was tripped back into the hole to 7601’ then washing and reaming to 8565’, pumping 600 gallons/min and rotating at 80 rpm. 35 barrel per hour losses were still occurring. The drill string was tripped out of the hole to 7233’ with MPD maintaining 12.8 lbs/gallon and experiencing 20-60 barrels per hour. Total 24hr losses to hole: -968bbls. Max gas: 1160 units. Avg gas: 74 units. PWD Drilling All Circ Avg Diam 47.8 bbls 9.500 Max: Customer:Report #: Well:Date: Area:24:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:*10000 units = 100% Gas In Air 0Avg: 10 229851 C3C2 70 N/A % 24 hr Max YP AgNO3 N/A (lb/100ft2) 3.604N/A Min 12.82 Avg 21 ASG Tim Collins / Kerry Garner C5iC4iC5n Tuff 0 GrvlCoal Max: 3.0/88.0 FXG65s 8469'1110.20 10.20 41 5 9774' 2342'7270' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water 12.62 North Slope 9774 Daily Charges Avg N/A N/A Pioneer Natural Resources ODSN-29 Oooguruk 21 11/7/2012 9774' 1035 10282523 0 Ambient Air Pit Room 8851 Chromatograph (ppm) 2953 C4n 2545 Min Max Max THTS Cor Solids New 8.2 N/A N/AN/A Avg 275 39 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 1718 3.554 0' Circulating J. Polya / J. Haberthur 2177 N/A Flow In (gpm) Current Pump & Flow Data: 12.93 74 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)49 N/A Depth Gas (units) 20 H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 8556'24.01 2177 24 hr Recap: Second DOB2C Pill was prepared. The drill string was tripped into the hole to 8300’MD. The pill was pumped and then chased with mud. The drill string was tripped out of the hole from 8300’ to 7740’ and three bottoms up were circulated. The drill string was tripped out to 7233’ where issues with MPD pumps led to the use of the cement pump for MPD purposes unit repairs could be complete. Drill string was tripped back into the hole, washing and reaming, to 8565’ with intermittent tight spots and pumping 600 gal/min and rotating at 80 rpm. The tripping into the hole continued to 8941’, pumping at 500 gal/min and 80 rpm. The trip in continued to 9774’ without pumping and rotation at 30 rpm. Circulated 50 barrels of high viscosity sweep. Only losses experiences were seepage losses. Total 24hr losses to hole: -390bbls. Max gas: 2177 units. Avg gas: 84 units. PWD Drilling All Circ Avg Diam 47.8 bbls 9.500 Max: Customer:Report #: Well:Date: Area:24:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:*10000 units = 100% Gas In Air 24 hr Recap: A sweep was pumped that yielded no increases. Three bottoms up were circulated. The pumps were cycled for the reamer. The drill string was tripped into the hole to 9774’. A 50 barrel high viscosity sweep was pumped that yielded slight increases. The well was displaced to 12.0 pounds per gallon LSND with added NXS-LUBE. Drill string was tripped out of the hole while lubricating from 9774’ to 7238, then tripped out without lubricating from 7238’ to 3924’. Preparations were made to displace with 13.5 pounds per gallon mud. Total 24hr losses to hole: -234bbls. Max gas: 642 units. Avg gas: 35 units. PWD Drilling All Circ Avg Diam 619.5 bbls 9.500 Max: Hole Condition On Bot Hrs 9774'45.53 642 Depth Gas (units) 20 H2S Data Sample Line Avg:0 C1 35 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)5 N/A 0' Circ. Displacement TOOH J. Polya / J. Haberthur 642 9737' Flow In (gpm) Current Pump & Flow Data: 13.14 Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 865 3.554 N/A N/AN/A Avg 154 22 Total Charges: Min Max Max THTS Cor Solids New 14.3 0 Ambient Air Pit Room 2611 Chromatograph (ppm) 1028 C4n 365 109 95133 Pioneer Natural Resources ODSN-29 Oooguruk 22 11/8/2012 9774' North Slope 9774 Daily Charges Avg N/A N/A 1.26 Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water Gas Breakdown Sd LstShSstSiltSiltstClystCht 9774' 2342'7270' 2.5/82.5 FXG65s 8469'1112.00 12.00 43 5 C5iC4iC5n Tuff 0 GrvlCoal Max: Tim Collins / Kerry Garner (lb/100ft2) 4.011N/A Min 12.75 Avg 32 ASG N/A % 24 hr Max YP AgNO3 N/A 0Avg: 10 65667 C3C2 70 Customer:Report #: Well:Date: Area:24:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:*10000 units = 100% Gas In Air 0Avg: 10 N/A C3C2 70 N/A % 24 hr Max YP AgNO3 N/A (lb/100ft2) 4.011N/A Min N/A Avg 32 ASG Tim Collins / Kerry Garner C5iC4iC5n Tuff 0 GrvlCoal Max: 2.5/82.5 FXG65s 8469'1112.00 12.00 43 5 9774' 2342'7270' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water N/A North Slope 9774 Daily Charges Avg N/A N/A Pioneer Natural Resources ODSN-29 Oooguruk 23 11/9/2012 9774' N/A N/AN/A 0 Ambient Air Pit Room N/A Chromatograph (ppm) N/A C4n N/A Min Max Max THTS Cor Solids New 14.3 N/A N/AN/A Avg 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke N/A Max @ ft 42 3.554 0' TOOH J. Polya / J. Haberthur N/A N/A Flow In (gpm) Current Pump & Flow Data: N/A N/A N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)N/A N/A Depth Gas (units) 20 H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 9774'45.53 N/A 24 hr Recap: 56 barrels of high viscosity, 13.5 pounds per gallon Pill was spotted and chased with 50 barrels of 13.5 pounds per gallon LSND. The drill string was tripped out of the hole to 3498’ and the 13.5 pounds per gallon LSND was displaced. There was a total loss of 6 barrels to the hole during displacement. The drill string was tripped out of the hole and the BHA was laid down. Preparations to run 7” casing were made and the casing run began at approximately 19:00 hours. Total 24hr losses to hole: -241bbls. Max gas: 0 units. Avg gas: 0 units. PWD Drilling All Circ Avg Diam 619.5 bbls 9.500 Max: Customer:Report #: Well:Date: Area:24:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:*10000 units = 100% Gas In Air 24 hr Recap: The running of the 7” 26# casing continued from 3444’ to 9759’, where it was landed. The casing was filled with 11.2 pounds per gallon LDSN. The laying down of the heavy weight pipe began. Total 24hr losses to hole: -118bbls. Max gas: 12 units. Avg gas: 138 units. PWD Drilling All Circ Avg Diam 619.5 bbls 9.500 Max: Hole Condition On Bot Hrs 9774'45.53 138 Depth Gas (units) 20 H2S Data Sample Line Avg:0 C1 12 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)N/A N/A 0' Cement/Lay Down Pipe J. Polya / J. Haberthur 138 Trip Gas Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 355 3.554 N/A N/AN/A Avg 32 0 Total Charges: Min Max Max THTS Cor Solids New 11.7 0 Ambient Air Pit Room 5030 Chromatograph (ppm) 2536 C4n 2587 1050 23242520 Pioneer Natural Resources ODSN-29 Oooguruk 24 11/10/2012 9774' North Slope Trip Gas Daily Charges Avg N/A N/A N/A Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water Gas Breakdown Sd LstShSstSiltSiltstClystCht 9774' 2342'7270' 3.0/84.5 FXG65s 9774'1511.20 11.20 47 5 C5iC4iC5n Tuff 0 GrvlCoal Max: Tim Collins / Kerry Garner (lb/100ft2) 3.846N/A Min N/A Avg 25 ASG N/A % 24 hr Max YP AgNO3 N/A 0Avg: 10 198116 C3C2 70 Customer:Report #: Well:Date: Area:24:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:*10000 units = 100% Gas In Air 0Avg: 10 N/A C3C2 70 N/A % 24 hr Max YP AgNO3 N/A (lb/100ft2) 3.846N/A Min N/A Avg 25 ASG Tim Collins / Kerry Garner C5iC4iC5n Tuff 0 GrvlCoal Max: 3.0/84.5 FXG65s 9774'1511.20 11.20 47 5 9774' 2342'7270' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water N/A North Slope 9774 Daily Charges Avg N/A N/A Pioneer Natural Resources ODSN-29 Oooguruk 25 11/11/2012 9774' N/A N/AN/A 0 Ambient Air Pit Room N/A Chromatograph (ppm) N/A C4n N/A Min Max Max THTS Cor Solids New 11.7 N/A N/AN/A Avg 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 0 3.554 0' Safety Standdown J. Polya / J. Haberthur N/A N/A Flow In (gpm) Current Pump & Flow Data: N/A N/A N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)N/A N/A Depth Gas (units) 20 H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 9774'45.53 N/A 24 hr Recap: The remainder of the 5” drill pipe was laid down into the mouse hole and over 2 barrels of 11.2 pound per gallon LSND was put into the 11 ¾” by 7” annulus every 30 minutes. An additional 100 barrels of 11.2 pounds per gallon LSND were bullheaded down the annulus. The top rams were changed to 2 7/8” by 5” VBR’s. There was a safety standdown. Total 24hr losses to hole: 0bbls. Max gas: 0 units. Avg gas: 0 units. PWD Drilling All Circ Avg Diam 619.5 bbls 9.500 Max: Customer:Report #: Well:Date: Area:24:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:*10000 units = 100% Gas In Air 24 hr Recap: Safety Stand Down. Total 24hr losses to hole: 0bbls. Max gas: 0 units. Avg gas: 0 units. PWD Drilling All Circ Avg Diam 619.5 bbls 9.500 Max: Hole Condition On Bot Hrs 9774'45.53 N/A Depth Gas (units) 20 H2S Data Sample Line Avg:0 C1 N/A N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)N/A N/A 0' Safety Standdown J. Polya / J. Haberthur N/A N/A Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 0 3.554 N/A N/AN/A Avg 0 0 Total Charges: Min Max Max THTS Cor Solids New 11.7 0 Ambient Air Pit Room N/A Chromatograph (ppm) N/A C4n N/A N/A N/AN/A Pioneer Natural Resources ODSN-29 Oooguruk 26 11/12/2012 9774' North Slope 9774 Daily Charges Avg N/A N/A N/A Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water Gas Breakdown Sd LstShSstSiltSiltstClystCht 9774' 2342'7270' 3.0/84.5 FXG65s 9774'1511.20 11.20 47 5 C5iC4iC5n Tuff 0 GrvlCoal Max: Tim Collins / Kerry Garner (lb/100ft2) 3.846N/A Min N/A Avg 25 ASG N/A % 24 hr Max YP AgNO3 N/A 0Avg: 10 N/A C3C2 70 Customer:Report #: Well:Date: Area:24:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: 8 ROP & Gas: . Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers:*10000 units = 100% Gas In Air 0Avg: 10 N/A C3C2 70 N/A % 24 hr Max YP AgNO3 N/A (lb/100ft2) 3.846N/A Min N/A Avg 25 ASG Tim Collins / Kerry Garner C5iC4iC5n Tuff 0 GrvlCoal Max: 3.0/84.5 FXG65s 9774'1511.20 11.20 47 5 9774' 2342'7270' Sst Silt Siltst ClystCht Gas Breakdown Sd LstSh Nabors 19AC N/A AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water N/A North Slope 9774 Daily Charges Avg N/A N/A Pioneer Natural Resources ODSN-29 Oooguruk 27 11/13/2012 9774' N/A N/AN/A 0 Ambient Air Pit Room N/A Chromatograph (ppm) N/A C4n N/A Min Max Max THTS Cor Solids New 11.7 N/A N/AN/A Avg 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 0 3.554 0' Safety Standdown J. Polya / J. Haberthur N/A N/A Flow In (gpm) Current Pump & Flow Data: N/A N/A N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)N/A N/A Depth Gas (units) 20 H2S Data Sample Line Avg:0 C1 Hole Condition On Bot Hrs 9774'45.53 N/A 24 hr Recap: Safety Stand Down until 18:00. BOP Test. Total 24hr losses to hole: 0bbls. Max gas: 0 units. Avg gas: 0 units. PWD Drilling All Circ Avg Diam 619.5 bbls 9.500 Max: Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data:Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) PWD Drilling All Circ Avg Diam 619.5 bbls 9.500 Max: Hole Condition On Bot Hrs 9774'45.53 Depth Gas (units) 20 H2S Data Sample Line Avg:0 C1 6 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units)3 N/A 0' TIH w/ Clean Out BHA J. Polya / J. Haberthur 88 ' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 0 3.554 N/AN/A Avg 0 0 Total Charges: Min Max Max THTS Cor Solids New 11.7 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODSN-29 Oooguruk 28 11/14/2012 9774' North Slope Daily Charges Avg N/A N/A N/A Nabors 19AC AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water Gas Breakdown Sd LstShSst Silt Siltst ClystCht 9774' 2342'7270' 3.0/84.5 FXG65s 9774' 1111.25 11.25 48 5 C5iC4iC5n Tuff 0 GrvlCoal Max: (lb/100ft2) 3.898N/A Min N/A Avg 27 ASG N/A % 24 hr Max YP AgNO3 N/A 0Avg: 10 C3C2 70 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… Logging Engineers:* 10000 units = 100% Gas In Air 24 hr Recap: Safety Standdown till 03:00 hrs. P/Up BHA and Stg on rig . P/Up and RIH w/ 105 jts 4"DP w/ J.Wkr. Flush. TOH. Psi test 7" csg/shoe to 3500 psi / 30 min. P/Up Clean Out BHA. TIH while P/Up 4" DP to 9055'. TIH on stds to 9473'. Prep to wash dn @ report time. Max gas: 8 units. Avg gas: 6 units. 8 N/A N/A N/A N/A N/AN/A9774 Todd A. Wilson / Kerry Garner N/A Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 0Avg: N/A C3 C2 N/A % 24 hr Max YP AgNO3 N/A (lb/100ft 2) 3.345 N/A Min N/A Avg 24 ASG Todd A. Wilson / Kerry Garner C5i C4i C5n Tuff 0 Grvl Coal Max: 3.0/82.0 FXG65s 9774'12 11.20 11.20 47 5 9774' 2342'7270' Sst Silt Siltst Clyst Cht Gas Breakdown Sd Lst Sh Nabors 19AC AK-AM-0009650310 10.625 1.464 cP PV Size NAP/Water N/A North Slope 9774 Daily Charges Avg N/A N/A Pioneer Natural Resources ODSN-29 Oooguruk 29 11/15/2012 9774' N/A N/A N/A 0 Ambient Air Pit Room N/A Chromatograph (ppm) N/A C4n N/A Min Max Max THTS Cor Solids New 14.2 N/A N/A Avg 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 0 3.554 0' TOH w/ Clean Out BHA J. Polya / J. Haberthur 29 29' Flow In (gpm) Current Pump & Flow Data: N/A 20 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 6 N/A Depth Gas (units) H2S Data Sample Line Avg: 0 C1 Hole Condition On Bot Hrs 9774'45.53 29 24 hr Recap: TIH to 9503'. Tag cmt stringers. Ream and wash f/ 9503' to 9634'. Downtime for top drive PLC communication prob.Recip and Circ. @ 0.5 bpm. Trouble shoot top drive PLC. Repair bad cable. Drill cmt & float to 9774'. Circ 3x B/Up. Shakers clean. Monitor well 10 min. Pump dry job. TOH to 2900' @ report dry job. TOH to 2900' @ report time. Max gas: 29 units. Avg gas: 20 units. Trip gas: 75 units. PWD Drilling All Circ Avg Diam 619.5 bbls 9.500 Max: Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 9774 0Avg: N/A C3 C2 20 20 N/A % 24 hr Max YP AgNO3 0.60 (lb/100ft 2) 2.176 0.5 Min N/A Avg 12 ASG Todd A. Wilson / Kerry Garner C5i C4i C5n Tuff 0 Grvl Coal Max: 89.6/10.4 PDC 9809'15 7.65 7.65 62 7 9774' Sst Silt Siltst Clyst Cht Gas Breakdown Sd 60 Lst Sh Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water N/A North Slope 9864 Daily Charges Avg N/A N/A Pioneer Natural Resources ODSN-29 Oooguruk 30 11/16/2012 9864' N/A N/A N/A 0 Ambient Air Pit Room N/A Chromatograph (ppm) N/A C4n N/A Min Max Max THTS Cor Solids New 3.4 N/A N/A Avg 235 66 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 2877 3.554 90' Drilling 6.125" Lateral J. Polya / J. Haberthur 270 270' Flow In (gpm) Current Pump & Flow Data: N/A 96 N/A Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 172 N/A Depth Gas (units) H2S Data Sample Line Avg: 0 C1 Hole Condition On Bot Hrs 9774'45.53 270 24 hr Recap: TOOH to Clean Out BHA. L/Dn BHA.P/Up BHA #9. TIH. Shallow test MWD. TIH to 9746'. Slip & cut DLn. Pull Trip Nip. Install MPD RCD bearing. Pump 40 bbl Hi Vis MOBM spacer. Displace active system to 7.65 ppg Enviromul. Dump spacer on return to surface. Dump 15 bbls WBM / MOBM interface. Drill to 9774'. Perform FIT 12.5 ppg EMW. Rotary drilling and sliding to 9987' holding 9.8 ppg EMW w/ MPD @ report time. Max gas: 270 units. Avg gas: 96 units. Trip gas: 270 units. Total Losses: -55 bbls PWD Drilling All Circ Avg Diam 619.5 bbls 9.500 Max: Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Rotary drilling and sliding to 10227' holding 9.85 ppg EMW w/ MPD. Perform Static Pore Psi Test w/ MPD. Pore Psi = 9.5 ppg EMW. Drilling and sliding to 10665' holding 9.85 ppg EMW w/ MPD @ report time. MADD pass all slide areas. Max gas: 846 units. Avg gas: 279 units. Total Losses: 0 PWD Drilling All Circ Avg Diam 619.5 bbls 9.500 Max: Hole Condition On Bot Hrs 10612'9.5 846 Depth Gas (units) 40 H2S Data Sample Line Avg: 0 C1 279 10256' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 846 143.4 748' Drilling 6.125" Lateral J. Polya / J. Cortez 846 10588' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 2985 3.554 N/A N/A Avg 235 66 Total Charges: Min Max Max THTS Cor Solids New 3.8 0 Ambient Air Pit Room 439 Chromatograph (ppm) 162 C4n 50 15 15 25 Pioneer Natural Resources ODSN-29 Oooguruk 31 11/17/2012 10612' North Slope 10612 Daily Charges Avg 30.2 231.5 N/A Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 9774' 86.9/13.1 PDC 10563'12 7.60 7.70 56 9 C5i C4i C5n Tuff 0 Grvl Coal Max: Todd A. Wilson / Kerry Garner (lb/100ft 2) 1.761 0.5 Min N/A Avg 12 ASG N/A % 24 hr Max YP AgNO3 0.48 9864 0Avg: 12796 C3 C2 60 Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) PWD Drilling All Circ Avg Diam 619.5 bbls 6.125 Max: Hole Condition On Bot Hrs 11627'13.2 926 Depth Gas (units) H2S Data Sample Line Avg: 0 C1 306 10897' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 112 150.0 1015' Drilling 6.125" Lateral J. Polya / J. Cortez 926 11338' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3160 3.554 N/A N/A Avg 238 67 Total Charges: Min Max Max THTS Cor Solids New 3.3 0 Ambient Air Pit Room 259 Chromatograph (ppm) 141 C4n 55 17 26 Pioneer Natural Resources ODSN-29 Oooguruk 32 11/18/2012 11627' North Slope 11627 Daily Charges Avg 44.2 332.0 N/A Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 9774' 87.5/12.5 PDC 11575'10 7.65 7.65 52 9 C5i C4i C5n Tuff 0 Grvl Coal Max: (lb/100ft 2) 2.111 0.5 Min N/A Avg 8 ASG N/A % 24 hr Max YP AgNO3 0.45 10612 0Avg: 4911 C3 C2 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… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Rotary drilling @ 150' per hr. and sliding to 11672' holding 9.9 EMW w/ MPD. MAD Pass all slide areas. Max gas: 926 units. Avg gas: 306 units. Total Losses: 0 926 259 141 55 17 17 26 11627 Todd A. Wilson / Kerry Garner 10612 4911 Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) PWD Drilling All Circ Avg Diam 619.5 bbls 6.125 Max: Hole Condition On Bot Hrs 12464'32.41 1440 Depth Gas (units) 80 H2S Data Sample Line Avg: 0 C1 189.0 12387' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 38 31.9 837' Drilling 6.125" Lateral J. Polya / J. Cortez 1440.0 12270' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 2795 3.554 N/A N/A Avg 227 77 Total Charges: Min Max Max THTS Cor Solids New 4.6 0 Ambient Air Pit Room 118 Chromatograph (ppm) 73 C4n 32 11 15 Pioneer Natural Resources ODSN-29 Oooguruk 33 11/19/2012 12464' North Slope 12464 Daily Charges Avg 36.2 308.8 N/A Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 9774' 87.4/12.6 PDC 12461'11 7.80 7.80 52 9 C5i C4i C5n Tuff 0 Grvl Coal Max: (lb/100ft 2) 2.144 0.5 Min N/A Avg 10 ASG N/A % 24 hr Max YP AgNO3 0.80 11627 0Avg: 2154 C3 C2 20 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… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Rotary drilling and sliding to 12269' holding 10.0 ppg EMW w/ MPD. Repair wash out in rig bleed off line. Drill to 12387'. Circ while Geol reviews hole data. Drill ahead to 12464'. Pk off. Circ and Cond. Attmpt to clean up hole. No go. TOH to 11900'. Decision made to OH sidetrack. Troughing @ 11931' @ report time. Max gas: 1440 units. Avg gas: 189 units. Total Losses: 0 1440 118 73 32 11 12 15 12464 Todd A. Wilson / Kerry Garner 11627 2154 Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 11930 0Avg: 3210 C3 C2 N/A % 24 hr Max YP AgNO3 0.50 (lb/100ft 2) 2.361 0.5 Min N/A Avg 10 ASG Todd A. Wilson / Kerry Garner C5i C4i C5n Tuff 0 Grvl Coal Max: 87.4/12.6 PDC 12250'11 7.85 7.90 53 9 9774' Sst Silt Siltst Clyst Cht Gas Breakdown Sd Lst Sh Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water N/A North Slope 12314 Daily Charges Avg 45.0 181.0 Pioneer Natural Resources ODSN-29 Oooguruk 34 11/20/2012 12314' 0 05 0 Ambient Air Pit Room 89 Chromatograph (ppm) 38 C4n 12 Min Max Max THTS Cor Solids New 4.4 N/A N/A Avg 259 73 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3337 3.554 384' Drilling 6.125" Lateral J. Polya / J. Cortez 2151.0 12250' Flow In (gpm) Current Pump & Flow Data: N/A 223.0 12284' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 400 61.4 Depth Gas (units) H2S Data Sample Line Avg: 0 C1 Hole Condition On Bot Hrs 12314'16.86 2151 24 hr Recap: Time drilling and sliding to 11961' holding 10.0 ppg EMW w/ MPD. Rotary drilling to 12250' @ 150' per hr. Check trip to SdTrk pt 11900'. TIH to 12250'. Rotary drilling and sliding to 12346' @ 150' hr @ report time. Max gas: 2151 units. Avg gas: 223 units. Total Losses: 0 PWD Drilling All Circ Avg Diam 619.5 bbls 6.125 Max: Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Rotary drilling and sliding to 12469'. MADD Pass all slide areas. C/O MPD RCD bearing. Drilling and Sliding to 12800' @ report time. Max gas: 2141 units. Avg gas: 213 units. Total Losses: 0 PWD Drilling All Circ Avg Diam 619.5 bbls 6.125 Max: Hole Condition On Bot Hrs 12799'14.73 2141 Depth Gas (units) 70 H2S Data Sample Line Avg: 0 C1 213.0 12783' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 41 30.1 485' Drilling 6.125" Lateral J. Polya / J. Cortez 2141.0 12470' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 2755 3.554 N/A N/A Avg 218 64 Total Charges: Min Max Max THTS Cor Solids New 3.8 0 Ambient Air Pit Room 630 Chromatograph (ppm) 254 C4n 73 18 20 39 Pioneer Natural Resources ODSN-29 Oooguruk 35 11/21/2012 12799' North Slope 12799 Daily Charges Avg 19.3 184.0 N/A Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 9774' 88.4/11.6 PDC 12781'12 7.85 7.90 54 9 C5i C4i C5n Tuff 0 Grvl Coal Max: Todd A. Wilson / Kerry Garner (lb/100ft 2) 2.618 0.5 Min N/A Avg 9 ASG N/A % 24 hr Max YP AgNO3 0.60 12314 0Avg: 15911 C3 C2 30 Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Rotary drilling and sliding to 13763' holding 9.8 ppg EMW at shoe w/ MPD. Max gas: 883 units. Avg gas: 221 Total Losses: 0 PWD Drilling All Circ Avg Diam 619.5 bbls 6.125 Max: Hole Condition On Bot Hrs 13745'22.73 883 Depth Gas (units) 80 H2S Data Sample Line Avg: 0 C1 221.0 12914' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 30 172.9 945' Drilling 6.125" Lateral J. Polya / J. Cortez 883.0 13168' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3580 3.554 N/A N/A Avg 259 73 Total Charges: Min Max Max THTS Cor Solids New 5.4 0 Ambient Air Pit Room 218 Chromatograph (ppm) 100 C4n 30 7 715 Pioneer Natural Resources ODSN-29 Oooguruk 36 11/22/2012 13745' North Slope 13745 Daily Charges Avg 39.1 388.5 N/A Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 9774' 91.5/8.5 PDC 13695'15 8.00 8.10 61 9 C5i C4i C5n Tuff 0 Grvl Coal Max: Todd A. Wilson / Kerry Garner (lb/100ft 2) 2.609 0.35 Min N/A Avg 11 ASG N/A % 24 hr Max YP AgNO3 0.45 12799 0Avg: 4273 C3 C2 20 Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 13745 0Avg: 3704 C3 C2 N/A % 24 hr Max YP AgNO3 0.45 (lb/100ft 2) 2.606 0.30 Min N/A Avg 11 ASG Todd A. Wilson / Kerry Garner C5i C4i C5n Tuff 0 Grvl Coal Max: 91.5/8.5 PDC 14335'19 8.05 8.10 60 9 9774' Sst Silt Siltst Clyst Cht Gas Breakdown Sd Lst Sh Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water N/A North Slope 14341 Daily Charges Avg 31.6 314.1 Pioneer Natural Resources ODSN-29 Oooguruk 37 11/23/2012 14341' 8 89 0 Ambient Air Pit Room 124 Chromatograph (ppm) 50 C4n 20 Min Max Max THTS Cor Solids New 5.8 N/A N/A Avg 259 73 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 4048 3.554 596' Drilling 6.125" Lateral J. Polya / J. Cortez 896 13942' Flow In (gpm) Current Pump & Flow Data: N/A 204 14091' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) Depth Gas (units) H2S Data Sample Line Avg: 0 C1 Hole Condition On Bot Hrs 14341'22.73 896 24 hr Recap: Rotary drilling and sliding to 13887' holding 9.8 ppg EMW at shoe w/ MPD. C/O MPD RCD bearing. Rotary time drilling and sliding to 14358' holding 9.8 ppg EMW at shoe w/ MPD @ report time. Max gas: 896 units. Avg gas: 204 units Total Losses: 0 PWD Drilling All Circ Avg Diam 619.5 bbls 6.125 Max: Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Rotary drilling and sliding to 14404' holding 9.8 ppg EMW at shoe w/ MPD. Working thru multiple intermittent pack offs. Circ 4x B/Up w/ intermittent pack offs. Drill to 14464'. Pk off / lost circ. Stg pumps & rot to full rate. TOH to 13374'. Tight f/ 14394' to 13500'. Circ 1x B/Up. C/O MPD RCD bearing @ report time. Max gas: 6458 units. Avg gas: 548 units Total Losses: -10 bbls PWD Drilling All Circ Avg Diam 619.5 bbls 6.125 Max: Hole Condition On Bot Hrs 14462'2.6 6458 Depth Gas (units) 80 H2S Data Sample Line Avg: 0 C1 548 14462' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 28 0.0 121' Drilling 6.125" Lateral J. Polya / J. Cortez 6458 14426' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 4048 3.554 N/A N/A Avg 259 73 Total Charges: Min Max Max THTS Cor Solids New 7.1 0 Ambient Air Pit Room 11234 Chromatograph (ppm) 4988 C4n 1228 263 280 662 Pioneer Natural Resources ODSN-29 Oooguruk 38 11/24/2012 14462' North Slope 14462 Daily Charges Avg 8.1 48.0 N/A Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 9774' 93.1/6.9 PDC 14462'15 8.05 8.05 61 9 C5i C4i C5n Tuff 0 Grvl Coal Max: Todd A. Wilson / Kerry Garner (lb/100ft 2) 2.610 0.25 Min N/A Avg 10 ASG N/A % 24 hr Max YP AgNO3 0.50 14341 0Avg: 161806 C3 C2 20 Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: C/O MPD RCD bearing. C/O Saver sub. TOH to 13117'. Circ. TIH and begin OH troughing SdTrk #2 from 13130' to 13160'. Time drlg / time sliding to 13300' @ report time.. Max gas: 295 units. Avg gas: 79 units Total Losses: 0 bbls PWD Drilling All Circ Avg Diam 619.5 bbls 6.125 Max: Hole Condition On Bot Hrs 13300'6.19 295 Depth Gas (units) 80 H2S Data Sample Line Avg: 0 C1 79 13230' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 35 5..3 140' Drilling 6.125" Lateral R .Klepzig / J. Cortez 295 13275' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 4048 3.554 N/A N/A Avg 259 73 Total Charges: Min Max Max THTS Cor Solids New 5.2 0 Ambient Air Pit Room 135 Chromatograph (ppm) 41 C4n 12 10 77 Pioneer Natural Resources ODSN-29 Oooguruk 39 11/25/2012 13300' North Slope 13300 Daily Charges Avg 5.0 78.3 N/A Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 9774' 92.6/7.4 PDC 13292'19 7.95 8.05 72 9 C5i C4i C5n Tuff 0 Grvl Coal Max: Todd A. Wilson / Kerry Garner (lb/100ft 2) 2.603 0.30 Min N/A Avg 12 ASG N/A % 24 hr Max YP AgNO3 0.25 13160 0Avg: 6561 C3 C2 20 Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 13300 0Avg: 873 C3 C2 20 N/A % 24 hr Max YP AgNO3 0.50 (lb/100ft 2) 3.481 0.45 Min N/A Avg 13 ASG Todd A. Wilson / Kerry Garner C5i C4i C5n Tuff 0 Grvl Coal Max: 77.0/10.0 PDC 13292'20 10.00 10.00 85 9 9774' Sst Silt Siltst Clyst Cht Gas Breakdown Sd Lst Sh Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water N/A North Slope 13330 Daily Charges Avg 1.2 5.9 Pioneer Natural Resources ODSN-29 Oooguruk 40 11/26/2012 13330' 0 00 0 Ambient Air Pit Room 36 Chromatograph (ppm) 15 C4n 5 Min Max Max THTS Cor Solids New 12.4 N/A N/A Avg 259 73 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 4048 3.554 30' Tripping R .Klepzig / J. Cortez 284 13330' Flow In (gpm) Current Pump & Flow Data: N/A 42 13322' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 10 0.0 Depth Gas (units) 80 H2S Data Sample Line Avg: 0 C1 Hole Condition On Bot Hrs 13330'6.27 284 24 hr Recap:Time drlg / time sliding to 13309'.MADD Pass slide areas. Time drlg /time sliding to 13330'. Circ B/Up. Pmp18 bbls 10.0 ppg Hi vis spacer. Chase w/ 10.0 ppg KWM. Pmp out to 9746'.Displace active system frm 7.9 ppg MOBM to 10.0 ppg KWM. Remove RCD bearing. Inst Trip Nip. POOH to 6857'. Pmp slug and TOH laying down bad 4" DP. TOH to BHA. Removing nukes @report time. Max gas: 284 units. Avg gas: 42 units Total Losses: 0 bbls PWD Drilling All Circ Avg Diam 619.5 bbls 6.125 Max: Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Lay Dn BHA #9. P/Up DP to 2112. Circ 1.5 x DP vol. TOH & rack back stds. Remove wear bshg. Test BOPs. Btm ram door tst failure. C/ O seal. Retest same. Good test. Inst wear bshg. R/Dn tst equip. P/Up DP to 1163'. Rk bk stds. P/Up BHA # 10. RIH. Shallow test MWD @ report time. Max gas: 0 units. Avg gas: 0 units Total Losses: -0 bbls PWD Drilling All Circ Avg Diam 619.5 bbls 6.125 Max: Hole Condition On Bot Hrs 13330'0 0 Depth Gas (units) 80 H2S Data Sample Line Avg: 0 C1 0 0' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 0.0 0.0 0' TIH w/ BHA #10 R .Klepzig / J. Cortez 0 0' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 0 3.554 New 10-20K N/A N/A Avg 0 0 Total Charges: Min Max Max THTS Cor Solids New 12.5 0 Ambient Air Pit Room 0 Chromatograph (ppm) 0 C4n 0 0 00 Pioneer Natural Resources ODSN-29 Oooguruk 41 11/27/2012 13330' North Slope 13330 Daily Charges Avg 6.125 0.384 0.0 0.0 N/A Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 13330' 3556'193.11 9774' 10 PDC 77.0/10.0 PDC 13330' 13330' 21 10.00 10.00 98 9 C5i C4i C5n Tuff 0 Grvl Coal Max: Todd A. Wilson / Kerry Garner (lb/100ft 2) 3.481 0.43 Min N/A Avg 15 ASG N/A % 24 hr Max YP AgNO3 0.48 90 13330 0Avg: 0 C3 C2 20 Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: TIH to 9746'. Slip & cut Drill Ln. Inst MPD RCD bearing. Pump 18 bbl 10.0 ppg Hi vis spacer. Chase and displace active system to 7.9 ppg MOBM. TIH to 11900'. Circ B/Up. TIH to 13110'. Perform directional check shots. MADD Pass f/ 12775' to 12268', and 13190' to 13110'. Time slide drilling @ report time to 13334'. Max gas: 838 units. Avg gas: 38 units Total Losses: -50 bbls PWD Drilling All Circ Avg Diam 619.5 bbls 6.125 Max: Hole Condition On Bot Hrs 13332'1.29 838 Depth Gas (units) 80 H2S Data Sample Line Avg: 0 C1 38 13331' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 23.0 1.2 2' Drilling 6.125" Lateral R .Klepzig / J. Cortez 838 13330' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 2645 3.554 New 10-20K N/A N/A Avg 203 57 Total Charges: Min Max Max THTS Cor Solids New 5.7 0 Ambient Air Pit Room 323 Chromatograph (ppm) 155 C4n 44 9 922 Pioneer Natural Resources ODSN-29 Oooguruk 42 11/28/2012 13332' North Slope 13332 Daily Charges Avg 6.125 0.384 0.1 1.4 N/A Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 13330' 3556'193.11 9774' 10 PDC 86.0/8.0 PDC 13330' 13330' 20 8.05 8.05 75 9 C5i C4i C5n Tuff 0 Grvl Coal Max: Todd A. Wilson / Kerry Garner (lb/100ft 2) 2.631 0.30 Min N/A Avg 10 ASG N/A % 24 hr Max YP AgNO3 0.75 90 13330 0Avg: 6959 C3 C2 20 Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Continue drilling 6 1/8" Production Lateral. Time drill from 13,333' to 13,368'. Directional drill from 13,368' to 13,488' @ report time. Max gas: 285 units. Avg gas: 28 units Total Losses: 0 bbls PWD Drilling All Circ Avg Diam 619.5 bbls 6.125 Max: Hole Condition On Bot Hrs 13488'44.06 285 Depth Gas (units) 80 H2S Data Sample Line Avg: 0 C1 28 13424' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 111 129.0 156' Drilling 6 1/8" Lateral R .Klepzig / J. Cortez 285 13363' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3390 3.554 New 10-20K N/A N/A Avg 203 67 Total Charges: Min Max Max THTS Cor Solids New 4.5 0 Ambient Air Pit Room 18 Chromatograph (ppm) 11 C4n 7 0 00 Pioneer Natural Resources ODSN-29 Oooguruk 43 11/29/2012 13488' North Slope 13488 Daily Charges Avg 6.125 0.384 5.9 76.8 N/A Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 13330' 3556'193.11 9774' 10 PDC 87.3/8.0 PDC 13355' 13330' 16 7.85 7.90 66 9 C5i C4i C5n Tuff 0 Grvl Coal Max: Todd A. Wilson / Kerry Garner (lb/100ft 2) 2.634 0.25 Min N/A Avg 11 ASG N/A % 24 hr Max YP AgNO3 0.50 90 13332 0Avg: 323 C3 C2 20 Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Continue drilling 6 1/8" Production Lateral. Directional drill from 13,480' to 13,774'. Trough from 13,774' to 14,458' maintaining 9.8 ppg EMW at shoe with MPD. MADD Pass all slide areas. Drilling ahead @ report time. Max gas: 3481 units. Avg gas: 384 units Total Losses: 0 bbls PWD Drilling All Circ Avg Diam 619.5 bbls 6.125 Max: Hole Condition On Bot Hrs 14458'13.59 3481 Depth Gas (units) 10 H2S Data Sample Line Avg: 0 C1 384 13706' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 150 105.4 970' Drilling 6 1/8" Lateral R .Klepzig / J. Cortez 3481 14278' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3400 3.554 New 10-20K N/A N/A Avg 239 67 Total Charges: Min Max Max THTS Cor Solids New 4.9 0 Ambient Air Pit Room 2037 Chromatograph (ppm) 820 C4n 212 45 51 108 Pioneer Natural Resources ODSN-29 Oooguruk 44 11/30/2012 14458' North Slope 14458 Daily Charges Avg 6.125 0.384 105.3 201.7 N/A Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 13330' 3556'193.11 9774' 10 PDC 87.4/7.5 PDC 14177' 13330' 16 7.90 8.00 63 9 C5i C4i C5n Tuff 0 Grvl Coal Max: Todd A. Wilson / Kerry Garner (lb/100ft 2) 2.626 0.25 Min N/A Avg 11 ASG N/A % 24 hr Max YP AgNO3 0.50 90 13488 0Avg: 46804 C3 C2 90 Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Continue drilling 6 1/8" Production Lateral from 14,458' to 15,716' (TD). Circulate 2.5 times Open Hole volume. Change out MPD bearing. Maintaining 9.8 ppg EMW at shoe with MPD. Backream from 15,716' to 13,984'. EMW at 7" shoe increased to 10.1 ppg. Slight losses were encountered. Decreased EMW to 9.9 ppg. Continue to backream to shoe at report time. Max gas: 2651 units. Avg gas: 555 units Total Losses: -15 bbls PWD Drilling All Circ Avg Diam 619.5 bbls 6.125 Max: Hole Condition On Bot Hrs 15716'46.04 2651 Depth Gas (units) H2S Data Sample Line Avg: 0 C1 555 15342' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 78 0.0 1258' Backream to shoe R .Klepzig / J. Cortez 2651 15525' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 3400 3.554 New 10-20K N/A N/A Avg 239 67 Total Charges: Min Max Max THTS Cor Solids New 5.5 0 Ambient Air Pit Room 1149 Chromatograph (ppm) 578 C4n 196 59 58 91 Pioneer Natural Resources ODSN-29 Oooguruk 45 12/1/2012 15716' North Slope 15716 Daily Charges Avg 6.125 0.384 33.7 135.0 N/A Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 13330' 3556'193.11 9774' 10 PDC 86.2/8.0 PDC 15716' 13330' 20 8.00 8.10 70 9 C5i C4i C5n Tuff 0 Grvl Coal Max: Todd A. Wilson / Kerry Garner (lb/100ft 2) 2.602 0.28 Min N/A Avg 11 ASG N/A % 24 hr Max YP AgNO3 0.50 90 14458 0Avg: 23632 C3 C2 100 Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Finish back reaming from 13,984' to 9,746' running HIS log 240 gpm 50 rpm ( packed off at 11,820' ). Decreased EMW to 9.8 ppg while back reaming out of hole. Circulate bottoms ups. Change out swivel packing. Trip in hole at report time. Max gas: 841 units. Avg gas: 69 units Total Losses: -0 bbls PWD Drilling All Circ Avg Diam 619.5 bbls 6.125 Max: Hole Condition On Bot Hrs 15716'46.04 841 Depth Gas (units) H2S Data Sample Line Avg: 0 C1 69 0' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 15 0.0 0' RIH to TD R .Klepzig / J. Cortez 841 15716' Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 2880 3.554 New 10-20K N/A N/A Avg 240 68 Total Charges: Min Max Max THTS Cor Solids New 5.3 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODSN-29 Oooguruk 46 12/2/2012 15716' North Slope 15716 Daily Charges Avg 6.125 0.384 0.0 0.0 N/A Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 13330' 3556'193.11 9774' 10 PDC 86.2/8.0 PDC 15716' 13330' 16 8.00 8.10 64 9 C5i C4i C5n Tuff 0 Grvl Coal Max: Todd A. Wilson / Kerry Garner (lb/100ft 2) 2.629 0.30 Min N/A Avg 12 ASG N/A % 24 hr Max YP AgNO3 0.55 90 15716 0Avg: C3 C2 100 Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 15716 0Avg: C3 C2 100 N/A % 24 hr Max YP AgNO3 0.45 90 (lb/100ft 2) 3.728 0.30 Min N/A Avg 16 ASG Todd A. Wilson / Kerry Garner C5i C4i C5n Tuff 0 Grvl Coal Max: 78.6/9.5 PDC 15716' 13330' 24 10.00 10.00 75 9 13330' 3556'193.11 9774' 10 PDC Sst Silt Siltst Clyst Cht Gas Breakdown Sd Lst Sh Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water N/A North Slope 15716 Daily Charges Avg 6.125 0.384 0.0 0.0 Pioneer Natural Resources ODSN-29 Oooguruk 47 12/3/2012 15716' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids New 11.6 New 10-20K N/A N/A Avg 240 68 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft 2880 3.554 0' POOH w/ 6 1/8" BHA R .Klepzig / J. Cortez 10000 15716' Flow In (gpm) Current Pump & Flow Data: N/A 292 0' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 16 0.0 Depth Gas (units) H2S Data Sample Line Avg: 0 C1 Hole Condition On Bot Hrs 15716'46.04 10000 24 hr Recap: Continue tripping in hole to TD at 15,716'. Break circulation and displace wellbore from 8.0 ppg ENVIROMUL to 10.0 ppg KWM ENVIROMUL (pumped 50 bbls Hi-Vis 10 ppg spacer). 10000 units gas while circulating bottoms up. MPD maintained 9.8 ppg EMW at shoe. Rig down MPD. Pull out of hole from 15,716' to 15,139'-swabbing. Pump out from 15,139' to 9,746' 3 bpm. Circulate bottoms up 2 times. Pull out of from 9,746' to 9,170'-swabbing. Circulate bottoms up. Pull out of hole from 9,170' to 6,664' -some swabbing. Circulate bottoms up. Pump out from 6,664' to 5,314' at 3 bpm. Pull out of hole from 5,314' to 3,677' at report time. Max gas: 10000 units. Avg gas: 292 units Total Losses: -35 bbls PWD Drilling All Circ Avg Diam 619.5 bbls 6.125 Max: Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Pulled out of the hole from 3,677' to surface and laid down 6 1/8" BHA. Picked up and flushed 24 joints of 4" heavy weight drill pipe. Rigged up to run 4 1/2" Liner. Running in to 6,318' at report time. Max gas: 1 unit. Avg gas: 0 units Total Losses: -6 bbls PWD Drilling All Circ Avg Diam 619.5 bbls 6.125 Max: Hole Condition On Bot Hrs 15716'0 Depth Gas (units) H2S Data Sample Line Avg: 0 C1 0 0' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 0 0.0 0' Run in hole with Liner R .Klepzig / J. Cortez 1 Circ Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft - 3.554 New 10-20K N/A N/A Avg - - Total Charges: Min Max Max THTS Cor Solids New 11.7 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODSN-29 Oooguruk 48 12/4/2012 15716' North Slope Daily Charges Avg 6.125 0.384 0.0 0.0 N/A Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 13330' 3556'193.11 9774' 10 PDC 89.2/10.8 PDC 15716' 13330' 24 10.00 10.00 90 9 C5i C4i C5n Tuff 0 Grvl Coal Max: David Mckechnie/Andrew Bongard (lb/100ft 2) 3.704 0.30 Min N/A Avg 13 ASG N/A % 24 hr Max YP AgNO3 0.45 90 0Avg: C3 C2 100 Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 0Avg: C3 C2 N/A % 24 hr Max YP AgNO3 0.45 90 (lb/100ft 2) 3.704 0.30 Min N/A Avg 14 ASG David Mckechnie/Andrew Bongard C5i C4i C5n Tuff 0 Grvl Coal Max: 89.2/10.8 PDC 15716' 13330' 22 10.00 10.00 85 9 13330' 3556'193.11 9774' 10 PDC Sst Silt Siltst Clyst Cht Gas Breakdown Sd Lst Sh Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water N/A North Slope Daily Charges Avg 6.125 0.384 0.0 0.0 Pioneer Natural Resources ODSN-29 Oooguruk 49 12/5/2012 15716' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids New 11.7 New 10-20K N/A N/A Avg - - Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft - 3.554 0' Setting ECPs R .Klepzig / J. Cortez 32 Circ Flow In (gpm) Current Pump & Flow Data: N/A 5 0' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 0 0.0 Depth Gas (units) H2S Data Sample Line Avg: 0 C1 Hole Condition On Bot Hrs 15716'0 24 hr Recap: Continued to run in the hole with 4 1/2" lower completion. Circulated bottoms up at 6,188' at 3 bbls per minute. Continued running in to 15706, filling pipe every 10 stands. Circulated, stepping up to 2 bbls per minute. Rigged up cement line and inflating ECP's (10 in total) with cement at report time. Max gas: 32 unit. Avg gas: 5 units Total Losses: -26 bbls PWD Drilling All Circ Avg Diam 619.5 bbls 6.125 Max: Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Rigged down Cement line. Set liner top packer. Test liner top packer/annulus. Displaced the well to 10.00 ppg brine. Slip and cut drill line. Pulled out of the hole and laid down 4" drill pipe and liner running tool. Rigged up to run 4 1/5" tubing. Running in the hole to 1415' at report time. Max gas: 270 unit. Avg gas: 18 units Total Losses: 0 bbls PWD Drilling All Circ Avg Diam - 6.125 Max: Hole Condition On Bot Hrs 15716'0 Depth Gas (units) H2S Data Sample Line Avg: 0 C1 18 0' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 0 0.0 0' Setting ECPs R .Klepzig / J. Cortez 270 Circ Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft - 3.554 New 10-20K N/A N/A Avg - - Total Charges: Min Max Max THTS Cor Solids New - 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODSN-29 Oooguruk 50 12/6/2012 15716' North Slope Daily Charges Avg 6.125 0.384 0.0 0.0 N/A Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 13330' 3556'193.11 9774' 10 PDC - PDC 15716' 13330' -10.00 10.00 - 9 C5i C4i C5n Tuff 0 Grvl Coal Max: David Mckechnie/Andrew Bongard (lb/100ft 2) -- Min N/A Avg - ASG N/A % 24 hr Max YP AgNO3 - 90 0Avg: C3 C2 Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 24 hr Recap: Continued to run 4 1/2" tubing until the hanger was landed. Tested top and bottom hanger seals to 10,000 PSI for 30 minutes and tested tubing to 3500 PSI for 30 minutes. Laying down landing joint at report time. Max gas: 0 units. Avg gas: 0 units Total Losses: 0 bbls PWD Drilling All Circ Avg Diam - 6.125 Max: Hole Condition On Bot Hrs 15716'0 Depth Gas (units) H2S Data Sample Line Avg: 0 C1 0 0' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 0 0.0 0' Lay down Landing Joint R .Klepzig / J. Cortez 0 - Flow In (gpm) Current Pump & Flow Data: N/A Flow In (spm) SPP (psi) Gallons/stroke Max @ ft - 3.554 New 10-20K N/A N/A Avg - - Total Charges: Min Max Max THTS Cor Solids New - 0 Ambient Air Pit Room Chromatograph (ppm) C4n Pioneer Natural Resources ODSN-29 Oooguruk 51 12/7/2012 15716' North Slope Daily Charges Avg 6.125 0.384 0.0 0.0 N/A Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water Gas Breakdown Sd Lst Sh Sst Silt Siltst Clyst Cht 13330' 3556'193.11 9774' 10 PDC - PDC 15716' 13330' -10.00 10.00 - 9 C5i C4i C5n Tuff 0 Grvl Coal Max: David Mckechnie/Andrew Bongard (lb/100ft 2) -- Min N/A Avg - ASG N/A % 24 hr Max YP AgNO3 - 90 0Avg: C3 C2 Customer: Report #: Well: Date: Area: 24:00 Depth Location: Progress 24 hrs: Rig: Rig Activity: Job No.: Report For: 8 ROP & Gas: . Mud Data: Density (ppg) Viscosity Depth ft in out (sec/qt) BHA Run # Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to to to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - Pumps Off Gas; PG - Produced Gas; RG - Ream Gas; T-- - Trip…; F-- - Formation…; E-- - Early… Logging Engineers: * 10000 units = 100% Gas In Air 0Avg: C3 C2 N/A % 24 hr Max YP AgNO3 - 90 (lb/100ft 2) -- Min N/A Avg - ASG David Mckechnie/Andrew Bongard C5i C4i C5n Tuff 0 Grvl Coal Max: - PDC 15716' 13330' -- - - 9 13330' 3556'193.11 9774' 10 PDC Sst Silt Siltst Clyst Cht Gas Breakdown Sd Lst Sh Nabors 19AC AK-AM-0009650310 6.125 0.385 cP PV Size NAP/Water N/A North Slope Daily Charges Avg 6.125 0.384 0.0 0.0 Pioneer Natural Resources ODSN-29 Oooguruk 52 12/8/2012 15716' 0 Ambient Air Pit Room Chromatograph (ppm) C4n Min Max Max THTS Cor Solids New - New 10-20K N/A N/A Avg - - Total Charges: Flow In (spm) SPP (psi) Gallons/stroke Max @ ft - 3.554 0' R .Klepzig / J. Cortez 0 - Flow In (gpm) Current Pump & Flow Data: N/A 0 0' Depth Ann Corr Current R.O.P. (ft/hr) Gas (units) 0 0.0 Depth Gas (units) H2S Data Sample Line Avg: 0 C1 Hole Condition On Bot Hrs 15716'0 24 hr Recap: Installed and tested BPV. Nippled down blow out preventer equipment. Nippled up and tested tree. Laid down 4" drill pipe. Rigged down gas equipment and preparing to move to ODSN-24 at report time. Max gas: 0 units. Avg gas: 0 units Total Losses: 0 bbls PWD Drilling All Circ Avg Diam - 6.125 Max: W E L L N A M E : OD S N - 2 9 LO C A T I O N : Oooguruk OP E R A T O R : Pi o n e e r N a t u r a l R e s o u r c e s AREA:North Slope MU D C O : Ba r o i d ST A T E : Alaska RI G : Na b o r s 1 9 A C SPUD:15-Oct-12 SP E R R Y J O B : AK - A M - 0 0 0 9 6 5 0 3 1 0 TD:1-Dec-12 BI T RE C O R D BH A # B i t # S D L Ru n # Bi t T y p e B i t Si z e De p t h I n D e p t h Ou t Fo o t a g e B i t Ho u r s TF A A V G RO P WO B (m a x ) RP M (m a x ) SP P (m a x ) FL O W G P M (m a x ) Bi t G r a d e R e m a r k s 1 1 1 0 0 B a k e r M X L - 1 V 1 4 . 5 1 5 8 2 4 3 7 2 2 7 9 2 1 . 2 5 0 . 6 9 9 5 1 0 7 2 2 6 0 1 6 0 0 6 0 0 0 - 1 - W T - N - E - I - N O - B H A P O O H t o c h a n g e m o t o r b e n d 2 1 r r 1 2 0 0 B a k e r M X L - 1 V 1 4 . 5 2 4 3 7 4 1 4 5 1 7 0 8 1 5 . 6 4 0 . 6 9 9 5 1 0 9 3 0 8 0 3 0 0 0 8 0 0 2 - 3 - W T - A - E - I - N O - T D D r i l l e d t o 1 1 - 3 / 4 " C a s i n g P o i n t 3 1 r r 2 3 0 0 B a k e r M X L - 1 V 1 4 . 5 4 1 4 5 4 1 4 5 0 - 0 . 6 9 9 5 - - - - - 2 - 3 - W T - A - E - I - N O - T D C l e a n o u t r u n 4 2 4 0 0 B a k e r G T - C 1 1 0 . 6 2 5 4 1 4 5 4 1 6 5 2 0 1 . 7 8 0 . 8 5 6 0 1 1 3 5 1 3 0 2 5 5 0 7 0 0 0 - 2 - C D - A - E - I - J D - B H A C l e a n o u t s h o e a n d d r i l l r a t h o l e 5 3 5 0 0 H D B S F X G 6 5 s 1 0 . 6 2 5 4 1 6 5 7 2 7 0 3 1 0 5 3 4 . 1 1 1 . 4 6 4 2 9 1 1 4 1 4 5 4 4 0 8 2 5 0 - 0 - N O - A X - I - E - R - T D D r i l l e d I n t e r m e d i a t e 1 6 4 6 0 0 B a k e r G T - C 1 8 . 5 7 2 7 0 7 2 9 0 2 0 0 . 4 5 0 . 8 6 2 1 4 4 2 0 8 0 1 6 5 0 6 0 0 2 - 1 - B T - M - E - I - C D - T D C l e a n o u t s h o e a n d d r i l l r a t h o l e 7 5 7 0 0 H D B S S F E 5 6 M 8 . 5 0 7 2 9 0 9 7 7 4 2 4 8 4 4 4 . 5 5 1 . 0 8 3 0 5 6 2 8 1 0 0 4 0 0 0 7 0 0 1 - 2 - C T - A - X - I - S D - T D D r i l l e d I n t e r m e d i a t e 2 8 6 8 0 0 B a k e r S T X - 1 6 . 1 2 5 9 7 5 9 9 7 5 9 0 - 0 . 9 2 0 4 - - - 2 4 2 0 2 3 5 2 - 1 - C T - E - I - N O - B H A C l e a n O u t R u n 9 7 9 0 0 B a k e r - H C D 5 0 5 Z X 6 . 1 2 5 9 7 7 4 1 2 4 6 4 2 6 9 0 3 6 . 0 7 0 . 3 8 5 0 7 5 - - - - 1 - 1 - C T - N - X - I - L N - B H A P B 1 9b 7 r r 1 1 0 0 0 B a k e r - H C D 5 0 5 Z X 6 . 1 2 5 1 1 9 3 0 1 4 4 6 4 2 5 3 4 6 7 . 0 9 0 . 3 8 5 0 3 8 3 5 9 0 3 8 0 0 2 6 0 1 - 1 - C T - N - X - I - L N - B H A P B 2 9c 7 r r 2 1 1 0 0 B a k e r - H C D 5 0 5 Z X 6 . 1 2 5 1 3 1 6 0 1 3 3 3 0 1 7 0 2 5 . 0 1 0 . 3 8 5 0 7 8 4 0 3 3 5 0 2 6 0 1 - 1 - C T - N - X - I - L N - B H A 10 8 1 2 0 0 H D B S F X 5 5 6 . 1 2 5 1 3 3 3 0 1 5 7 1 6 1 3 8 6 14 3 . 0 0 0. 3 8 3 5 2 8 4 0 9 0 3 8 0 0 2 6 0 2 - 1 - B T - N - X - I - C T - T D D r i l l e d P r o d u c t i o n L a t e r a l W E L L N A M E : OD S N - 2 9 LO C A T I O N : Oo o g u r u k OP E R A T O R : Pi o n e e r N a t u r a l R e s o u r c e s AR E A : No r t h S l o p e MU D C O : Ba r o i d ST A T E : A la s k a RI G : Na b o r s 1 9 A C SP U D : 15 - O c t - 1 2 SP E R R Y J O B : A K- A M - 0 0 0 9 6 5 0 3 1 0 TD : 1- D e c - 1 2 W a t e r - a n d O i l - B a s e d M u d R e c o r d Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e S o l i d s Oi l / W a t e r Sd P m p H M B T P f / M f C h l o r H a r d R e m a r k s ft - M D p p g s e c l b / 1 0 0 l b / 1 0 0 f t 2 m / 3 0 m R h e o m e t e r 3 2 n d s % % % p p b E q v m g / l C a + + 16 - O c t 2 1 5 2 9 . 4 0 6 5 1 6 3 2 1 4 / 2 4 / 2 9 1 0 . 4 6 4 / 4 8 / 3 9 / 3 0 / 1 5 / 1 3 2 / 0 4 . 9 2. 0 / 9 1 . 8 0 . 0 1 0 . 6 0 9 . 9 1 2 . 5 0 . 2 5 / 0 . 4 5 2 4 5 0 0 8 0 0 D r illing 14.5" Surface Interval 17 - O c t 3 3 0 0 9 . 5 0 5 9 1 4 3 2 1 8 / 2 4 / 2 9 7 . 2 6 0 / 4 6 / 4 1 / 3 3 / 1 9 / 1 7 2 / 0 6 . 8 2. 5 / 8 8 . 8 0 . 2 0 0 . 5 0 1 0 . 0 1 4 . 0 0 . 2 5 / 0 . 4 5 2 4 0 0 0 7 2 0 D r illing 14.5" Surface Interval 18 - O c t 4 1 4 5 9 . 6 0 5 3 1 3 2 8 1 5 / 1 9 / 3 2 9 . 0 5 4 / 41 / 3 7 / 3 2 / 1 9 / 1 4 2 / 0 8 . 1 2 . 5 / 8 8 . 2 0 . 2 0 0 . 3 0 9 . 5 17 . 0 0 . 2 0 / 0 . 5 0 2 4 5 0 0 6 8 0 R u n 1 1 3 / 4 " C a s ing 19 - O c t 4 1 4 5 9 . 5 0 4 6 6 2 6 1 3 / 1 7 / 2 3 1 0 . 8 3 8 / 32 / 2 6 / 2 1 / 1 4 / 1 3 2 / 0 7 . 3 2 . 0 / 8 9 . 5 0 . 2 0 0 . 3 0 9 . 9 15 . 0 0 . 2 0 / 0 . 5 0 2 4 0 0 0 6 4 0 T O O H w / 1 1 3 / 4 " Casing 20 - O c t 4 1 4 5 9 . 4 5 4 5 9 2 1 1 5 / 1 9 / 2 7 9 . 4 3 9 / 30 / 2 7 / 2 2 / 1 6 / 1 5 2 / 0 6 . 9 1 . 5 / 9 0 . 3 0 . 2 0 0 . 3 0 9 . 7 1 7 . 0 0 . 2 0 / 0 . 7 0 2 4 0 0 0 6 8 0 B a c k r e a m i n g 21 - O c t 4 1 4 5 9 . 5 0 4 6 1 1 2 1 1 4 / 1 8 / 2 6 8 . 8 4 3 / 32 / 2 6 / 2 1 / 1 5 / 1 3 2 / 0 7 . 4 1 . 5 / 9 0 . 0 0 . 1 0 1 . 2 0 9 . 7 18 . 0 0 . 2 0 / 0 . 9 0 2 1 0 0 0 6 8 0 R u n 1 1 3 / 4 " C a s ing 22 - O c t 4 1 4 5 9 . 5 0 4 7 8 2 0 1 4 / 1 8 / 2 4 1 0 . 1 3 6 / 28 / 2 5 / 2 0 / 1 5 / 1 3 2 / 0 7 . 4 1 . 0 / 9 0 . 5 0 . 1 0 0 . 2 0 9 . 6 1 9 . 0 0 . 2 0 / 1 . 1 0 2 0 0 0 0 7 2 0 T e s t i n g B O P s Da t e D e p t h W t V i s P V Y P G e l s H T H P R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R 6/ R 3 Ca k e S o l i d s Oi l / W a t e r Al k a PO M Ex c e s s Li m e El e c St a b Ca C l 2 W P S L G S / H G S A S G R e m a r k s ft - M D p p g s e c l b / 1 0 0 lb / 1 0 0 f t 2 m/ 3 0 m R h e o m e t e r 3 2 n d s % % m l p p b v o l t s p p b p p m p p b A S G 23 - O c t 4 1 6 5 1 0 . 5 5 8 5 3 3 1 8 1 1 / 1 5 / 1 9 2 . 2 8 4 / 5 1 / 2 9 / 3 6 / 1 0 / 8 0 / 1 1 7 6 4 . 5 / 1 7 . 5 N /A 7 . 5 1 8 7 2 2 . 3 8 1 4 0 0 0 1 1 1 1 . 8 7 / 6 9 . 9 3 . 0 4 6 Lay Down BHA 24 - O c t 5 0 0 0 1 0 . 5 5 7 7 3 3 2 0 1 2 / 1 7 / 2 1 2 . 1 89 / 5 3 / 4 2 / 2 9 / 1 4 / 1 2 0 / 2 1 7 . 4 6 4 . 4 / 1 7 . 3 N / A 6 . 7 3 1 2 9 8 2. 5 8 1 3 7 7 3 7 1 1 7 . 8 5 / 6 5 . 2 1 3 . 0 0 8 Drill Intermediate 1 25 - O c t 6 1 6 6 1 0 . 6 5 7 0 3 9 2 2 1 3 / 1 9 / 2 5 2 . 0 10 0 / 6 1 / 4 6 / 3 1 / 1 3 / 1 1 0 / 2 1 9 . 7 6 4 . 7 / 1 5 . 0 N / A 6 . 8 6 1 4 3 8 0. 9 3 1 0 4 9 1 2 1 4 8 . 9 0 / 4 9 . 0 7 2 . 8 7 1 Drill Intermediate 1 26 - O c t 7 2 7 0 1 0 . 6 6 7 4 1 1 7 1 2 / 1 6 / 2 1 2 . 0 99 / 5 8 / 4 5 / 2 9 / 1 2 / 9 0 / 2 2 0 . 1 6 7 . 5 / 1 2 . 0 N /A 7 . 6 4 8 3 7 3 . 3 5 1 0 3 9 2 5 1 5 6 . 7 0 / 4 2 . 7 2 2 . 8 3 1 TD Intermediate 1 27 - O c t 7 2 7 0 1 0 . 6 0 7 4 3 0 1 8 1 0 / 1 6 / 2 2 2 . 2 78 / 4 8 / 3 7 / 2 5 / 1 1 / 9 0 / 2 2 0 . 6 6 7 . 6 / 1 2 . 0 N / A 6 . 9 9 7 9 7 1 . 9 1 0 1 6 6 3 1 6 4 . 7 7 / 3 6 . 8 1 2 . 7 9 4 T O O H / T I H W i p e r run 28 - O c t 7 2 7 0 1 0 . 6 0 8 7 3 0 1 8 1 1 / 1 7 / 2 1 2 . 2 78 / 4 8 / 3 7 / 2 5 / 1 1 / 1 0 0 / 2 2 0 . 3 6 6 . 7 / 1 2 . 5 N / A 5 . 8 3 9 2 1 2 . 4 1 0 3 7 9 0 1 6 1 . 85 / 3 7 . 9 7 2 . 8 0 3 T O O H W i p e r r u n / RU 9 5/8 29 - O c t 7 2 7 0 1 0 . 6 0 9 0 4 3 1 7 1 0 / 1 7 / 2 3 2 . 4 10 3 / 6 0 / 3 7 / 2 7 / 1 1 / 1 0 0 / 2 2 1 . 5 6 6 . 0 / 1 2 . 0 N / A 5 . 8 3 8 4 7 2 . 4 1 0 7 6 4 9 1 8 4 . 38 / 1 9 . 2 6 2 . 6 9 7 T I H w / 9 5 / 8 Casing 30 - O c t 7 2 7 0 1 0 . 6 0 9 3 4 1 1 9 1 2 / 1 8 / 2 6 2 . 4 10 1 / 6 0 / 4 3 / 2 6 / 1 1 / 1 0 0 / 2 2 1 . 5 6 6 . 0 / 1 2 . 0 N / A 5 . 8 3 9 2 3 3 . 0 1 1 7 8 8 5 1 8 4 . 41 / 1 8 . 6 9 2 . 9 6 4 C m n t , T O O H , B OP test Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e S o l i d s Oi l / W a t e r Sd P m p H M B T P f / M f C h l o r H a r d R e m a r k s ft - M D p p g s e c l b / 1 0 0 l b / 1 0 0 f t 2 m / 3 0 m R h e o m e t e r 3 2 n d s % % % p p b E q v m g / l C a + + 31 - O c t 7 2 9 0 1 0 . 2 0 4 6 1 0 2 4 1 1 / 1 4 / 1 8 2 . 6 4 4 / 3 4 / 2 9 / 2 3 / 1 1 / 9 1 / 3 7 . 7 1 . 0 / 9 0 . 5 0 . 0 1 0 . 9 5 1 0 . 6 1 . 0 0 0 . 2 5 / 0 . 5 5 1 4 0 0 0 . 0 5 2 0 D r ill Cmnt / rathole / TOOH 1- N o v 7 4 3 3 1 0 . 1 8 4 5 8 2 3 1 0 / 1 3 / 1 6 2 . 6 39 / 3 1 / 2 7 / 2 1 / 1 0 / 8 1 / 3 7 . 7 2 . 5 / 8 9 . 0 0 . 1 0 0 . 9 0 1 0 . 2 0 . 5 0 0 . 2 5 / 0 . 5 5 1 4 0 0 0 . 0 5 2 0 T e s t M P D / D r ill Intermediate 2 2- N o v 8 2 7 8 1 0 . 2 2 4 4 1 1 3 3 9 / 1 2 / 1 4 3 . 0 5 5 / 4 4 / 3 9 / 9 1 / 1 1 / 9 1 / 3 9 . 3 4 . 0 / 8 6 . 0 0 . 0 1 0 . 6 5 9 . 8 6 . 0 0 0 . 2 2 / 0 . 6 5 1 4 0 0 0 . 0 3 2 0 D r illing Intermediate 2 3- N o v 8 4 6 9 1 0 . 2 0 3 5 7 1 7 4 / 6 / 8 3 . 8 3 1 / 2 4 / 1 9 / 1 4 / 5 / 4 1 / 3 8 . 7 2 . 0 / 8 8 . 5 0 . 0 2 0 . 4 0 9 . 0 5 . 0 0 0 . 1 5 / . 0 6 0 1 5 0 0 0 . 0 7 6 0 D r illing Intermediate 2 4- N o v 9 5 0 8 1 0 . 2 0 3 9 1 0 2 2 5 / 6 / 8 2 . 8 4 2 / 3 2 / 2 6 / 1 9 / 7 / 5 1 / 3 8 . 6 2 . 5 / 8 8 . 0 0 . 0 1 0 . 9 0 1 0 . 4 6 . 5 0 0 . 2 5 / 0 . 6 0 1 7 0 0 0 . 0 2 4 0 D r illing Intermediate 2 5- N o v 9 7 7 4 1 0 . 2 0 4 0 9 1 6 5 / 7 / 8 3 . 8 4 1 / 31 / 2 3 / 1 7 / 6 / 5 1 / 0 8 . 9 1 . 8 / 8 8 . 5 0 . 1 0 0 . 4 0 9 . 1 6 . 5 0 0. 1 2 / 0 . 4 0 1 5 0 0 0 . 0 6 4 0 T D I n t e r m e d i a t e 2 / T O O H 6- N o v 9 7 7 4 1 0 . 2 0 3 8 1 2 1 9 4 / 6 / 8 3 . 9 4 3 / 31 / 2 4 / 1 7 / 5 / 4 2 / 3 8 . 2 2 . 0 / 8 9 . 0 0 . 0 1 0 . 5 0 8 . 6 6 . 8 0 0. 0 5 / 0 . 6 0 1 5 0 0 0 . 0 8 7 6 C i r c u l a t i n g / p u m p i n g p ills 7- N o v 9 7 7 4 1 0 . 2 0 4 1 1 1 2 1 4 / 7 / 9 4 . 2 4 3 / 32 / 2 6 / 1 9 / 6 / 4 1 / 3 8 . 2 3 . 0 / 8 8 . 0 0 . 0 1 0 . 8 5 1 0 . 8 6 . 5 0 0 . 2 0 / 0 . 5 5 1 5 0 0 0 . 0 7 6 0 C i r c u l a t i n g / p u m p i n g pills 8- N o v 9 7 7 4 1 2 . 0 0 4 3 1 1 3 2 1 2 / 1 6 / 1 8 5 . 2 5 4 / 4 3 / 3 6 / 2 9 / 1 4 / 1 2 2 / 3 1 4 . 3 2. 5 / 8 2 . 5 0 . 0 1 0 . 3 0 9 . 0 0 . 5 0 0 . 1 0 / 0 . 4 0 1 4 0 0 0 . 0 4 0 0 P O O H 9- N o v 9 7 7 4 1 1 . 2 0 4 7 1 3 2 4 6 / 1 1 / 1 4 5 . 2 5 0 / 37 / 3 1 / 2 3 / 8 / 6 2 / 0 1 1 . 7 3 . 0 / 8 4 . 5 0 . 0 1 0 . 7 0 1 0 . 7 6 .5 0 0 . 2 5 / 0 . 7 5 1 5 0 0 0 . 0 5 6 0 R u n n i n g 7 " C a s i n g 10 - N o v 9 7 7 4 1 1 . 2 0 4 7 1 5 2 5 6 / 1 2 / 1 7 4 . 8 5 5 / 40 / 3 4 / 2 6 / 8 / 6 2 / 0 1 1 . 7 3 . 0 / 8 4 . 5 0 . 0 1 0 . 8 0 1 0 . 8 7 . 5 0 0 . 1 8 / 0 . 5 5 1 5 0 0 0 . 0 6 4 0 C e m e n t j o b / L a y d own HWDP 11 - N o v 9 7 7 4 1 1 . 2 0 4 7 1 5 2 5 6 / 1 2 / 1 7 4 . 8 5 5 / 4 0 / 3 4 / 2 6 / 8 / 6 2 / 0 1 1 . 7 3 . 0 / 8 4 . 5 0 . 0 1 0 . 8 0 1 0 . 8 7 . 5 0 0 . 1 8 / 0 . 5 5 1 5 0 0 0 . 0 6 4 0 Lay Down HWDP/Safety Stand Down 12 - N o v 9 7 7 4 1 1 . 2 5 4 7 1 1 2 6 8 / 1 2 / 1 5 6 . 4 4 8 / 37 / 3 1 / 2 4 / 1 0 / 8 2 / 0 1 1 . 7 3 . 0 / 8 4 . 5 0 . 0 1 1 . 0 0 1 1 . 2 7 .5 0 0 . 2 5 / 0 . 5 0 1 5 0 0 0 . 0 1 1 2 0 S a f e t y S t a n d D o w n 13 - N o v 9 7 7 4 1 1 . 2 5 4 7 1 1 2 6 9 / 1 2 / 1 5 6 . 5 4 8 / 37 / 3 1 / 2 4 / 1 0 / 8 2 / 0 1 1 . 7 3 . 0 / 8 4 . 5 0 . 0 1 0 . 0 0 1 0 . 8 7 .5 0 0 . 2 0 / 0 . 8 0 1 5 0 0 0 1 1 2 0 F i n i s h T e s t i n g B O P E 14 - N o v 9 7 7 4 1 1 . 2 5 4 8 1 1 2 7 1 0 / 1 3 / 1 8 6 . 6 48 / 3 8 / 3 1 / 2 4 / 1 0 / 9 2 / 0 1 1 . 7 3 . 0 / 8 4 . 5 0 . 0 1 0 . 0 0 1 0 . 3 7 . 5 0 0 . 2 0 / 0 . 8 0 1 5 0 0 0 1 0 8 0 T I H w / C l e a n O u t B H A 15 - N o v 9 7 7 4 1 1 . 2 0 4 7 1 2 2 4 1 0 / 1 3 / 1 7 6 . 5 48 / 3 6 / 3 1 / 2 4 / 1 0 / 9 2 / 0 1 4 . 2 3 . 0 / 8 2 . 0 0 . 0 1 0 . 0 0 1 0 . 7 7 . 5 0 0 . 2 0 / 0 . 8 0 1 5 0 0 0 1 1 2 0 T O H w / C l e a n O u t B H A Pa g e 1 o f 2 Da t e D e p t h W t V i s P V Y P G e l s H T H P R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R 6/ R 3 Ca k e S o l i d s Oi l / W a t e r Al k a PO M Ex c e s s Li m e El e c St a b Ca C l 2 W P S L G S / H G S A S G R e m a r k s ft - M D p p g s e c l b / 1 0 0 lb / 1 0 0 f t 2 m/ 3 0 m R h e o m e t e r 3 2 n d s % % m l p p b v o l t s p p b p p m p p b A S G 16 - N o v 9 9 3 8 7 . 6 5 6 2 1 5 1 2 6 / 7 / 1 3 5 . 2 2 8 / 2 0 / 1 6 / 1 1 / 8 / 6 0 / 2 3 . 4 8 9 . 6 / 1 0 . 4 0 . 1 0 4 .7 9 8 7 3 . 0 4 . 3 2 1 6 6 , 3 3 7 3 9 . 2 7 / - 1 3 . 2 9 2 . 1 7 6 D r illing 6.125" Lateral 17 - N o v 1 0 6 7 8 7 . 6 0 5 6 1 2 1 2 8 / 1 1 / 1 7 5 . 1 3 6 / 2 4 / 2 0 / 1 4 / 8 / 7 0 / 2 3 . 8 8 6 . 9 / 1 3 . 1 0 . 1 0 5 .8 3 1 7 2 0 . 0 3 . 1 6 1 4 1 , 1 3 4 5 3 . 4 1 / - 2 9 . 6 7 1 . 7 6 1 D r illing 6.125" Lateral 18 - N o v 1 1 6 5 9 7 . 6 5 5 2 1 0 8 6 / 9 / 1 3 5 . 3 2 8 / 1 8 / 1 3 / 9 / 6 / 5 0 / 2 3 . 3 8 7 . 5 / 1 2 . 5 0 . 1 0 5 .3 1 1 4 1 0 . 0 2 . 8 7 1 4 3 , 9 1 3 3 9 . 8 5 / - 1 5 . 0 7 2 . 1 1 1 D r illing 6.125" Lateral 19 - N o v 1 1 9 3 0 7 . 8 0 5 2 1 1 1 0 7 / 1 0 / 1 2 5 . 2 3 2 / 2 1 / 1 5 / 1 1 / 7 / 5 0 / 2 4 . 6 8 7 . 4 / 1 2 . 6 0 . 1 0 5 .8 3 1 2 0 9 . 0 6 . 2 6 1 4 0 , 7 6 4 5 3 . 7 4 / - 1 9 . 2 4 2 . 1 4 4 D r illing 6.125" Lateral 20 - N o v 1 2 3 4 9 7 . 8 5 5 3 1 1 1 0 7 / 9 / 1 2 5 . 1 3 2 / 2 1 / 1 5 / 1 0 / 7 / 5 0 / 2 4 . 4 8 7 . 4 / 1 2 . 6 0 . 1 0 7 .2 5 1 4 3 7 . 0 3 . 3 5 1 4 3 , 4 6 4 4 5 . 7 7 / - 9 . 6 2 2 . 3 6 1 D r illing 6.125" Lateral 21 - N o v 1 2 8 0 0 7 . 8 5 5 4 1 2 9 6 / 9 / 1 1 4 . 4 3 3 / 2 1 / 1 6 / 1 1 / 8 / 6 0 / 2 4 . 4 8 8 . 4 / 1 1 . 6 0 . 1 0 8 . 1 6 1 9 5 4 . 0 4 . 3 2 1 5 2 , 3 6 4 3 4 . 3 1 / 0 . 6 2 2 . 6 1 8 D r illing 6.125" Lateral 22 - N o v 1 3 7 5 8 8 . 0 0 6 1 1 5 1 1 6 / 9 / 14 4 . 2 4 6 / 2 1 / 1 9 / 1 4 / 6 / 5 0 / 2 5 . 4 91 . 5 / 8 . 5 0. 1 0 8 . 4 2 1 4 7 4 . 0 2 . 8 7 1 4 8 , 85 3 4 8 . 7 5 / 0 . 4 4 2 . 6 0 9 D r illing 6.125" Lateral 23 - N o v 1 4 3 5 8 8 . 0 5 6 0 1 9 1 1 6 / 1 4 / 2 0 4 . 0 4 9 / 3 0 / 2 2 1 5 / 6 / 5 0 / 2 5 . 8 9 1 . 5 / 8 . 5 0 . 1 0 7 .9 0 1 9 1 0 . 0 2 . 8 7 1 2 9 , 7 7 4 5 2 . 7 1 / 0 . 3 3 2 . 6 0 6 D r illing 6.125" Lateral 24 - N o v 1 4 4 6 4 8 . 0 5 6 1 1 5 1 0 6 / 1 4 / 2 3 4 . 1 4 0 / 2 5 / 1 9 / 1 4 / 6 / 4 0 / 2 6 . 0 9 3 . 1 / 6 . 9 0 . 1 0 7 . 1 2 1 4 6 5 . 0 3 . 3 5 1 3 0 , 9 7 1 5 4 . 3 9 / 0 . 5 3 2 . 6 1 0 D r illing 6.125" Lateral 25 - N o v 1 3 3 0 0 7 . 9 5 7 2 1 9 1 2 7 / 1 1 / 1 8 4 . 2 5 0 / 3 1 / 2 2 / 1 4 / 5 / 4 0 / 2 5 . 2 9 2 . 6 / 7 . 4 0 . 1 0 4 . 6 6 1 6 7 7 . 0 0 . 9 3 1 4 8 , 6 6 4 4 7 . 7 4 / 0 . 1 4 2 . 6 0 3 D r illing 6.125" Lateral 26 - N o v 1 3 3 0 0 1 0 . 0 0 9 0 2 4 1 3 1 2 / 2 0 2 5 4 . 8 61 / 3 7 / 2 6 / 1 7 / 7 / 6 0 / 2 1 2 . 4 8 8 . 5 / 1 1 . 5 0 . 1 0 6 . 8 6 15 1 6 . 0 3 . 3 5 1 5 2 , 8 2 0 5 1 . 0 0 / 1 0 0 . 8 3 3 . 4 8 1 L / D n B H A 27 - N o v 1 3 3 3 0 1 0 . 0 0 9 8 2 1 1 5 1 5 / 2 3 / 2 8 5 . 1 57 / 3 6 / 2 5 / 1 5 / 7 / 6 0 / 2 1 2 . 5 8 8 . 5 / 1 1 . 5 0 . 1 0 7 . 5 0 1 6 2 7 . 0 3 . 1 6 1 4 7 , 0 7 6 5 1 . 0 9 / 1 0 1 . 0 1 3 . 4 8 1 T I H w / B H A #10 28 - N o v 1 3 3 3 3 8 . 0 5 7 5 2 0 1 0 5 / 1 6 / 2 2 4 . 3 5 0 / 3 0 / 2 3 / 1 5 / 4 / 3 0 / 2 5 . 7 8 6 . 0 / 8 . 0 0 . 1 0 5 . 0 5 1 8 7 3 . 0 4 . 1 2 1 2 8 , 0 0 1 5 1 . 0 1 / 1 . 6 5 2 . 6 3 1 D r illing 6.125" Lateral 29 - N o v 1 3 4 8 0 7 . 8 5 6 6 1 6 1 1 5 / 1 2 / 2 0 4 . 0 4 3 / 2 7 / 1 9 / 1 2 / 4 / 3 0 / 2 4 . 5 8 7 . 3 / 8 . 0 . . 0 1 3 . 8 8 1 4 6 2 . 0 3 . 3 5 1 0 9 , 0 9 3 3 9 . 7 4 / 1 . 3 8 2 . 6 3 4 D r illing 6.125" Lateral 30 - N o v 1 4 4 5 8 7 . 9 0 6 3 1 6 1 1 5 / 1 5 / 2 1 3 . 5 4 3 / 2 7 / 1 9 / 1 3 / 5 / 4 0 / 2 4 . 9 8 7 . 4 / 7 . 5 0 . 0 1 2 . 7 2 1 4 6 5 . 0 3 . 3 5 1 1 5 , 5 2 6 4 3 . 5 3 / 1 . 1 4 2 . 6 2 6 D r illing 6.125" Lateral 1- D e c 1 5 7 1 6 8 . 0 0 7 0 2 0 1 1 7 / 1 7 / 2 3 2 . 8 5 1 / 31 / 2 4 / 1 6 / 6 / 5 0 / 2 5 . 5 8 6 . 2 / 8 . 0 0 . 0 1 5 . 1 8 1 4 1 4 . 0 3 . 3 5 1 2 1 , 1 9 3 5 0 . 1 4 / 0 . 0 8 2 . 6 0 2 B a c k r e a m i n g t o 7 " shoe 2- D e c 1 5 7 1 6 8 . 0 0 6 4 1 6 1 2 7 / 1 8 / 2 3 2 . 8 44 / 2 8 / 2 2 / 1 4 / 6 / 5 0 / 2 5 . 3 8 5 . 4 / 9 . 0 0 . 0 1 2 . 8 5 14 6 3 . 0 3 . 8 4 1 1 5 , 7 6 9 4 7 . 4 1 / 1 . 4 0 2 . 6 2 9 R I H t o T D 3- D e c 1 5 7 1 6 1 0 . 0 0 7 5 2 4 1 6 8 / 2 6 / 3 4 3 . 8 6 4 / 40 / 3 0 / 2 0 / 7 / 6 0 / 2 1 1 . 6 7 8 . 6 / 9 . 5 0 .0 1 2 . 5 9 1 4 5 5 . 0 2 . 8 7 1 1 1 , 5 6 9 3 1 . 0 4 / 1 1 9 . 9 7 3 . 7 2 8 P O O H w / 6 1 / 8 " BHA 4- D e c 1 5 7 1 6 1 0 . 0 0 9 0 2 4 1 3 8 / 2 7 / 3 0 3 . 2 61 / 3 7 / 2 9 / 1 9 / 7 / 6 0 / 2 1 1 . 7 8 9 . 2 / 1 0 . 8 0 . 0 1 4 . 2 7 1 5 1 1 . 0 2 . 8 7 1 1 1 , 5 6 9 3 2 . 9 5 / 1 1 8 . 3 5 3 . 7 0 4 R I H w i t h 4 1 /2" Liner 11 . 7 5 " C a s i n g @ 4 1 4 0 ' M D 9. 6 2 5 " C a s i n g @ 7 2 3 8 ' M D 7" C a s i n g @ 9 7 5 9 ' M D Ca s i n g R e c o r d 16 " C o n d u c t o r @ 1 5 8 ' M D Pa g e 2 o f 2 Marker MD INC AZ TVD TVDSS Top of Permafrost 862.0 10.33 106.96 854.03 797.83 Base of Permafrost 1697.0 19.73 55.29 1668.85 1612.65 Top Ugnu D 1761.0 21.44 52.65 1728.82 1672.62 Top West Sak 2565.0 34.57 40.98 2433.25 2377.05 Cretaceous Tuffs 3490.0 45.66 37.74 3129.25 3073.05 Hue 2 Shale 4084.0 53.09 39.43 3509.84 3453.64 11-3/4" SCP 4139.7 52.07 38.39 3543.58 3487.38 Brookian 2B 5379.0 49.73 38.01 4330.66 4274.46 Top Torok Sand 6610.0 50.97 38.54 5110.31 5054.11 Base Torok Sand 7040.0 51.17 38.13 5381.56 5325.36 9-5/8" ICP1 7238.0 51.00 37.03 5506.33 5450.13 Torok 1 Shale 7247.0 51.11 37.05 5511.99 5455.79 Top HRZ 7805.0 52.07 26.89 5865.32 5809.12 Base HRZ 8014.0 52.00 15.77 5993.91 5937.71 Kalubik Marker 8150.0 54.69 6.88 6074.95 6018.75 Top Kuparuk C 8263.0 56.20 0.30 6138.99 6082.79 Base Kuparuk (LCU)8332.0 57.85 356.57 6176.70 612.50 BCU 8742.0 75.87 351.68 6341.73 6285.53 Top Nuiqsut 9594.0 85.62 326.49 6418.07 6361.87 Top Nuiq::Nuiq_1 D1 9633.0 85.64 324.01 6421.05 6364.85 7" ICP2 9759.1 87.29 315.74 6429.77 6373.57 Invert #1 10220.2 90.00 314.56 6445.34 6389.14 Revert #1 11685.5 90.00 316.92 6406.39 6350.19 Unmapped Fault 11750.0 89.78 316.64 6406.60 6350.40 Kickoff from PB1 11930.0 91.64 315.62 6406.26 6350.06 Invert #2 12793.7 90.00 311.76 6417.78 6361.58 Kickoff from PB2 13160.0 92.77 310.86 6404.03 6347.83 Revert #2 13324.8 90.00 321.24 6400.36 6344.16 Fault ~9' DTNW 13470.0 87.44 320.5 6406.13 6349.93 TD 15716.0 89.87 316.89 6429.59 6373.39 ODSN-29 Interpolated Tops Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSN-29 ODSN-29 PN5 PB1 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-29 PN5 PB1 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-29 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Oooguruk Development Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: ft +E/-W +N/-S Position Uncertainty ft ft ftGround Level: ODSN-29 ft ft 0.00 0.00 6,031,108.44 469,923.95 13.50Wellhead Elevation:ft0.00 70° 29' 45.820 N 150° 14' 45.357 W Wellbore Declination (?) Field Strength (nT) Sample Date Dip Angle (?) ODSN-29 PN5 PB1 Model NameMagnetics IGRF2010 10/10/2012 20.57 80.97 57,668 Phase:Version: Audit Notes: Design ODSN-29 PN5 PB1 1.0 ACTUAL Vertical Section: Depth From (TVD) (ft) +N/-S (ft) Direction (bearing) +E/-W (ft) Tie On Depth:42.70 350.270.000.0042.70 From (ft) Survey Program DescriptionTool NameSurvey (Wellbore) To (ft) Date 12/14/2012 Survey Start Date SRG-SS Surface readout gyro single shot100.00 729.00 ODSN-29 GYRO (ODSN-29 PN5 PB1)11/07/2012 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag775.48 4,139.70 ODSN-29 MWD (ODSN-29 PN5 PB1)11/08/2012 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag4,139.70 7,238.00 ODSN-29 MWD (ODSN-29 PN5 PB1)11/08/2012 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag7,238.00 9,759.10 ODSN-29 MWD (ODSN-29 PN5 PB1)11/08/2012 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag9,759.10 12,367.53 ODSN-29 MWD (ODSN-29 PN5 PB1)11/08/2012 MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 42.70 0.00 0.00 42.70 0.00 0.00-13.50 6,031,108.44 469,923.95 0.00 0.00 UNDEFINED 100.00 0.12 142.74 100.00 -0.05 0.0443.80 6,031,108.39 469,923.99 0.21 -0.05 SRG-SS (1) 172.00 0.15 342.94 172.00 -0.02 0.05115.80 6,031,108.42 469,924.00 0.37 -0.03 SRG-SS (1) 261.00 1.50 148.91 260.99 -0.90 0.62204.79 6,031,107.53 469,924.57 1.85 -1.00 SRG-SS (1) 354.00 4.95 146.57 353.83 -5.30 3.46297.63 6,031,103.13 469,927.39 3.71 -5.80 SRG-SS (1) 448.00 9.11 143.99 447.10 -14.70 10.07390.90 6,031,093.70 469,933.96 4.44 -16.20 SRG-SS (1) 541.00 11.62 142.76 538.58 -28.12 20.07482.38 6,031,080.24 469,943.91 2.71 -31.11 SRG-SS (1) 636.00 10.55 138.46 631.81 -42.25 31.63575.61 6,031,066.07 469,955.41 1.42 -46.98 SRG-SS (1) 729.00 10.64 121.05 723.24 -53.05 44.63667.04 6,031,055.22 469,968.36 3.43 -59.83 SRG-SS (1) 775.48 10.70 114.93 768.92 -57.08 52.22712.72 6,031,051.15 469,975.94 2.44 -65.09 MWD+IFR2+MS+sag (2) 12/14/2012 12:52:27PM COMPASS 2003.16 Build 42 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSN-29 ODSN-29 PN5 PB1 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-29 PN5 PB1 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-29 True MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 871.35 10.29 106.10 863.19 -63.21 68.52806.99 6,031,044.96 469,992.21 1.73 -73.88 MWD+IFR2+MS+sag (2) 967.21 8.57 109.64 957.76 -67.98 83.48901.56 6,031,040.13 470,007.14 1.89 -81.11 MWD+IFR2+MS+sag (2) 1,057.98 8.88 89.26 1,047.50 -70.17 96.85991.30 6,031,037.89 470,020.51 3.40 -85.53 MWD+IFR2+MS+sag (2) 1,156.87 8.63 82.17 1,145.24 -69.06 111.841,089.04 6,031,038.94 470,035.50 1.12 -86.96 MWD+IFR2+MS+sag (2) 1,252.66 9.64 75.68 1,239.81 -66.09 126.731,183.61 6,031,041.84 470,050.40 1.50 -86.56 MWD+IFR2+MS+sag (2) 1,344.56 11.97 66.08 1,330.09 -60.33 142.901,273.89 6,031,047.54 470,066.59 3.20 -83.61 MWD+IFR2+MS+sag (2) 1,443.83 14.03 61.93 1,426.81 -50.49 162.931,370.61 6,031,057.30 470,086.66 2.28 -77.30 MWD+IFR2+MS+sag (2) 1,538.72 16.10 60.74 1,518.43 -38.64 184.561,462.23 6,031,069.05 470,108.33 2.21 -69.28 MWD+IFR2+MS+sag (2) 1,630.58 18.58 58.48 1,606.11 -24.76 208.151,549.91 6,031,082.84 470,131.98 2.80 -59.59 MWD+IFR2+MS+sag (2) 1,726.05 20.24 53.90 1,696.16 -7.08 234.461,639.96 6,031,100.41 470,158.36 2.36 -46.60 MWD+IFR2+MS+sag (2) 1,823.57 23.59 50.42 1,786.62 15.30 263.141,730.42 6,031,122.67 470,187.13 3.68 -29.39 MWD+IFR2+MS+sag (2) 1,919.50 24.52 50.45 1,874.22 40.20 293.291,818.02 6,031,147.45 470,217.37 0.97 -9.94 MWD+IFR2+MS+sag (2) 2,012.11 26.18 49.20 1,957.91 65.79 323.571,901.71 6,031,172.92 470,247.75 1.88 10.16 MWD+IFR2+MS+sag (2) 2,108.98 29.74 46.35 2,043.46 96.35 357.141,987.26 6,031,203.34 470,281.45 3.92 34.61 MWD+IFR2+MS+sag (2) 2,203.85 30.55 43.54 2,125.51 130.07 390.782,069.31 6,031,236.92 470,315.22 1.71 62.16 MWD+IFR2+MS+sag (2) 2,300.31 30.90 43.41 2,208.43 165.84 424.692,152.23 6,031,272.54 470,349.27 0.37 91.68 MWD+IFR2+MS+sag (2) 2,394.61 30.17 41.08 2,289.65 201.29 456.902,233.45 6,031,307.86 470,381.62 1.47 121.18 MWD+IFR2+MS+sag (2) 2,485.66 32.87 41.15 2,367.26 237.15 488.202,311.06 6,031,343.59 470,413.06 2.97 151.23 MWD+IFR2+MS+sag (2) 2,582.97 34.96 40.94 2,448.01 278.10 523.852,391.81 6,031,384.39 470,448.87 2.15 185.56 MWD+IFR2+MS+sag (2) 2,676.49 35.93 37.95 2,524.20 319.98 558.292,468.00 6,031,426.12 470,483.47 2.12 221.02 MWD+IFR2+MS+sag (2) 2,772.74 37.48 37.32 2,601.37 365.54 593.412,545.17 6,031,471.54 470,518.77 1.66 259.99 MWD+IFR2+MS+sag (2) 2,866.80 38.36 38.20 2,675.57 411.23 628.812,619.37 6,031,517.08 470,554.35 1.10 299.05 MWD+IFR2+MS+sag (2) 2,962.28 39.48 38.14 2,749.85 458.39 665.882,693.65 6,031,564.09 470,591.61 1.17 339.26 MWD+IFR2+MS+sag (2) 3,056.78 42.54 37.76 2,821.15 507.29 704.002,764.95 6,031,612.82 470,629.93 3.25 381.01 MWD+IFR2+MS+sag (2) 3,152.51 44.40 38.36 2,890.62 559.14 744.612,834.42 6,031,664.50 470,670.74 1.99 425.25 MWD+IFR2+MS+sag (2) 3,244.56 45.78 38.50 2,955.61 610.20 785.132,899.41 6,031,715.40 470,711.46 1.50 468.73 MWD+IFR2+MS+sag (2) 3,339.91 44.52 38.40 3,022.85 663.14 827.162,966.65 6,031,768.16 470,753.70 1.32 513.81 MWD+IFR2+MS+sag (2) 3,437.78 44.79 38.83 3,092.47 716.89 870.093,036.27 6,031,821.73 470,796.84 0.41 559.52 MWD+IFR2+MS+sag (2) 3,531.82 46.35 36.87 3,158.31 769.92 911.283,102.11 6,031,874.59 470,838.24 2.23 604.83 MWD+IFR2+MS+sag (2) 3,628.46 46.31 36.78 3,225.04 825.87 953.183,168.84 6,031,930.36 470,880.36 0.08 652.90 MWD+IFR2+MS+sag (2) 3,721.08 49.15 38.54 3,287.33 880.10 995.063,231.13 6,031,984.42 470,922.46 3.37 699.27 MWD+IFR2+MS+sag (2) 3,815.98 52.06 38.95 3,347.55 937.29 1,040.963,291.35 6,032,041.42 470,968.59 3.08 747.88 MWD+IFR2+MS+sag (2) 3,913.69 53.35 38.96 3,406.76 997.74 1,089.833,350.56 6,032,101.66 471,017.70 1.32 799.20 MWD+IFR2+MS+sag (2) 4,007.06 52.27 39.23 3,463.20 1,055.47 1,136.733,407.00 6,032,159.19 471,064.83 1.18 848.17 MWD+IFR2+MS+sag (2) 4,093.51 53.19 39.45 3,515.55 1,108.67 1,180.343,459.35 6,032,212.22 471,108.65 1.08 893.24 MWD+IFR2+MS+sag (2) 4,193.35 50.77 38.33 3,577.04 1,169.88 1,229.733,520.84 6,032,273.22 471,158.28 2.58 945.22 MWD+IFR2+MS+sag (3) 4,235.17 50.22 38.20 3,603.64 1,195.21 1,249.713,547.44 6,032,298.47 471,178.36 1.34 966.81 MWD+IFR2+MS+sag (3) 4,329.62 50.67 36.91 3,663.79 1,252.94 1,294.103,607.59 6,032,356.01 471,222.97 1.16 1,016.21 MWD+IFR2+MS+sag (3) 4,424.83 50.66 37.77 3,724.14 1,311.49 1,338.763,667.94 6,032,414.37 471,267.87 0.70 1,066.37 MWD+IFR2+MS+sag (3) 4,520.03 51.23 38.51 3,784.12 1,369.63 1,384.423,727.92 6,032,472.32 471,313.76 0.85 1,115.96 MWD+IFR2+MS+sag (3) 12/14/2012 12:52:27PM COMPASS 2003.16 Build 42 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSN-29 ODSN-29 PN5 PB1 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-29 PN5 PB1 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-29 True MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 4,614.29 51.72 40.80 3,842.84 1,426.40 1,431.483,786.64 6,032,528.89 471,361.04 1.97 1,163.95 MWD+IFR2+MS+sag (3) 4,710.58 51.23 38.43 3,902.82 1,484.42 1,479.513,846.62 6,032,586.71 471,409.30 1.99 1,213.02 MWD+IFR2+MS+sag (3) 4,805.30 49.64 37.91 3,963.15 1,541.82 1,524.633,906.95 6,032,643.92 471,454.66 1.73 1,261.97 MWD+IFR2+MS+sag (3) 4,899.73 49.48 38.02 4,024.40 1,598.48 1,568.853,968.20 6,032,700.40 471,499.09 0.19 1,310.34 MWD+IFR2+MS+sag (3) 4,992.80 50.29 38.34 4,084.37 1,654.43 1,612.844,028.17 6,032,756.16 471,543.31 0.91 1,358.05 MWD+IFR2+MS+sag (3) 5,090.15 50.44 39.45 4,146.47 1,712.78 1,659.924,090.27 6,032,814.31 471,590.61 0.89 1,407.60 MWD+IFR2+MS+sag (3) 5,185.51 51.01 37.43 4,206.84 1,770.59 1,705.804,150.64 6,032,871.94 471,636.73 1.75 1,456.83 MWD+IFR2+MS+sag (3) 5,280.47 50.10 37.49 4,267.17 1,828.80 1,750.404,210.97 6,032,929.96 471,681.56 0.96 1,506.67 MWD+IFR2+MS+sag (3) 5,375.64 49.67 38.02 4,328.49 1,886.35 1,794.964,272.29 6,032,987.32 471,726.35 0.62 1,555.85 MWD+IFR2+MS+sag (3) 5,471.03 51.32 37.62 4,389.17 1,944.48 1,840.094,332.97 6,033,045.27 471,771.70 1.76 1,605.53 MWD+IFR2+MS+sag (3) 5,565.75 51.40 38.05 4,448.32 2,002.92 1,885.474,392.12 6,033,103.51 471,817.32 0.36 1,655.45 MWD+IFR2+MS+sag (3) 5,661.24 51.07 37.96 4,508.10 2,061.58 1,931.314,451.90 6,033,161.98 471,863.39 0.35 1,705.52 MWD+IFR2+MS+sag (3) 5,755.74 50.60 37.62 4,567.79 2,119.48 1,976.214,511.59 6,033,219.70 471,908.52 0.57 1,755.00 MWD+IFR2+MS+sag (3) 5,852.58 50.84 37.86 4,629.10 2,178.76 2,022.094,572.90 6,033,278.78 471,954.64 0.31 1,805.68 MWD+IFR2+MS+sag (3) 5,948.17 51.25 37.06 4,689.20 2,237.77 2,067.304,633.00 6,033,337.60 472,000.08 0.78 1,856.19 MWD+IFR2+MS+sag (3) 6,041.98 50.15 37.38 4,748.61 2,295.57 2,111.214,692.41 6,033,395.22 472,044.22 1.20 1,905.75 MWD+IFR2+MS+sag (3) 6,136.90 49.57 37.71 4,809.80 2,353.11 2,155.434,753.60 6,033,452.57 472,088.66 0.67 1,954.98 MWD+IFR2+MS+sag (3) 6,233.24 49.87 39.47 4,872.09 2,410.55 2,201.274,815.89 6,033,509.82 472,134.73 1.43 2,003.85 MWD+IFR2+MS+sag (3) 6,327.80 50.83 38.16 4,932.43 2,467.28 2,246.904,876.23 6,033,566.36 472,180.59 1.47 2,052.05 MWD+IFR2+MS+sag (3) 6,422.21 50.76 37.12 4,992.11 2,525.21 2,291.584,935.91 6,033,624.10 472,225.49 0.86 2,101.60 MWD+IFR2+MS+sag (3) 6,517.54 51.12 37.06 5,052.18 2,584.26 2,336.224,995.98 6,033,682.96 472,270.37 0.38 2,152.25 MWD+IFR2+MS+sag (3) 6,612.58 50.97 38.58 5,111.93 2,642.64 2,381.535,055.73 6,033,741.15 472,315.91 1.25 2,202.13 MWD+IFR2+MS+sag (3) 6,708.03 50.51 38.55 5,172.34 2,700.42 2,427.605,116.14 6,033,798.75 472,362.21 0.48 2,251.30 MWD+IFR2+MS+sag (3) 6,803.17 50.84 38.39 5,232.63 2,758.04 2,473.395,176.43 6,033,856.18 472,408.23 0.37 2,300.35 MWD+IFR2+MS+sag (3) 6,898.93 51.00 39.16 5,293.00 2,816.00 2,519.945,236.80 6,033,913.93 472,455.01 0.65 2,349.60 MWD+IFR2+MS+sag (3) 6,994.31 51.17 38.97 5,352.91 2,873.62 2,566.715,296.71 6,033,971.36 472,502.01 0.24 2,398.49 MWD+IFR2+MS+sag (3) 7,089.04 51.17 37.23 5,412.31 2,931.69 2,612.245,356.11 6,034,029.24 472,547.77 1.43 2,448.03 MWD+IFR2+MS+sag (3) 7,186.05 50.62 36.84 5,473.50 2,991.78 2,657.585,417.30 6,034,089.14 472,593.35 0.65 2,499.59 MWD+IFR2+MS+sag (3) 7,239.97 51.01 37.04 5,507.57 3,025.18 2,682.705,451.37 6,034,122.44 472,618.60 0.78 2,528.27 MWD+IFR2+MS+sag (4) 7,253.31 51.20 37.06 5,515.94 3,033.47 2,688.965,459.74 6,034,130.70 472,624.89 1.43 2,535.38 MWD+IFR2+MS+sag (4) 7,347.99 51.20 38.68 5,575.27 3,091.71 2,734.255,519.07 6,034,188.75 472,670.41 1.33 2,585.14 MWD+IFR2+MS+sag (4) 7,443.25 50.19 38.10 5,635.62 3,149.48 2,780.035,579.42 6,034,246.33 472,716.42 1.16 2,634.34 MWD+IFR2+MS+sag (4) 7,538.01 49.51 37.02 5,696.72 3,206.90 2,824.185,640.52 6,034,303.56 472,760.80 1.13 2,683.46 MWD+IFR2+MS+sag (4) 7,633.13 50.49 34.29 5,757.86 3,266.10 2,866.645,701.66 6,034,362.59 472,803.49 2.43 2,734.64 MWD+IFR2+MS+sag (4) 7,728.76 51.43 30.23 5,818.11 3,328.90 2,906.255,761.91 6,034,425.22 472,843.35 3.44 2,789.84 MWD+IFR2+MS+sag (4) 7,822.71 52.22 26.12 5,876.20 3,393.98 2,941.105,820.00 6,034,490.15 472,878.46 3.54 2,848.10 MWD+IFR2+MS+sag (4) 7,919.13 51.97 19.97 5,935.47 3,463.93 2,970.865,879.27 6,034,559.97 472,908.50 5.04 2,912.01 MWD+IFR2+MS+sag (4) 8,014.10 52.00 15.77 5,993.97 3,535.11 2,993.815,937.77 6,034,631.06 472,931.74 3.48 2,978.29 MWD+IFR2+MS+sag (4) 8,109.08 54.08 9.02 6,051.12 3,609.17 3,010.035,994.92 6,034,705.04 472,948.25 6.08 3,048.54 MWD+IFR2+MS+sag (4) 8,204.65 55.50 4.49 6,106.24 3,686.68 3,019.186,050.04 6,034,782.51 472,957.72 4.15 3,123.39 MWD+IFR2+MS+sag (4) 12/14/2012 12:52:27PM COMPASS 2003.16 Build 42 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSN-29 ODSN-29 PN5 PB1 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-29 PN5 PB1 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-29 True MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 8,299.52 56.76 357.64 6,159.15 3,765.36 3,020.616,102.95 6,034,861.17 472,959.46 6.14 3,200.70 MWD+IFR2+MS+sag (4) 8,395.04 59.96 354.49 6,209.26 3,846.47 3,014.996,153.06 6,034,942.29 472,954.17 4.37 3,281.58 MWD+IFR2+MS+sag (4) 8,490.01 63.54 352.73 6,254.21 3,929.58 3,005.666,198.01 6,035,025.43 472,945.18 4.11 3,365.08 MWD+IFR2+MS+sag (4) 8,585.18 68.13 351.60 6,293.16 4,015.58 2,993.816,236.96 6,035,111.47 472,933.68 4.94 3,451.84 MWD+IFR2+MS+sag (4) 8,680.70 72.73 351.59 6,325.15 4,104.59 2,980.666,268.95 6,035,200.52 472,920.89 4.82 3,541.80 MWD+IFR2+MS+sag (4) 8,775.68 77.59 351.73 6,349.47 4,195.40 2,967.356,293.27 6,035,291.38 472,907.95 5.12 3,633.55 MWD+IFR2+MS+sag (4) 8,871.40 81.78 350.38 6,366.60 4,288.40 2,952.706,310.40 6,035,384.43 472,893.68 4.59 3,727.69 MWD+IFR2+MS+sag (4) 8,966.20 85.58 350.25 6,377.04 4,381.27 2,936.856,320.84 6,035,477.35 472,878.21 4.01 3,821.90 MWD+IFR2+MS+sag (4) 9,017.12 87.31 349.59 6,380.19 4,431.30 2,927.966,323.99 6,035,527.41 472,869.52 3.64 3,872.72 MWD+IFR2+MS+sag (4) 9,060.56 87.43 349.78 6,382.19 4,474.00 2,920.196,325.99 6,035,570.13 472,861.92 0.52 3,916.11 MWD+IFR2+MS+sag (4) 9,112.53 87.43 349.67 6,384.52 4,525.08 2,910.936,328.32 6,035,621.25 472,852.87 0.21 3,968.03 MWD+IFR2+MS+sag (4) 9,156.56 87.01 349.26 6,386.65 4,568.32 2,902.896,330.45 6,035,664.52 472,845.00 1.33 4,012.00 MWD+IFR2+MS+sag (4) 9,252.44 87.06 344.00 6,391.62 4,661.44 2,880.756,335.42 6,035,757.72 472,823.25 5.48 4,107.53 MWD+IFR2+MS+sag (4) 9,346.04 85.39 339.79 6,397.78 4,750.19 2,851.746,341.58 6,035,846.58 472,794.60 4.83 4,199.90 MWD+IFR2+MS+sag (4) 9,442.51 84.96 334.69 6,405.90 4,838.81 2,814.566,349.70 6,035,935.33 472,757.78 5.29 4,293.52 MWD+IFR2+MS+sag (4) 9,537.10 85.58 330.13 6,413.70 4,922.33 2,770.916,357.50 6,036,019.02 472,714.48 4.85 4,383.22 MWD+IFR2+MS+sag (4) 9,632.57 85.64 324.03 6,421.02 5,002.20 2,719.216,364.82 6,036,099.09 472,663.10 6.37 4,470.68 MWD+IFR2+MS+sag (4) 9,663.68 85.70 322.57 6,423.37 5,027.07 2,700.676,367.17 6,036,124.03 472,644.66 4.68 4,498.33 MWD+IFR2+MS+sag (4) 9,697.60 85.58 320.58 6,425.95 5,053.56 2,679.656,369.75 6,036,150.61 472,623.75 5.86 4,527.99 MWD+IFR2+MS+sag (4) 9,776.75 87.78 318.00 6,430.53 5,113.45 2,628.126,374.33 6,036,210.70 472,572.47 4.28 4,595.73 MWD+IFR2+MS+sag (5) 9,862.68 88.58 317.11 6,433.26 5,176.83 2,570.166,377.06 6,036,274.30 472,514.77 1.39 4,667.99 MWD+IFR2+MS+sag (5) 9,959.37 88.46 317.67 6,435.76 5,247.97 2,504.726,379.56 6,036,345.70 472,449.63 0.59 4,749.16 MWD+IFR2+MS+sag (5) 10,055.30 86.60 317.60 6,439.89 5,318.78 2,440.146,383.69 6,036,416.76 472,385.34 1.94 4,829.87 MWD+IFR2+MS+sag (5) 10,152.06 88.21 316.05 6,444.27 5,389.26 2,374.006,388.07 6,036,487.51 472,319.50 2.31 4,910.52 MWD+IFR2+MS+sag (5) 10,248.25 90.74 313.95 6,445.15 5,457.27 2,306.006,388.95 6,036,555.78 472,251.78 3.42 4,989.04 MWD+IFR2+MS+sag (5) 10,344.58 90.99 313.70 6,443.70 5,523.96 2,236.516,387.50 6,036,622.75 472,182.56 0.37 5,066.52 MWD+IFR2+MS+sag (5) 10,441.15 91.67 313.39 6,441.46 5,590.47 2,166.536,385.26 6,036,689.54 472,112.86 0.77 5,143.90 MWD+IFR2+MS+sag (5) 10,536.95 92.22 312.87 6,438.21 5,655.93 2,096.666,382.01 6,036,755.27 472,043.26 0.79 5,220.22 MWD+IFR2+MS+sag (5) 10,633.35 91.85 314.43 6,434.78 5,722.43 2,026.956,378.58 6,036,822.04 471,973.83 1.66 5,297.54 MWD+IFR2+MS+sag (5) 10,729.68 90.56 314.67 6,432.76 5,789.99 1,958.326,376.56 6,036,889.87 471,905.48 1.36 5,375.73 MWD+IFR2+MS+sag (5) 10,825.68 91.30 314.76 6,431.20 5,857.52 1,890.116,375.00 6,036,957.68 471,837.55 0.78 5,453.82 MWD+IFR2+MS+sag (5) 10,922.06 90.37 313.66 6,429.80 5,924.72 1,821.036,373.60 6,037,025.15 471,768.76 1.49 5,531.73 MWD+IFR2+MS+sag (5) 11,018.42 91.17 310.85 6,428.50 5,989.50 1,749.736,372.30 6,037,090.21 471,697.72 3.03 5,607.63 MWD+IFR2+MS+sag (5) 11,115.04 92.47 310.17 6,425.43 6,052.23 1,676.316,369.23 6,037,153.23 471,624.56 1.52 5,681.87 MWD+IFR2+MS+sag (5) 11,210.97 92.59 309.82 6,421.20 6,113.83 1,602.896,365.00 6,037,215.12 471,551.40 0.39 5,754.98 MWD+IFR2+MS+sag (5) 11,307.49 92.29 311.57 6,417.09 6,176.70 1,529.786,360.89 6,037,278.28 471,478.55 1.84 5,829.31 MWD+IFR2+MS+sag (5) 11,403.74 91.54 313.13 6,413.87 6,241.50 1,458.696,357.67 6,037,343.36 471,407.73 1.80 5,905.19 MWD+IFR2+MS+sag (5) 11,500.65 91.61 314.11 6,411.21 6,308.33 1,388.566,355.01 6,037,410.47 471,337.88 1.01 5,982.91 MWD+IFR2+MS+sag (5) 11,595.80 92.16 315.42 6,408.08 6,375.30 1,321.046,351.88 6,037,477.70 471,270.64 1.49 6,060.33 MWD+IFR2+MS+sag (5) 11,692.96 89.82 317.05 6,406.40 6,445.45 1,253.856,350.20 6,037,548.11 471,203.74 2.93 6,140.82 MWD+IFR2+MS+sag (5) 12/14/2012 12:52:27PM COMPASS 2003.16 Build 42 Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSN-29 ODSN-29 PN5 PB1 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-29 PN5 PB1 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-29 True MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 11,787.10 89.75 316.37 6,406.75 6,513.97 1,189.306,350.55 6,037,616.89 471,139.47 0.73 6,219.27 MWD+IFR2+MS+sag (5) 11,885.85 90.06 316.41 6,406.92 6,585.47 1,121.196,350.72 6,037,688.66 471,071.66 0.32 6,301.25 MWD+IFR2+MS+sag (5) 11,982.48 93.52 314.68 6,403.90 6,654.40 1,053.566,347.70 6,037,757.85 471,004.32 4.00 6,380.62 MWD+IFR2+MS+sag (5) 12,078.69 93.09 316.94 6,398.35 6,723.27 986.616,342.15 6,037,826.98 470,937.66 2.39 6,459.81 MWD+IFR2+MS+sag (5) 12,175.48 92.28 316.73 6,393.82 6,793.79 920.476,337.62 6,037,897.76 470,871.81 0.86 6,540.49 MWD+IFR2+MS+sag (5) 12,270.85 92.59 315.57 6,389.76 6,862.50 854.466,333.56 6,037,966.73 470,806.08 1.26 6,619.37 MWD+IFR2+MS+sag (5) 12,367.53 92.59 314.85 6,385.40 6,931.04 786.426,329.20 6,038,035.54 470,738.33 0.74 6,698.43 MWD+IFR2+MS+sag (5) 12,464.00 92.59 314.85 6,381.04 6,999.01 718.106,324.84 6,038,103.78 470,670.29 0.00 6,776.97 PROJECTED to TD 12/14/2012 12:52:27PM COMPASS 2003.16 Build 42 Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSN-29 ODSN-29 PN5 PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-29 PN5 PB2 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-29 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Oooguruk Development Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: ft +E/-W +N/-S Position Uncertainty ft ft ftGround Level: ODSN-29 ft ft 0.00 0.00 6,031,108.44 469,923.95 13.50Wellhead Elevation:ft0.00 70° 29' 45.820 N 150° 14' 45.357 W Wellbore Declination (?) Field Strength (nT) Sample Date Dip Angle (?) ODSN-29 PN5 PB2 Model NameMagnetics IGRF2010 10/10/2012 20.57 80.97 57,668 Phase:Version: Audit Notes: Design ODSN-29 PN5 PB2 1.0 ACTUAL Vertical Section: Depth From (TVD) (ft) +N/-S (ft) Direction (bearing) +E/-W (ft) Tie On Depth:11,885.85 350.270.000.0042.70 From (ft) Survey Program DescriptionTool NameSurvey (Wellbore) To (ft) Date 12/14/2012 Survey Start Date SRG-SS Surface readout gyro single shot100.00 729.00 ODSN-29 GYRO (ODSN-29 PN5 PB1)11/07/2012 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag775.48 4,138.70 ODSN-29 MWD (ODSN-29 PN5 PB1)11/08/2012 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag4,139.70 7,238.00 ODSN-29 MWD (ODSN-29 PN5 PB1)11/08/2012 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag7,238.00 9,759.10 ODSN-29 MWD (ODSN-29 PN5 PB1)11/08/2012 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag9,759.10 11,885.85 ODSN-29 MWD (ODSN-29 PN5 PB1)11/08/2012 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag11,930.00 14,292.19 ODSN-29 PN5 MWD (ODSN-29 PN5 PB 11/20/2012 MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 42.70 0.00 0.00 42.70 0.00 0.00-13.50 6,031,108.44 469,923.95 0.00 0.00 UNDEFINED 100.00 0.12 142.74 100.00 -0.05 0.0443.80 6,031,108.39 469,923.99 0.21 -0.05 SRG-SS (1) 172.00 0.15 342.94 172.00 -0.02 0.05115.80 6,031,108.42 469,924.00 0.37 -0.03 SRG-SS (1) 261.00 1.50 148.91 260.99 -0.90 0.62204.79 6,031,107.53 469,924.57 1.85 -1.00 SRG-SS (1) 354.00 4.95 146.57 353.83 -5.30 3.46297.63 6,031,103.13 469,927.39 3.71 -5.80 SRG-SS (1) 448.00 9.11 143.99 447.10 -14.70 10.07390.90 6,031,093.70 469,933.96 4.44 -16.20 SRG-SS (1) 541.00 11.62 142.76 538.58 -28.12 20.07482.38 6,031,080.24 469,943.91 2.71 -31.11 SRG-SS (1) 636.00 10.55 138.46 631.81 -42.25 31.63575.61 6,031,066.07 469,955.41 1.42 -46.98 SRG-SS (1) 729.00 10.64 121.05 723.24 -53.05 44.63667.04 6,031,055.22 469,968.36 3.43 -59.83 SRG-SS (1) 775.48 10.70 114.93 768.92 -57.08 52.22712.72 6,031,051.15 469,975.94 2.44 -65.09 MWD+IFR2+MS+sag (2) 12/14/2012 1:08:21PM COMPASS 2003.16 Build 42 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSN-29 ODSN-29 PN5 PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-29 PN5 PB2 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-29 True MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 871.35 10.29 106.10 863.19 -63.21 68.52806.99 6,031,044.96 469,992.21 1.73 -73.88 MWD+IFR2+MS+sag (2) 967.21 8.57 109.64 957.76 -67.98 83.48901.56 6,031,040.13 470,007.14 1.89 -81.11 MWD+IFR2+MS+sag (2) 1,057.98 8.88 89.26 1,047.50 -70.17 96.85991.30 6,031,037.89 470,020.51 3.40 -85.53 MWD+IFR2+MS+sag (2) 1,156.87 8.63 82.17 1,145.24 -69.06 111.841,089.04 6,031,038.94 470,035.50 1.12 -86.96 MWD+IFR2+MS+sag (2) 1,252.66 9.64 75.68 1,239.81 -66.09 126.731,183.61 6,031,041.84 470,050.40 1.50 -86.56 MWD+IFR2+MS+sag (2) 1,344.56 11.97 66.08 1,330.09 -60.33 142.901,273.89 6,031,047.54 470,066.59 3.20 -83.61 MWD+IFR2+MS+sag (2) 1,443.83 14.03 61.93 1,426.81 -50.49 162.931,370.61 6,031,057.30 470,086.66 2.28 -77.30 MWD+IFR2+MS+sag (2) 1,538.72 16.10 60.74 1,518.43 -38.64 184.561,462.23 6,031,069.05 470,108.33 2.21 -69.28 MWD+IFR2+MS+sag (2) 1,630.58 18.58 58.48 1,606.11 -24.76 208.151,549.91 6,031,082.84 470,131.98 2.80 -59.59 MWD+IFR2+MS+sag (2) 1,726.05 20.24 53.90 1,696.16 -7.08 234.461,639.96 6,031,100.41 470,158.36 2.36 -46.60 MWD+IFR2+MS+sag (2) 1,823.57 23.59 50.42 1,786.62 15.30 263.141,730.42 6,031,122.67 470,187.13 3.68 -29.39 MWD+IFR2+MS+sag (2) 1,919.50 24.52 50.45 1,874.22 40.20 293.291,818.02 6,031,147.45 470,217.37 0.97 -9.94 MWD+IFR2+MS+sag (2) 2,012.11 26.18 49.20 1,957.91 65.79 323.571,901.71 6,031,172.92 470,247.75 1.88 10.16 MWD+IFR2+MS+sag (2) 2,108.98 29.74 46.35 2,043.46 96.35 357.141,987.26 6,031,203.34 470,281.45 3.92 34.61 MWD+IFR2+MS+sag (2) 2,203.85 30.55 43.54 2,125.51 130.07 390.782,069.31 6,031,236.92 470,315.22 1.71 62.16 MWD+IFR2+MS+sag (2) 2,300.31 30.90 43.41 2,208.43 165.84 424.692,152.23 6,031,272.54 470,349.27 0.37 91.68 MWD+IFR2+MS+sag (2) 2,394.61 30.17 41.08 2,289.65 201.29 456.902,233.45 6,031,307.86 470,381.62 1.47 121.18 MWD+IFR2+MS+sag (2) 2,485.66 32.87 41.15 2,367.26 237.15 488.202,311.06 6,031,343.59 470,413.06 2.97 151.23 MWD+IFR2+MS+sag (2) 2,582.97 34.96 40.94 2,448.01 278.10 523.852,391.81 6,031,384.39 470,448.87 2.15 185.56 MWD+IFR2+MS+sag (2) 2,676.49 35.93 37.95 2,524.20 319.98 558.292,468.00 6,031,426.12 470,483.47 2.12 221.02 MWD+IFR2+MS+sag (2) 2,772.74 37.48 37.32 2,601.37 365.54 593.412,545.17 6,031,471.54 470,518.77 1.66 259.99 MWD+IFR2+MS+sag (2) 2,866.80 38.36 38.20 2,675.57 411.23 628.812,619.37 6,031,517.08 470,554.35 1.10 299.05 MWD+IFR2+MS+sag (2) 2,962.28 39.48 38.14 2,749.85 458.39 665.882,693.65 6,031,564.09 470,591.61 1.17 339.26 MWD+IFR2+MS+sag (2) 3,056.78 42.54 37.76 2,821.15 507.29 704.002,764.95 6,031,612.82 470,629.93 3.25 381.01 MWD+IFR2+MS+sag (2) 3,152.51 44.40 38.36 2,890.62 559.14 744.612,834.42 6,031,664.50 470,670.74 1.99 425.25 MWD+IFR2+MS+sag (2) 3,244.56 45.78 38.50 2,955.61 610.20 785.132,899.41 6,031,715.40 470,711.46 1.50 468.73 MWD+IFR2+MS+sag (2) 3,339.91 44.52 38.40 3,022.85 663.14 827.162,966.65 6,031,768.16 470,753.70 1.32 513.81 MWD+IFR2+MS+sag (2) 3,437.78 44.79 38.83 3,092.47 716.89 870.093,036.27 6,031,821.73 470,796.84 0.41 559.52 MWD+IFR2+MS+sag (2) 3,531.82 46.35 36.87 3,158.31 769.92 911.283,102.11 6,031,874.59 470,838.24 2.23 604.83 MWD+IFR2+MS+sag (2) 3,628.46 46.31 36.78 3,225.04 825.87 953.183,168.84 6,031,930.36 470,880.36 0.08 652.90 MWD+IFR2+MS+sag (2) 3,721.08 49.15 38.54 3,287.33 880.10 995.063,231.13 6,031,984.42 470,922.46 3.37 699.27 MWD+IFR2+MS+sag (2) 3,815.98 52.06 38.95 3,347.55 937.29 1,040.963,291.35 6,032,041.42 470,968.59 3.08 747.88 MWD+IFR2+MS+sag (2) 3,913.69 53.35 38.96 3,406.76 997.74 1,089.833,350.56 6,032,101.66 471,017.70 1.32 799.20 MWD+IFR2+MS+sag (2) 4,007.06 52.27 39.23 3,463.20 1,055.47 1,136.733,407.00 6,032,159.19 471,064.83 1.18 848.17 MWD+IFR2+MS+sag (2) 4,093.51 53.19 39.45 3,515.55 1,108.67 1,180.343,459.35 6,032,212.22 471,108.65 1.08 893.24 MWD+IFR2+MS+sag (2) 4,193.35 50.77 38.33 3,577.04 1,169.88 1,229.733,520.84 6,032,273.22 471,158.28 2.58 945.22 MWD+IFR2+MS+sag (3) 4,235.17 50.22 38.20 3,603.64 1,195.21 1,249.713,547.44 6,032,298.47 471,178.36 1.34 966.81 MWD+IFR2+MS+sag (3) 4,329.62 50.67 36.91 3,663.79 1,252.94 1,294.103,607.59 6,032,356.01 471,222.97 1.16 1,016.21 MWD+IFR2+MS+sag (3) 4,424.83 50.66 37.77 3,724.14 1,311.49 1,338.763,667.94 6,032,414.37 471,267.87 0.70 1,066.37 MWD+IFR2+MS+sag (3) 4,520.03 51.23 38.51 3,784.12 1,369.63 1,384.423,727.92 6,032,472.32 471,313.76 0.85 1,115.96 MWD+IFR2+MS+sag (3) 12/14/2012 1:08:21PM COMPASS 2003.16 Build 42 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSN-29 ODSN-29 PN5 PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-29 PN5 PB2 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-29 True MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 4,614.29 51.72 40.80 3,842.84 1,426.40 1,431.483,786.64 6,032,528.89 471,361.04 1.97 1,163.95 MWD+IFR2+MS+sag (3) 4,710.58 51.23 38.43 3,902.82 1,484.42 1,479.513,846.62 6,032,586.71 471,409.30 1.99 1,213.02 MWD+IFR2+MS+sag (3) 4,805.30 49.64 37.91 3,963.15 1,541.82 1,524.633,906.95 6,032,643.92 471,454.66 1.73 1,261.97 MWD+IFR2+MS+sag (3) 4,899.73 49.48 38.02 4,024.40 1,598.48 1,568.853,968.20 6,032,700.40 471,499.09 0.19 1,310.34 MWD+IFR2+MS+sag (3) 4,992.80 50.29 38.34 4,084.37 1,654.43 1,612.844,028.17 6,032,756.16 471,543.31 0.91 1,358.05 MWD+IFR2+MS+sag (3) 5,090.15 50.44 39.45 4,146.47 1,712.78 1,659.924,090.27 6,032,814.31 471,590.61 0.89 1,407.60 MWD+IFR2+MS+sag (3) 5,185.51 51.01 37.43 4,206.84 1,770.59 1,705.804,150.64 6,032,871.94 471,636.73 1.75 1,456.83 MWD+IFR2+MS+sag (3) 5,280.47 50.10 37.49 4,267.17 1,828.80 1,750.404,210.97 6,032,929.96 471,681.56 0.96 1,506.67 MWD+IFR2+MS+sag (3) 5,375.64 49.67 38.02 4,328.49 1,886.35 1,794.964,272.29 6,032,987.32 471,726.35 0.62 1,555.85 MWD+IFR2+MS+sag (3) 5,471.03 51.32 37.62 4,389.17 1,944.48 1,840.094,332.97 6,033,045.27 471,771.70 1.76 1,605.53 MWD+IFR2+MS+sag (3) 5,565.75 51.40 38.05 4,448.32 2,002.92 1,885.474,392.12 6,033,103.51 471,817.32 0.36 1,655.45 MWD+IFR2+MS+sag (3) 5,661.24 51.07 37.96 4,508.10 2,061.58 1,931.314,451.90 6,033,161.98 471,863.39 0.35 1,705.52 MWD+IFR2+MS+sag (3) 5,755.74 50.60 37.62 4,567.79 2,119.48 1,976.214,511.59 6,033,219.70 471,908.52 0.57 1,755.00 MWD+IFR2+MS+sag (3) 5,852.58 50.84 37.86 4,629.10 2,178.76 2,022.094,572.90 6,033,278.78 471,954.64 0.31 1,805.68 MWD+IFR2+MS+sag (3) 5,948.17 51.25 37.06 4,689.20 2,237.77 2,067.304,633.00 6,033,337.60 472,000.08 0.78 1,856.19 MWD+IFR2+MS+sag (3) 6,041.98 50.15 37.38 4,748.61 2,295.57 2,111.214,692.41 6,033,395.22 472,044.22 1.20 1,905.75 MWD+IFR2+MS+sag (3) 6,136.90 49.57 37.71 4,809.80 2,353.11 2,155.434,753.60 6,033,452.57 472,088.66 0.67 1,954.98 MWD+IFR2+MS+sag (3) 6,233.24 49.87 39.47 4,872.09 2,410.55 2,201.274,815.89 6,033,509.82 472,134.73 1.43 2,003.85 MWD+IFR2+MS+sag (3) 6,327.80 50.83 38.16 4,932.43 2,467.28 2,246.904,876.23 6,033,566.36 472,180.59 1.47 2,052.05 MWD+IFR2+MS+sag (3) 6,422.21 50.76 37.12 4,992.11 2,525.21 2,291.584,935.91 6,033,624.10 472,225.49 0.86 2,101.60 MWD+IFR2+MS+sag (3) 6,517.54 51.12 37.06 5,052.18 2,584.26 2,336.224,995.98 6,033,682.96 472,270.37 0.38 2,152.25 MWD+IFR2+MS+sag (3) 6,612.58 50.97 38.58 5,111.93 2,642.64 2,381.535,055.73 6,033,741.15 472,315.91 1.25 2,202.13 MWD+IFR2+MS+sag (3) 6,708.03 50.51 38.55 5,172.34 2,700.42 2,427.605,116.14 6,033,798.75 472,362.21 0.48 2,251.30 MWD+IFR2+MS+sag (3) 6,803.17 50.84 38.39 5,232.63 2,758.04 2,473.395,176.43 6,033,856.18 472,408.23 0.37 2,300.35 MWD+IFR2+MS+sag (3) 6,898.93 51.00 39.16 5,293.00 2,816.00 2,519.945,236.80 6,033,913.93 472,455.01 0.65 2,349.60 MWD+IFR2+MS+sag (3) 6,994.31 51.17 38.97 5,352.91 2,873.62 2,566.715,296.71 6,033,971.36 472,502.01 0.24 2,398.49 MWD+IFR2+MS+sag (3) 7,089.04 51.17 37.23 5,412.31 2,931.69 2,612.245,356.11 6,034,029.24 472,547.77 1.43 2,448.03 MWD+IFR2+MS+sag (3) 7,186.05 50.62 36.84 5,473.50 2,991.78 2,657.585,417.30 6,034,089.14 472,593.35 0.65 2,499.59 MWD+IFR2+MS+sag (3) 7,239.97 51.01 37.04 5,507.57 3,025.18 2,682.705,451.37 6,034,122.44 472,618.60 0.78 2,528.27 MWD+IFR2+MS+sag (4) 7,253.31 51.20 37.06 5,515.94 3,033.47 2,688.965,459.74 6,034,130.70 472,624.89 1.43 2,535.38 MWD+IFR2+MS+sag (4) 7,347.99 51.20 38.68 5,575.27 3,091.71 2,734.255,519.07 6,034,188.75 472,670.41 1.33 2,585.14 MWD+IFR2+MS+sag (4) 7,443.25 50.19 38.10 5,635.62 3,149.48 2,780.035,579.42 6,034,246.33 472,716.42 1.16 2,634.34 MWD+IFR2+MS+sag (4) 7,538.01 49.51 37.02 5,696.72 3,206.90 2,824.185,640.52 6,034,303.56 472,760.80 1.13 2,683.46 MWD+IFR2+MS+sag (4) 7,633.13 50.49 34.29 5,757.86 3,266.10 2,866.645,701.66 6,034,362.59 472,803.49 2.43 2,734.64 MWD+IFR2+MS+sag (4) 7,728.76 51.43 30.23 5,818.11 3,328.90 2,906.255,761.91 6,034,425.22 472,843.35 3.44 2,789.84 MWD+IFR2+MS+sag (4) 7,822.71 52.22 26.12 5,876.20 3,393.98 2,941.105,820.00 6,034,490.15 472,878.46 3.54 2,848.10 MWD+IFR2+MS+sag (4) 7,919.13 51.97 19.97 5,935.47 3,463.93 2,970.865,879.27 6,034,559.97 472,908.50 5.04 2,912.01 MWD+IFR2+MS+sag (4) 8,014.10 52.00 15.77 5,993.97 3,535.11 2,993.815,937.77 6,034,631.06 472,931.74 3.48 2,978.29 MWD+IFR2+MS+sag (4) 8,109.08 54.08 9.02 6,051.12 3,609.17 3,010.035,994.92 6,034,705.04 472,948.25 6.08 3,048.54 MWD+IFR2+MS+sag (4) 8,204.65 55.50 4.49 6,106.24 3,686.68 3,019.186,050.04 6,034,782.51 472,957.72 4.15 3,123.39 MWD+IFR2+MS+sag (4) 12/14/2012 1:08:21PM COMPASS 2003.16 Build 42 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSN-29 ODSN-29 PN5 PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-29 PN5 PB2 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-29 True MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 8,299.52 56.76 357.64 6,159.15 3,765.36 3,020.616,102.95 6,034,861.17 472,959.46 6.14 3,200.70 MWD+IFR2+MS+sag (4) 8,395.04 59.96 354.49 6,209.26 3,846.47 3,014.996,153.06 6,034,942.29 472,954.17 4.37 3,281.58 MWD+IFR2+MS+sag (4) 8,490.01 63.54 352.73 6,254.21 3,929.58 3,005.666,198.01 6,035,025.43 472,945.18 4.11 3,365.08 MWD+IFR2+MS+sag (4) 8,585.18 68.13 351.60 6,293.16 4,015.58 2,993.816,236.96 6,035,111.47 472,933.68 4.94 3,451.84 MWD+IFR2+MS+sag (4) 8,680.70 72.73 351.59 6,325.15 4,104.59 2,980.666,268.95 6,035,200.52 472,920.89 4.82 3,541.80 MWD+IFR2+MS+sag (4) 8,775.68 77.59 351.73 6,349.47 4,195.40 2,967.356,293.27 6,035,291.38 472,907.95 5.12 3,633.55 MWD+IFR2+MS+sag (4) 8,871.40 81.78 350.38 6,366.60 4,288.40 2,952.706,310.40 6,035,384.43 472,893.68 4.59 3,727.69 MWD+IFR2+MS+sag (4) 8,966.20 85.58 350.25 6,377.04 4,381.27 2,936.856,320.84 6,035,477.35 472,878.21 4.01 3,821.90 MWD+IFR2+MS+sag (4) 9,017.12 87.31 349.59 6,380.19 4,431.30 2,927.966,323.99 6,035,527.41 472,869.52 3.64 3,872.72 MWD+IFR2+MS+sag (4) 9,060.56 87.43 349.78 6,382.19 4,474.00 2,920.196,325.99 6,035,570.13 472,861.92 0.52 3,916.11 MWD+IFR2+MS+sag (4) 9,112.53 87.43 349.67 6,384.52 4,525.08 2,910.936,328.32 6,035,621.25 472,852.87 0.21 3,968.03 MWD+IFR2+MS+sag (4) 9,156.56 87.01 349.26 6,386.65 4,568.32 2,902.896,330.45 6,035,664.52 472,845.00 1.33 4,012.00 MWD+IFR2+MS+sag (4) 9,252.44 87.06 344.00 6,391.62 4,661.44 2,880.756,335.42 6,035,757.72 472,823.25 5.48 4,107.53 MWD+IFR2+MS+sag (4) 9,346.04 85.39 339.79 6,397.78 4,750.19 2,851.746,341.58 6,035,846.58 472,794.60 4.83 4,199.90 MWD+IFR2+MS+sag (4) 9,442.51 84.96 334.69 6,405.90 4,838.81 2,814.566,349.70 6,035,935.33 472,757.78 5.29 4,293.52 MWD+IFR2+MS+sag (4) 9,537.10 85.58 330.13 6,413.70 4,922.33 2,770.916,357.50 6,036,019.02 472,714.48 4.85 4,383.22 MWD+IFR2+MS+sag (4) 9,632.57 85.64 324.03 6,421.02 5,002.20 2,719.216,364.82 6,036,099.09 472,663.10 6.37 4,470.68 MWD+IFR2+MS+sag (4) 9,663.68 85.70 322.57 6,423.37 5,027.07 2,700.676,367.17 6,036,124.03 472,644.66 4.68 4,498.33 MWD+IFR2+MS+sag (4) 9,697.60 85.58 320.58 6,425.95 5,053.56 2,679.656,369.75 6,036,150.61 472,623.75 5.86 4,527.99 MWD+IFR2+MS+sag (4) 9,776.75 87.78 318.00 6,430.53 5,113.45 2,628.126,374.33 6,036,210.70 472,572.47 4.28 4,595.73 MWD+IFR2+MS+sag (5) 9,862.68 88.58 317.11 6,433.26 5,176.83 2,570.166,377.06 6,036,274.30 472,514.77 1.39 4,667.99 MWD+IFR2+MS+sag (5) 9,959.37 88.46 317.67 6,435.76 5,247.97 2,504.726,379.56 6,036,345.70 472,449.63 0.59 4,749.16 MWD+IFR2+MS+sag (5) 10,055.30 86.60 317.60 6,439.89 5,318.78 2,440.146,383.69 6,036,416.76 472,385.34 1.94 4,829.87 MWD+IFR2+MS+sag (5) 10,152.06 88.21 316.05 6,444.27 5,389.26 2,374.006,388.07 6,036,487.51 472,319.50 2.31 4,910.52 MWD+IFR2+MS+sag (5) 10,248.25 90.74 313.95 6,445.15 5,457.27 2,306.006,388.95 6,036,555.78 472,251.78 3.42 4,989.04 MWD+IFR2+MS+sag (5) 10,344.58 90.99 313.70 6,443.70 5,523.96 2,236.516,387.50 6,036,622.75 472,182.56 0.37 5,066.52 MWD+IFR2+MS+sag (5) 10,441.15 91.67 313.39 6,441.46 5,590.47 2,166.536,385.26 6,036,689.54 472,112.86 0.77 5,143.90 MWD+IFR2+MS+sag (5) 10,536.95 92.22 312.87 6,438.21 5,655.93 2,096.666,382.01 6,036,755.27 472,043.26 0.79 5,220.22 MWD+IFR2+MS+sag (5) 10,633.35 91.85 314.43 6,434.78 5,722.43 2,026.956,378.58 6,036,822.04 471,973.83 1.66 5,297.54 MWD+IFR2+MS+sag (5) 10,729.68 90.56 314.67 6,432.76 5,789.99 1,958.326,376.56 6,036,889.87 471,905.48 1.36 5,375.73 MWD+IFR2+MS+sag (5) 10,825.68 91.30 314.76 6,431.20 5,857.52 1,890.116,375.00 6,036,957.68 471,837.55 0.78 5,453.82 MWD+IFR2+MS+sag (5) 10,922.06 90.37 313.66 6,429.80 5,924.72 1,821.036,373.60 6,037,025.15 471,768.76 1.49 5,531.73 MWD+IFR2+MS+sag (5) 11,018.42 91.17 310.85 6,428.50 5,989.50 1,749.736,372.30 6,037,090.21 471,697.72 3.03 5,607.63 MWD+IFR2+MS+sag (5) 11,115.04 92.47 310.17 6,425.43 6,052.23 1,676.316,369.23 6,037,153.23 471,624.56 1.52 5,681.87 MWD+IFR2+MS+sag (5) 11,210.97 92.59 309.82 6,421.20 6,113.83 1,602.896,365.00 6,037,215.12 471,551.40 0.39 5,754.98 MWD+IFR2+MS+sag (5) 11,307.49 92.29 311.57 6,417.09 6,176.70 1,529.786,360.89 6,037,278.28 471,478.55 1.84 5,829.31 MWD+IFR2+MS+sag (5) 11,403.74 91.54 313.13 6,413.87 6,241.50 1,458.696,357.67 6,037,343.36 471,407.73 1.80 5,905.19 MWD+IFR2+MS+sag (5) 11,500.65 91.61 314.11 6,411.21 6,308.33 1,388.566,355.01 6,037,410.47 471,337.88 1.01 5,982.91 MWD+IFR2+MS+sag (5) 11,595.80 92.16 315.42 6,408.08 6,375.30 1,321.046,351.88 6,037,477.70 471,270.64 1.49 6,060.33 MWD+IFR2+MS+sag (5) 11,692.96 89.82 317.05 6,406.40 6,445.45 1,253.856,350.20 6,037,548.11 471,203.74 2.93 6,140.82 MWD+IFR2+MS+sag (5) 12/14/2012 1:08:21PM COMPASS 2003.16 Build 42 Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSN-29 ODSN-29 PN5 PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-29 PN5 PB2 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-29 True MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 11,787.10 89.75 316.37 6,406.75 6,513.97 1,189.306,350.55 6,037,616.89 471,139.47 0.73 6,219.27 MWD+IFR2+MS+sag (5) 11,885.85 90.06 316.41 6,406.92 6,585.47 1,121.196,350.72 6,037,688.66 471,071.66 0.32 6,301.25 MWD+IFR2+MS+sag (5) 11,930.00 91.64 315.62 6,406.26 6,617.23 1,090.536,350.06 6,037,720.54 471,041.13 4.00 6,337.74 MWD+IFR2+MS+sag (6) 11,982.38 88.70 316.59 6,406.11 6,654.98 1,054.226,349.91 6,037,758.42 471,004.98 5.91 6,381.08 MWD+IFR2+MS+sag (6) 12,078.63 90.49 317.22 6,406.79 6,725.25 988.466,350.59 6,037,828.96 470,939.51 1.97 6,461.46 MWD+IFR2+MS+sag (6) 12,173.76 89.69 319.77 6,406.64 6,796.49 925.436,350.44 6,037,900.44 470,876.77 2.81 6,542.32 MWD+IFR2+MS+sag (6) 12,270.70 88.95 319.99 6,407.79 6,870.61 862.976,351.59 6,037,974.81 470,814.62 0.80 6,625.94 MWD+IFR2+MS+sag (6) 12,367.70 90.00 322.34 6,408.68 6,946.16 802.156,352.48 6,038,050.60 470,754.11 2.65 6,710.68 MWD+IFR2+MS+sag (6) 12,463.93 90.37 324.79 6,408.36 7,023.58 745.006,352.16 6,038,128.24 470,697.28 2.57 6,796.63 MWD+IFR2+MS+sag (6) 12,560.38 87.10 323.14 6,410.49 7,101.54 688.286,354.29 6,038,206.42 470,640.89 3.80 6,883.06 MWD+IFR2+MS+sag (6) 12,656.14 88.21 318.40 6,414.41 7,175.63 627.796,358.21 6,038,280.75 470,580.70 5.08 6,966.31 MWD+IFR2+MS+sag (6) 12,753.18 88.46 312.81 6,417.24 7,244.91 559.966,361.04 6,038,350.30 470,513.16 5.76 7,046.06 MWD+IFR2+MS+sag (6) 12,849.23 92.10 310.33 6,416.77 7,308.63 488.126,360.57 6,038,414.30 470,441.58 4.59 7,121.00 MWD+IFR2+MS+sag (6) 12,945.70 91.91 311.58 6,413.39 7,371.82 415.316,357.19 6,038,477.78 470,369.03 1.31 7,195.59 MWD+IFR2+MS+sag (6) 13,041.26 92.60 311.23 6,409.63 7,434.97 343.696,353.43 6,038,541.21 470,297.68 0.81 7,269.94 MWD+IFR2+MS+sag (6) 13,138.40 92.78 310.74 6,405.07 7,498.61 270.446,348.87 6,038,605.14 470,224.70 0.54 7,345.04 MWD+IFR2+MS+sag (6) 13,235.25 92.72 311.27 6,400.43 7,562.09 197.446,344.23 6,038,668.90 470,151.96 0.55 7,419.94 MWD+IFR2+MS+sag (6) 13,330.33 92.59 312.55 6,396.02 7,625.53 126.756,339.82 6,038,732.62 470,081.54 1.35 7,494.41 MWD+IFR2+MS+sag (6) 13,427.17 92.59 312.94 6,391.65 7,691.19 55.716,335.45 6,038,798.56 470,010.77 0.40 7,571.14 MWD+IFR2+MS+sag (6) 13,524.23 91.79 313.29 6,387.94 7,757.48 -15.096,331.74 6,038,865.13 469,940.25 0.90 7,648.44 MWD+IFR2+MS+sag (6) 13,619.99 87.90 314.93 6,388.20 7,824.11 -83.836,332.00 6,038,932.04 469,871.78 4.41 7,725.73 MWD+IFR2+MS+sag (6) 13,716.44 87.41 312.76 6,392.14 7,890.87 -153.336,335.94 6,038,999.06 469,802.56 2.30 7,803.27 MWD+IFR2+MS+sag (6) 13,813.17 87.04 312.38 6,396.83 7,956.23 -224.486,340.63 6,039,064.71 469,731.68 0.55 7,879.71 MWD+IFR2+MS+sag (6) 13,908.90 87.22 309.71 6,401.62 8,019.00 -296.586,345.42 6,039,127.77 469,659.84 2.79 7,953.77 MWD+IFR2+MS+sag (6) 14,004.48 84.75 311.13 6,408.31 8,080.81 -369.176,352.11 6,039,189.87 469,587.52 2.98 8,026.96 MWD+IFR2+MS+sag (6) 14,101.20 86.05 309.21 6,416.07 8,143.00 -442.836,359.87 6,039,252.34 469,514.11 2.39 8,100.70 MWD+IFR2+MS+sag (6) 14,196.40 88.21 304.63 6,420.84 8,200.09 -518.826,364.64 6,039,309.74 469,438.36 5.31 8,169.82 MWD+IFR2+MS+sag (6) 14,292.19 89.32 305.22 6,422.90 8,254.92 -597.346,366.70 6,039,364.87 469,360.07 1.31 8,237.13 MWD+IFR2+MS+sag (6) 14,464.00 89.32 305.22 6,424.94 8,354.00 -737.696,368.74 6,039,464.51 469,220.14 0.00 8,358.50 PROJECTED to TD 12/14/2012 1:08:21PM COMPASS 2003.16 Build 42 Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSN-29 ODSN-29 PN5 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-29 PN5 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-29 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Oooguruk Development Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: ft +E/-W +N/-S Position Uncertainty ft ft ftGround Level: ODSN-29 ft ft 0.00 0.00 6,031,108.44 469,923.95 13.50Wellhead Elevation:ft0.00 70° 29' 45.820 N 150° 14' 45.357 W Wellbore Declination (?) Field Strength (nT) Sample Date Dip Angle (?) ODSN-29 PN5 Model NameMagnetics IGRF2010 10/10/2012 20.57 80.97 57,668 Phase:Version: Audit Notes: Design ODSN-29 PN5 1.0 ACTUAL Vertical Section: Depth From (TVD) (ft) +N/-S (ft) Direction (bearing) +E/-W (ft) Tie On Depth:13,041.26 350.270.000.0042.70 From (ft) Survey Program DescriptionTool NameSurvey (Wellbore) To (ft) Date 12/14/2012 Survey Start Date SRG-SS Surface readout gyro single shot100.00 729.00 ODSN-29 GYRO (ODSN-29 PN5 PB1)11/07/2012 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag775.48 4,138.70 ODSN-29 MWD (ODSN-29 PN5 PB1)11/08/2012 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag4,139.70 7,238.00 ODSN-29 MWD (ODSN-29 PN5 PB1)11/08/2012 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag7,238.00 9,697.60 ODSN-29 MWD (ODSN-29 PN5 PB1)11/08/2012 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag9,776.70 11,885.85 ODSN-29 MWD (ODSN-29 PN5 PB1)11/08/2012 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag11,930.00 13,041.26 ODSN-29 PN5 MWD (ODSN-29 PN5 PB 11/20/2012 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag13,138.40 15,641.71 ODSN-29 MWD (ODSN-29 PN5)11/26/2012 MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 42.70 0.00 0.00 42.70 0.00 0.00-13.50 6,031,108.44 469,923.95 0.00 0.00 UNDEFINED 100.00 0.12 142.74 100.00 -0.05 0.0443.80 6,031,108.39 469,923.99 0.21 -0.05 SRG-SS (1) 172.00 0.15 342.94 172.00 -0.02 0.05115.80 6,031,108.42 469,924.00 0.37 -0.03 SRG-SS (1) 261.00 1.50 148.91 260.99 -0.90 0.62204.79 6,031,107.53 469,924.57 1.85 -1.00 SRG-SS (1) 354.00 4.95 146.57 353.83 -5.30 3.46297.63 6,031,103.13 469,927.39 3.71 -5.80 SRG-SS (1) 448.00 9.11 143.99 447.10 -14.70 10.07390.90 6,031,093.70 469,933.96 4.44 -16.20 SRG-SS (1) 541.00 11.62 142.76 538.58 -28.12 20.07482.38 6,031,080.24 469,943.91 2.71 -31.11 SRG-SS (1) 636.00 10.55 138.46 631.81 -42.25 31.63575.61 6,031,066.07 469,955.41 1.42 -46.98 SRG-SS (1) 729.00 10.64 121.05 723.24 -53.05 44.63667.04 6,031,055.22 469,968.36 3.43 -59.83 SRG-SS (1) 12/14/2012 11:00:26AM COMPASS 2003.16 Build 42 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSN-29 ODSN-29 PN5 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-29 PN5 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-29 True MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 775.48 10.70 114.93 768.92 -57.08 52.22712.72 6,031,051.15 469,975.94 2.44 -65.09 MWD+IFR2+MS+sag (2) 871.35 10.29 106.10 863.19 -63.21 68.52806.99 6,031,044.96 469,992.21 1.73 -73.88 MWD+IFR2+MS+sag (2) 967.21 8.57 109.64 957.76 -67.98 83.48901.56 6,031,040.13 470,007.14 1.89 -81.11 MWD+IFR2+MS+sag (2) 1,057.98 8.88 89.26 1,047.50 -70.17 96.85991.30 6,031,037.89 470,020.51 3.40 -85.53 MWD+IFR2+MS+sag (2) 1,156.87 8.63 82.17 1,145.24 -69.06 111.841,089.04 6,031,038.94 470,035.50 1.12 -86.96 MWD+IFR2+MS+sag (2) 1,252.66 9.64 75.68 1,239.81 -66.09 126.731,183.61 6,031,041.84 470,050.40 1.50 -86.56 MWD+IFR2+MS+sag (2) 1,344.56 11.97 66.08 1,330.09 -60.33 142.901,273.89 6,031,047.54 470,066.59 3.20 -83.61 MWD+IFR2+MS+sag (2) 1,443.83 14.03 61.93 1,426.81 -50.49 162.931,370.61 6,031,057.30 470,086.66 2.28 -77.30 MWD+IFR2+MS+sag (2) 1,538.72 16.10 60.74 1,518.43 -38.64 184.561,462.23 6,031,069.05 470,108.33 2.21 -69.28 MWD+IFR2+MS+sag (2) 1,630.58 18.58 58.48 1,606.11 -24.76 208.151,549.91 6,031,082.84 470,131.98 2.80 -59.59 MWD+IFR2+MS+sag (2) 1,726.05 20.24 53.90 1,696.16 -7.08 234.461,639.96 6,031,100.41 470,158.36 2.36 -46.60 MWD+IFR2+MS+sag (2) 1,823.57 23.59 50.42 1,786.62 15.30 263.141,730.42 6,031,122.67 470,187.13 3.68 -29.39 MWD+IFR2+MS+sag (2) 1,919.50 24.52 50.45 1,874.22 40.20 293.291,818.02 6,031,147.45 470,217.37 0.97 -9.94 MWD+IFR2+MS+sag (2) 2,012.11 26.18 49.20 1,957.91 65.79 323.571,901.71 6,031,172.92 470,247.75 1.88 10.16 MWD+IFR2+MS+sag (2) 2,108.98 29.74 46.35 2,043.46 96.35 357.141,987.26 6,031,203.34 470,281.45 3.92 34.61 MWD+IFR2+MS+sag (2) 2,203.85 30.55 43.54 2,125.51 130.07 390.782,069.31 6,031,236.92 470,315.22 1.71 62.16 MWD+IFR2+MS+sag (2) 2,300.31 30.90 43.41 2,208.43 165.84 424.692,152.23 6,031,272.54 470,349.27 0.37 91.68 MWD+IFR2+MS+sag (2) 2,394.61 30.17 41.08 2,289.65 201.29 456.902,233.45 6,031,307.86 470,381.62 1.47 121.18 MWD+IFR2+MS+sag (2) 2,485.66 32.87 41.15 2,367.26 237.15 488.202,311.06 6,031,343.59 470,413.06 2.97 151.23 MWD+IFR2+MS+sag (2) 2,582.97 34.96 40.94 2,448.01 278.10 523.852,391.81 6,031,384.39 470,448.87 2.15 185.56 MWD+IFR2+MS+sag (2) 2,676.49 35.93 37.95 2,524.20 319.98 558.292,468.00 6,031,426.12 470,483.47 2.12 221.02 MWD+IFR2+MS+sag (2) 2,772.74 37.48 37.32 2,601.37 365.54 593.412,545.17 6,031,471.54 470,518.77 1.66 259.99 MWD+IFR2+MS+sag (2) 2,866.80 38.36 38.20 2,675.57 411.23 628.812,619.37 6,031,517.08 470,554.35 1.10 299.05 MWD+IFR2+MS+sag (2) 2,962.28 39.48 38.14 2,749.85 458.39 665.882,693.65 6,031,564.09 470,591.61 1.17 339.26 MWD+IFR2+MS+sag (2) 3,056.78 42.54 37.76 2,821.15 507.29 704.002,764.95 6,031,612.82 470,629.93 3.25 381.01 MWD+IFR2+MS+sag (2) 3,152.51 44.40 38.36 2,890.62 559.14 744.612,834.42 6,031,664.50 470,670.74 1.99 425.25 MWD+IFR2+MS+sag (2) 3,244.56 45.78 38.50 2,955.61 610.20 785.132,899.41 6,031,715.40 470,711.46 1.50 468.73 MWD+IFR2+MS+sag (2) 3,339.91 44.52 38.40 3,022.85 663.14 827.162,966.65 6,031,768.16 470,753.70 1.32 513.81 MWD+IFR2+MS+sag (2) 3,437.78 44.79 38.83 3,092.47 716.89 870.093,036.27 6,031,821.73 470,796.84 0.41 559.52 MWD+IFR2+MS+sag (2) 3,531.82 46.35 36.87 3,158.31 769.92 911.283,102.11 6,031,874.59 470,838.24 2.23 604.83 MWD+IFR2+MS+sag (2) 3,628.46 46.31 36.78 3,225.04 825.87 953.183,168.84 6,031,930.36 470,880.36 0.08 652.90 MWD+IFR2+MS+sag (2) 3,721.08 49.15 38.54 3,287.33 880.10 995.063,231.13 6,031,984.42 470,922.46 3.37 699.27 MWD+IFR2+MS+sag (2) 3,815.98 52.06 38.95 3,347.55 937.29 1,040.963,291.35 6,032,041.42 470,968.59 3.08 747.88 MWD+IFR2+MS+sag (2) 3,913.69 53.35 38.96 3,406.76 997.74 1,089.833,350.56 6,032,101.66 471,017.70 1.32 799.20 MWD+IFR2+MS+sag (2) 4,007.06 52.27 39.23 3,463.20 1,055.47 1,136.733,407.00 6,032,159.19 471,064.83 1.18 848.17 MWD+IFR2+MS+sag (2) 4,093.51 53.19 39.45 3,515.55 1,108.67 1,180.343,459.35 6,032,212.22 471,108.65 1.08 893.24 MWD+IFR2+MS+sag (2) 4,193.35 50.77 38.33 3,577.04 1,169.88 1,229.733,520.84 6,032,273.22 471,158.28 2.58 945.22 MWD+IFR2+MS+sag (3) 4,235.17 50.22 38.20 3,603.64 1,195.21 1,249.713,547.44 6,032,298.47 471,178.36 1.34 966.81 MWD+IFR2+MS+sag (3) 4,329.62 50.67 36.91 3,663.79 1,252.94 1,294.103,607.59 6,032,356.01 471,222.97 1.16 1,016.21 MWD+IFR2+MS+sag (3) 4,424.83 50.66 37.77 3,724.14 1,311.49 1,338.763,667.94 6,032,414.37 471,267.87 0.70 1,066.37 MWD+IFR2+MS+sag (3) 12/14/2012 11:00:26AM COMPASS 2003.16 Build 42 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSN-29 ODSN-29 PN5 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-29 PN5 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-29 True MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 4,520.03 51.23 38.51 3,784.12 1,369.63 1,384.423,727.92 6,032,472.32 471,313.76 0.85 1,115.96 MWD+IFR2+MS+sag (3) 4,614.29 51.72 40.80 3,842.84 1,426.40 1,431.483,786.64 6,032,528.89 471,361.04 1.97 1,163.95 MWD+IFR2+MS+sag (3) 4,710.58 51.23 38.43 3,902.82 1,484.42 1,479.513,846.62 6,032,586.71 471,409.30 1.99 1,213.02 MWD+IFR2+MS+sag (3) 4,805.30 49.64 37.91 3,963.15 1,541.82 1,524.633,906.95 6,032,643.92 471,454.66 1.73 1,261.97 MWD+IFR2+MS+sag (3) 4,899.73 49.48 38.02 4,024.40 1,598.48 1,568.853,968.20 6,032,700.40 471,499.09 0.19 1,310.34 MWD+IFR2+MS+sag (3) 4,992.80 50.29 38.34 4,084.37 1,654.43 1,612.844,028.17 6,032,756.16 471,543.31 0.91 1,358.05 MWD+IFR2+MS+sag (3) 5,090.15 50.44 39.45 4,146.47 1,712.78 1,659.924,090.27 6,032,814.31 471,590.61 0.89 1,407.60 MWD+IFR2+MS+sag (3) 5,185.51 51.01 37.43 4,206.84 1,770.59 1,705.804,150.64 6,032,871.94 471,636.73 1.75 1,456.83 MWD+IFR2+MS+sag (3) 5,280.47 50.10 37.49 4,267.17 1,828.80 1,750.404,210.97 6,032,929.96 471,681.56 0.96 1,506.67 MWD+IFR2+MS+sag (3) 5,375.64 49.67 38.02 4,328.49 1,886.35 1,794.964,272.29 6,032,987.32 471,726.35 0.62 1,555.85 MWD+IFR2+MS+sag (3) 5,471.03 51.32 37.62 4,389.17 1,944.48 1,840.094,332.97 6,033,045.27 471,771.70 1.76 1,605.53 MWD+IFR2+MS+sag (3) 5,565.75 51.40 38.05 4,448.32 2,002.92 1,885.474,392.12 6,033,103.51 471,817.32 0.36 1,655.45 MWD+IFR2+MS+sag (3) 5,661.24 51.07 37.96 4,508.10 2,061.58 1,931.314,451.90 6,033,161.98 471,863.39 0.35 1,705.52 MWD+IFR2+MS+sag (3) 5,755.74 50.60 37.62 4,567.79 2,119.48 1,976.214,511.59 6,033,219.70 471,908.52 0.57 1,755.00 MWD+IFR2+MS+sag (3) 5,852.58 50.84 37.86 4,629.10 2,178.76 2,022.094,572.90 6,033,278.78 471,954.64 0.31 1,805.68 MWD+IFR2+MS+sag (3) 5,948.17 51.25 37.06 4,689.20 2,237.77 2,067.304,633.00 6,033,337.60 472,000.08 0.78 1,856.19 MWD+IFR2+MS+sag (3) 6,041.98 50.15 37.38 4,748.61 2,295.57 2,111.214,692.41 6,033,395.22 472,044.22 1.20 1,905.75 MWD+IFR2+MS+sag (3) 6,136.90 49.57 37.71 4,809.80 2,353.11 2,155.434,753.60 6,033,452.57 472,088.66 0.67 1,954.98 MWD+IFR2+MS+sag (3) 6,233.24 49.87 39.47 4,872.09 2,410.55 2,201.274,815.89 6,033,509.82 472,134.73 1.43 2,003.85 MWD+IFR2+MS+sag (3) 6,327.80 50.83 38.16 4,932.43 2,467.28 2,246.904,876.23 6,033,566.36 472,180.59 1.47 2,052.05 MWD+IFR2+MS+sag (3) 6,422.21 50.76 37.12 4,992.11 2,525.21 2,291.584,935.91 6,033,624.10 472,225.49 0.86 2,101.60 MWD+IFR2+MS+sag (3) 6,517.54 51.12 37.06 5,052.18 2,584.26 2,336.224,995.98 6,033,682.96 472,270.37 0.38 2,152.25 MWD+IFR2+MS+sag (3) 6,612.58 50.97 38.58 5,111.93 2,642.64 2,381.535,055.73 6,033,741.15 472,315.91 1.25 2,202.13 MWD+IFR2+MS+sag (3) 6,708.03 50.51 38.55 5,172.34 2,700.42 2,427.605,116.14 6,033,798.75 472,362.21 0.48 2,251.30 MWD+IFR2+MS+sag (3) 6,803.17 50.84 38.39 5,232.63 2,758.04 2,473.395,176.43 6,033,856.18 472,408.23 0.37 2,300.35 MWD+IFR2+MS+sag (3) 6,898.93 51.00 39.16 5,293.00 2,816.00 2,519.945,236.80 6,033,913.93 472,455.01 0.65 2,349.60 MWD+IFR2+MS+sag (3) 6,994.31 51.17 38.97 5,352.91 2,873.62 2,566.715,296.71 6,033,971.36 472,502.01 0.24 2,398.49 MWD+IFR2+MS+sag (3) 7,089.04 51.17 37.23 5,412.31 2,931.69 2,612.245,356.11 6,034,029.24 472,547.77 1.43 2,448.03 MWD+IFR2+MS+sag (3) 7,186.05 50.62 36.84 5,473.50 2,991.78 2,657.585,417.30 6,034,089.14 472,593.35 0.65 2,499.59 MWD+IFR2+MS+sag (3) 7,239.97 51.01 37.04 5,507.57 3,025.18 2,682.705,451.37 6,034,122.44 472,618.60 0.78 2,528.27 MWD+IFR2+MS+sag (4) 7,253.31 51.20 37.06 5,515.94 3,033.47 2,688.965,459.74 6,034,130.70 472,624.89 1.43 2,535.38 MWD+IFR2+MS+sag (4) 7,347.99 51.20 38.68 5,575.27 3,091.71 2,734.255,519.07 6,034,188.75 472,670.41 1.33 2,585.14 MWD+IFR2+MS+sag (4) 7,443.25 50.19 38.10 5,635.62 3,149.48 2,780.035,579.42 6,034,246.33 472,716.42 1.16 2,634.34 MWD+IFR2+MS+sag (4) 7,538.01 49.51 37.02 5,696.72 3,206.90 2,824.185,640.52 6,034,303.56 472,760.80 1.13 2,683.46 MWD+IFR2+MS+sag (4) 7,633.13 50.49 34.29 5,757.86 3,266.10 2,866.645,701.66 6,034,362.59 472,803.49 2.43 2,734.64 MWD+IFR2+MS+sag (4) 7,728.76 51.43 30.23 5,818.11 3,328.90 2,906.255,761.91 6,034,425.22 472,843.35 3.44 2,789.84 MWD+IFR2+MS+sag (4) 7,822.71 52.22 26.12 5,876.20 3,393.98 2,941.105,820.00 6,034,490.15 472,878.46 3.54 2,848.10 MWD+IFR2+MS+sag (4) 7,919.13 51.97 19.97 5,935.47 3,463.93 2,970.865,879.27 6,034,559.97 472,908.50 5.04 2,912.01 MWD+IFR2+MS+sag (4) 8,014.10 52.00 15.77 5,993.97 3,535.11 2,993.815,937.77 6,034,631.06 472,931.74 3.48 2,978.29 MWD+IFR2+MS+sag (4) 8,109.08 54.08 9.02 6,051.12 3,609.17 3,010.035,994.92 6,034,705.04 472,948.25 6.08 3,048.54 MWD+IFR2+MS+sag (4) 12/14/2012 11:00:26AM COMPASS 2003.16 Build 42 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSN-29 ODSN-29 PN5 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-29 PN5 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-29 True MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 8,204.65 55.50 4.49 6,106.24 3,686.68 3,019.186,050.04 6,034,782.51 472,957.72 4.15 3,123.39 MWD+IFR2+MS+sag (4) 8,299.52 56.76 357.64 6,159.15 3,765.36 3,020.616,102.95 6,034,861.17 472,959.46 6.14 3,200.70 MWD+IFR2+MS+sag (4) 8,395.04 59.96 354.49 6,209.26 3,846.47 3,014.996,153.06 6,034,942.29 472,954.17 4.37 3,281.58 MWD+IFR2+MS+sag (4) 8,490.01 63.54 352.73 6,254.21 3,929.58 3,005.666,198.01 6,035,025.43 472,945.18 4.11 3,365.08 MWD+IFR2+MS+sag (4) 8,585.18 68.13 351.60 6,293.16 4,015.58 2,993.816,236.96 6,035,111.47 472,933.68 4.94 3,451.84 MWD+IFR2+MS+sag (4) 8,680.70 72.73 351.59 6,325.15 4,104.59 2,980.666,268.95 6,035,200.52 472,920.89 4.82 3,541.80 MWD+IFR2+MS+sag (4) 8,775.68 77.59 351.73 6,349.47 4,195.40 2,967.356,293.27 6,035,291.38 472,907.95 5.12 3,633.55 MWD+IFR2+MS+sag (4) 8,871.40 81.78 350.38 6,366.60 4,288.40 2,952.706,310.40 6,035,384.43 472,893.68 4.59 3,727.69 MWD+IFR2+MS+sag (4) 8,966.20 85.58 350.25 6,377.04 4,381.27 2,936.856,320.84 6,035,477.35 472,878.21 4.01 3,821.90 MWD+IFR2+MS+sag (4) 9,017.12 87.31 349.59 6,380.19 4,431.30 2,927.966,323.99 6,035,527.41 472,869.52 3.64 3,872.72 MWD+IFR2+MS+sag (4) 9,060.56 87.43 349.78 6,382.19 4,474.00 2,920.196,325.99 6,035,570.13 472,861.92 0.52 3,916.11 MWD+IFR2+MS+sag (4) 9,112.53 87.43 349.67 6,384.52 4,525.08 2,910.936,328.32 6,035,621.25 472,852.87 0.21 3,968.03 MWD+IFR2+MS+sag (4) 9,156.56 87.01 349.26 6,386.65 4,568.32 2,902.896,330.45 6,035,664.52 472,845.00 1.33 4,012.00 MWD+IFR2+MS+sag (4) 9,252.44 87.06 344.00 6,391.62 4,661.44 2,880.756,335.42 6,035,757.72 472,823.25 5.48 4,107.53 MWD+IFR2+MS+sag (4) 9,346.04 85.39 339.79 6,397.78 4,750.19 2,851.746,341.58 6,035,846.58 472,794.60 4.83 4,199.90 MWD+IFR2+MS+sag (4) 9,442.51 84.96 334.69 6,405.90 4,838.81 2,814.566,349.70 6,035,935.33 472,757.78 5.29 4,293.52 MWD+IFR2+MS+sag (4) 9,537.10 85.58 330.13 6,413.70 4,922.33 2,770.916,357.50 6,036,019.02 472,714.48 4.85 4,383.22 MWD+IFR2+MS+sag (4) 9,632.57 85.64 324.03 6,421.02 5,002.20 2,719.216,364.82 6,036,099.09 472,663.10 6.37 4,470.68 MWD+IFR2+MS+sag (4) 9,663.68 85.70 322.57 6,423.37 5,027.07 2,700.676,367.17 6,036,124.03 472,644.66 4.68 4,498.33 MWD+IFR2+MS+sag (4) 9,697.60 85.58 320.58 6,425.95 5,053.56 2,679.656,369.75 6,036,150.61 472,623.75 5.86 4,527.99 MWD+IFR2+MS+sag (4) 9,776.75 87.78 318.00 6,430.53 5,113.45 2,628.126,374.33 6,036,210.70 472,572.47 4.28 4,595.73 MWD+IFR2+MS+sag (5) 9,862.68 88.58 317.11 6,433.26 5,176.83 2,570.166,377.06 6,036,274.30 472,514.77 1.39 4,667.99 MWD+IFR2+MS+sag (5) 9,959.37 88.46 317.67 6,435.76 5,247.97 2,504.726,379.56 6,036,345.70 472,449.63 0.59 4,749.16 MWD+IFR2+MS+sag (5) 10,055.30 86.60 317.60 6,439.89 5,318.78 2,440.146,383.69 6,036,416.76 472,385.34 1.94 4,829.87 MWD+IFR2+MS+sag (5) 10,152.06 88.21 316.05 6,444.27 5,389.26 2,374.006,388.07 6,036,487.51 472,319.50 2.31 4,910.52 MWD+IFR2+MS+sag (5) 10,248.25 90.74 313.95 6,445.15 5,457.27 2,306.006,388.95 6,036,555.78 472,251.78 3.42 4,989.04 MWD+IFR2+MS+sag (5) 10,344.58 90.99 313.70 6,443.70 5,523.96 2,236.516,387.50 6,036,622.75 472,182.56 0.37 5,066.52 MWD+IFR2+MS+sag (5) 10,441.15 91.67 313.39 6,441.46 5,590.47 2,166.536,385.26 6,036,689.54 472,112.86 0.77 5,143.90 MWD+IFR2+MS+sag (5) 10,536.95 92.22 312.87 6,438.21 5,655.93 2,096.666,382.01 6,036,755.27 472,043.26 0.79 5,220.22 MWD+IFR2+MS+sag (5) 10,633.35 91.85 314.43 6,434.78 5,722.43 2,026.956,378.58 6,036,822.04 471,973.83 1.66 5,297.54 MWD+IFR2+MS+sag (5) 10,729.68 90.56 314.67 6,432.76 5,789.99 1,958.326,376.56 6,036,889.87 471,905.48 1.36 5,375.73 MWD+IFR2+MS+sag (5) 10,825.68 91.30 314.76 6,431.20 5,857.52 1,890.116,375.00 6,036,957.68 471,837.55 0.78 5,453.82 MWD+IFR2+MS+sag (5) 10,922.06 90.37 313.66 6,429.80 5,924.72 1,821.036,373.60 6,037,025.15 471,768.76 1.49 5,531.73 MWD+IFR2+MS+sag (5) 11,018.42 91.17 310.85 6,428.50 5,989.50 1,749.736,372.30 6,037,090.21 471,697.72 3.03 5,607.63 MWD+IFR2+MS+sag (5) 11,115.04 92.47 310.17 6,425.43 6,052.23 1,676.316,369.23 6,037,153.23 471,624.56 1.52 5,681.87 MWD+IFR2+MS+sag (5) 11,210.97 92.59 309.82 6,421.20 6,113.83 1,602.896,365.00 6,037,215.12 471,551.40 0.39 5,754.98 MWD+IFR2+MS+sag (5) 11,307.49 92.29 311.57 6,417.09 6,176.70 1,529.786,360.89 6,037,278.28 471,478.55 1.84 5,829.31 MWD+IFR2+MS+sag (5) 11,403.74 91.54 313.13 6,413.87 6,241.50 1,458.696,357.67 6,037,343.36 471,407.73 1.80 5,905.19 MWD+IFR2+MS+sag (5) 11,500.65 91.61 314.11 6,411.21 6,308.33 1,388.566,355.01 6,037,410.47 471,337.88 1.01 5,982.91 MWD+IFR2+MS+sag (5) 11,595.80 92.16 315.42 6,408.08 6,375.30 1,321.046,351.88 6,037,477.70 471,270.64 1.49 6,060.33 MWD+IFR2+MS+sag (5) 12/14/2012 11:00:26AM COMPASS 2003.16 Build 42 Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSN-29 ODSN-29 PN5 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-29 PN5 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-29 True MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 11,692.96 89.82 317.05 6,406.40 6,445.45 1,253.856,350.20 6,037,548.11 471,203.74 2.93 6,140.82 MWD+IFR2+MS+sag (5) 11,787.10 89.75 316.37 6,406.75 6,513.97 1,189.306,350.55 6,037,616.89 471,139.47 0.73 6,219.27 MWD+IFR2+MS+sag (5) 11,885.85 90.06 316.41 6,406.92 6,585.47 1,121.196,350.72 6,037,688.66 471,071.66 0.32 6,301.25 MWD+IFR2+MS+sag (5) 11,930.00 91.64 315.62 6,406.26 6,617.23 1,090.536,350.06 6,037,720.54 471,041.13 4.00 6,337.74 MWD+IFR2+MS+sag (6) 11,982.38 88.70 316.59 6,406.11 6,654.98 1,054.226,349.91 6,037,758.42 471,004.98 5.91 6,381.08 MWD+IFR2+MS+sag (6) 12,078.63 90.49 317.22 6,406.79 6,725.25 988.466,350.59 6,037,828.96 470,939.51 1.97 6,461.46 MWD+IFR2+MS+sag (6) 12,173.76 89.69 319.77 6,406.64 6,796.49 925.436,350.44 6,037,900.44 470,876.77 2.81 6,542.32 MWD+IFR2+MS+sag (6) 12,270.70 88.95 319.99 6,407.79 6,870.61 862.976,351.59 6,037,974.81 470,814.62 0.80 6,625.94 MWD+IFR2+MS+sag (6) 12,367.70 90.00 322.34 6,408.68 6,946.16 802.156,352.48 6,038,050.60 470,754.11 2.65 6,710.68 MWD+IFR2+MS+sag (6) 12,463.93 90.37 324.79 6,408.36 7,023.58 745.006,352.16 6,038,128.24 470,697.28 2.57 6,796.63 MWD+IFR2+MS+sag (6) 12,560.38 87.10 323.14 6,410.49 7,101.54 688.286,354.29 6,038,206.42 470,640.89 3.80 6,883.06 MWD+IFR2+MS+sag (6) 12,656.14 88.21 318.40 6,414.41 7,175.63 627.796,358.21 6,038,280.75 470,580.70 5.08 6,966.31 MWD+IFR2+MS+sag (6) 12,753.18 88.46 312.81 6,417.24 7,244.91 559.966,361.04 6,038,350.30 470,513.16 5.76 7,046.06 MWD+IFR2+MS+sag (6) 12,849.23 92.10 310.33 6,416.77 7,308.63 488.126,360.57 6,038,414.30 470,441.58 4.59 7,121.00 MWD+IFR2+MS+sag (6) 12,945.70 91.91 311.58 6,413.39 7,371.82 415.316,357.19 6,038,477.78 470,369.03 1.31 7,195.59 MWD+IFR2+MS+sag (6) 13,041.26 92.60 311.23 6,409.63 7,434.97 343.696,353.43 6,038,541.21 470,297.68 0.81 7,269.94 MWD+IFR2+MS+sag (6) 13,138.40 92.78 310.74 6,405.07 7,498.61 270.446,348.87 6,038,605.14 470,224.70 0.54 7,345.04 MWD+IFR2+MS+sag (7) 13,160.00 92.77 310.86 6,404.03 7,512.71 254.116,347.83 6,038,619.30 470,208.42 0.56 7,361.70 MWD+IFR2+MS+sag (7) 13,234.94 90.68 312.66 6,401.77 7,562.60 198.246,345.57 6,038,669.41 470,152.76 3.68 7,420.30 MWD+IFR2+MS+sag (7) 13,266.42 91.23 316.02 6,401.25 7,584.59 175.736,345.05 6,038,691.49 470,130.34 10.81 7,445.79 MWD+IFR2+MS+sag (7) 13,298.81 91.05 319.60 6,400.60 7,608.58 153.986,344.40 6,038,715.57 470,108.70 11.06 7,473.11 MWD+IFR2+MS+sag (7) 13,331.05 89.75 321.63 6,400.38 7,633.50 133.536,344.18 6,038,740.56 470,088.35 7.48 7,501.12 MWD+IFR2+MS+sag (7) 13,375.93 87.03 320.97 6,401.64 7,668.50 105.486,345.44 6,038,775.68 470,060.44 6.24 7,540.37 MWD+IFR2+MS+sag (7) 13,425.25 87.30 320.72 6,404.08 7,706.70 74.386,347.88 6,038,814.00 470,029.50 0.75 7,583.27 MWD+IFR2+MS+sag (7) 13,521.42 87.61 320.24 6,408.35 7,780.82 13.246,352.15 6,038,888.35 469,968.67 0.59 7,666.65 MWD+IFR2+MS+sag (7) 13,620.64 87.37 318.22 6,412.69 7,855.88 -51.496,356.49 6,038,963.67 469,904.25 2.05 7,751.58 MWD+IFR2+MS+sag (7) 13,713.69 88.09 316.20 6,416.38 7,924.11 -114.646,360.18 6,039,032.15 469,841.38 2.30 7,829.50 MWD+IFR2+MS+sag (7) 13,813.11 87.22 317.68 6,420.45 7,996.69 -182.466,364.25 6,039,104.99 469,773.86 1.73 7,912.49 MWD+IFR2+MS+sag (7) 13,908.93 89.73 316.11 6,423.00 8,066.61 -247.916,366.80 6,039,175.17 469,708.70 3.09 7,992.47 MWD+IFR2+MS+sag (7) 14,006.48 90.23 315.81 6,423.03 8,136.73 -315.726,366.83 6,039,245.56 469,641.18 0.60 8,073.05 MWD+IFR2+MS+sag (7) 14,102.79 89.29 314.52 6,423.43 8,205.03 -383.636,367.23 6,039,314.13 469,573.56 1.66 8,151.84 MWD+IFR2+MS+sag (7) 14,195.99 89.38 313.30 6,424.52 8,269.66 -450.766,368.32 6,039,379.02 469,506.69 1.31 8,226.88 MWD+IFR2+MS+sag (7) 14,293.79 89.56 313.82 6,425.42 8,337.05 -521.636,369.22 6,039,446.69 469,436.10 0.56 8,305.28 MWD+IFR2+MS+sag (7) 14,390.20 88.63 314.82 6,426.94 8,404.40 -590.606,370.74 6,039,514.31 469,367.42 1.42 8,383.32 MWD+IFR2+MS+sag (7) 14,485.27 90.58 314.45 6,427.60 8,471.19 -658.256,371.40 6,039,581.37 469,300.05 2.09 8,460.58 MWD+IFR2+MS+sag (7) 14,581.72 89.93 314.43 6,427.17 8,538.72 -727.116,370.97 6,039,649.17 469,231.47 0.67 8,538.78 MWD+IFR2+MS+sag (7) 14,679.67 89.62 313.98 6,427.55 8,607.01 -797.326,371.35 6,039,717.74 469,161.54 0.56 8,617.95 MWD+IFR2+MS+sag (7) 14,776.13 89.10 313.02 6,428.63 8,673.41 -867.296,372.43 6,039,784.41 469,091.85 1.13 8,695.22 MWD+IFR2+MS+sag (7) 14,872.86 89.03 312.36 6,430.21 8,738.98 -938.386,374.01 6,039,850.27 469,021.03 0.69 8,771.86 MWD+IFR2+MS+sag (7) 14,964.83 89.75 313.07 6,431.19 8,801.37 -1,005.956,374.99 6,039,912.92 468,953.72 1.10 8,844.77 MWD+IFR2+MS+sag (7) 12/14/2012 11:00:26AM COMPASS 2003.16 Build 42 Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Pioneer Natural Resources Definitive Survey Report Well: Wellbore: ODSN-29 ODSN-29 PN5 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-29 PN5 Database:EDM_Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-29 True MD (ft) Inc (?) Azi (bearin +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 15,063.55 89.94 312.28 6,431.46 8,868.28 -1,078.536,375.26 6,039,980.12 468,881.42 0.82 8,922.99 MWD+IFR2+MS+sag (7) 15,155.42 90.03 312.05 6,431.48 8,929.95 -1,146.626,375.28 6,040,042.06 468,813.58 0.27 8,995.28 MWD+IFR2+MS+sag (7) 15,254.31 90.00 312.14 6,431.45 8,996.24 -1,220.006,375.25 6,040,108.64 468,740.48 0.10 9,073.02 MWD+IFR2+MS+sag (7) 15,351.08 90.52 313.51 6,431.02 9,062.02 -1,290.976,374.82 6,040,174.70 468,669.78 1.51 9,149.85 MWD+IFR2+MS+sag (7) 15,448.71 90.06 314.71 6,430.52 9,129.97 -1,361.076,374.32 6,040,242.92 468,599.97 1.32 9,228.67 MWD+IFR2+MS+sag (7) 15,545.35 90.69 316.31 6,429.89 9,198.91 -1,428.796,373.69 6,040,312.13 468,532.53 1.78 9,308.06 MWD+IFR2+MS+sag (7) 15,641.71 89.87 316.89 6,429.42 9,268.92 -1,494.996,373.22 6,040,382.40 468,466.62 1.04 9,388.25 MWD+IFR2+MS+sag (7) 15,716.00 89.87 316.89 6,429.59 9,323.16 -1,545.766,373.39 6,040,436.83 468,416.07 0.00 9,450.29 PROJECTED to TD 12/14/2012 11:00:26AM COMPASS 2003.16 Build 42 Page 7 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 0 4 8 1 21 62 02 42 83 23 64 04 44 85 25 66 06 46 8 Me a s u r e d D e p t h Rig Days ODSN-29 Days vs. Depth 16 Oct 2012 Sperry SDL Arrive on Location Set 7" Casing 9774' MD, 6432' TVD 11 Nov 2012 Commenced 14.5" Surface Hole Section 15 Oct 2012 Commenced 10.625" Intermediate 1 Hole Section 23 Oct 2012 TD 14.5" Surface Hole Section 4145' MD, 3546' TVD 18 Oct 2012 TD Intermediate 2 9774' MD, 6431' TVD 5 Nov 2012 End ODSN 29 PB1 12464' MD-6381' TVD 20 Nov 2012 TD Intermediate 1 7270' MD, 5527' TVD 26 Oct 2012 Commenced 6.125" Production Hole Section 11 Nov 2012 Set 11.75" Casing 4139' MD, 3543' TVD 21 Oct 2012 Set 9.625" Casing 7238' MD, 5506' TVD 29 Oct 2012 Commenced 8.5" Intermediate 2 Hole Section 31 Oct 2012 End ODSN 29 PB2 14464' MD-' TVD 20 Nov 2012 TD Production 15716' MD, 6429' TVD 01 Dec 2012 08 Dec 2012 Sperry SDL rigged down in preparation for rig move Surface Data Logging After Action Review Employee Name: Andrew A. Bongard Date: 12/06/2012 Well: ODSN-29 Hole Section: All What went as, or better than, planned: Upon discovering INSITE v7.4.1 was incompatible with IRIS, we reverted back to INSITE v7.3.7 on the IRIS computer alone. During run changes, we closed INSITE on the IRIS computer. Upon opening INSITE, we hand entered all geometry. This process proved to be and effective and efficient run-change method. Difficulties experienced: An issue arose when starting new runs with INSITE v7.4.1 installed on the IRIS computer. Pit volume calculations were not being calculated, and the following values were not being displayed: standpipe psi, pump rates, cumulative strokes, and bottoms up/surface-to-surface strokes and minutes. Recommendations: Upgrade all computers with INSITE v7.4.2 Innovations and/or cost savings: After having issues with INSITE v7.4.1, as a temporary fix can use Iris Data Mapping (MWD Stats) to display pump stroke measurements. GeoTap Pressure Transient Analysis Client: Pioneer Natural Resources, Inc. Well: ODSN-29 Field: Oooguruk Rig: Nabors 19AC Country: USA Logged: 11/03/12 Analyst: Steve Kizziar Date: 01/14/12 Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 2 Table of Contents Overview ....................................................................................................................................................... 4 Log Header .................................................................................................................................................... 5 Test Summary ............................................................................................................................................... 8 Gradients ..................................................................................................................................................... 13 Gradient 0 ............................................................................................................................................... 13 Plots ............................................................................................................................................................ 15 Test No. 1.0; MD: 8326.54 ft; TVD: 6173.79 ft ........................................................................................ 15 Test No. 2.0; MD: 8324.53 ft; TVD: 6172.71 ft ........................................................................................ 16 Test No. 3.0; MD: 8322.49 ft; TVD: 6171.61 ft ........................................................................................ 17 Test No. 4.0; MD: 8317.03 ft; TVD: 6168.68 ft ........................................................................................ 18 Test No. 5.0; MD: 8313.03 ft; TVD: 6166.52 ft ........................................................................................ 19 Test No. 5.1; MD: 8313.03 ft; TVD: 6166.52 ft ........................................................................................ 20 Test No. 5.2; MD: 8313.03 ft; TVD: 6166.52 ft ........................................................................................ 21 Test No. 5.3; MD: 8313.03 ft; TVD: 6166.52 ft ........................................................................................ 22 Test No. 6.0; MD: 8308.98 ft; TVD: 6164.32 ft ........................................................................................ 23 Test No. 6.1; MD: 8308.98 ft; TVD: 6164.32 ft ........................................................................................ 24 Test No. 6.2; MD: 8308.98 ft; TVD: 6164.32 ft ........................................................................................ 25 Test No. 6.3; MD: 8308.98 ft; TVD: 6164.32 ft ........................................................................................ 26 Test No. 7.0; MD: 8298.51 ft; TVD: 6158.60 ft ........................................................................................ 27 Test No. 8.0; MD: 8295.52 ft; TVD: 6156.96 ft ........................................................................................ 28 Test No. 8.1; MD: 8295.52 ft; TVD: 6156.96 ft ........................................................................................ 29 Test No. 8.2; MD: 8295.52 ft; TVD: 6156.96 ft ........................................................................................ 30 Test No. 8.3; MD: 8295.52 ft; TVD: 6156.96 ft ........................................................................................ 31 Test No. 9.0; MD: 8292.03 ft; TVD: 6155.04 ft ........................................................................................ 32 Test No. 9.1; MD: 8292.03 ft; TVD: 6155.04 ft ........................................................................................ 33 Test No. 9.2; MD: 8292.03 ft; TVD: 6155.04 ft ........................................................................................ 34 Test No. 9.3; MD: 8292.03 ft; TVD: 6155.04 ft ........................................................................................ 35 Test No. 10.0; MD: 8288.01 ft; TVD: 6152.83 ft ...................................................................................... 36 Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 3 Test No. 10.1; MD: 8288.01 ft; TVD: 6152.83 ft ...................................................................................... 37 Test No. 10.2; MD: 8288.01 ft; TVD: 6152.83 ft ...................................................................................... 38 Test No. 10.3; MD: 8288.01 ft; TVD: 6152.83 ft ...................................................................................... 39 Test No. 11.0; MD: 8286.02 ft; TVD: 6151.74 ft ...................................................................................... 40 Test No. 11.1; MD: 8286.02 ft; TVD: 6151.74 ft ...................................................................................... 41 Test No. 11.2; MD: 8286.02 ft; TVD: 6151.74 ft ...................................................................................... 42 Test No. 11.3; MD: 8286.02 ft; TVD: 6151.74 ft ...................................................................................... 43 Disclaimer .................................................................................................................................................... 44 Drawdown Buildup Analysis ....................................................................................................................... 45 Exact Mobility Analysis ............................................................................................................................ 45 Test Quality Parameters.......................................................................................................................... 47 Automatic Test Comments ..................................................................................................................... 48 Dual Probe Anisotropy Analysis (Vertical Interference Testing) ............................................................. 49 Anisotropy Dip‐angle Corrections ....................................................................................................... 49 Flow Rate Determination ........................................................................................................................ 50 Automatic Flow Rate Option ............................................................................................................... 50 Manual Flow Rate Option ................................................................................................................... 50 Manual Volume Option ....................................................................................................................... 50 RTS Mobility Drawdown and Buildup Calculation Summary .................................................................. 51 Table 1 PTA Spherical Flow Regime Calculations (Typical Physical Units) ......................................... 51 Table 2 PTA Radial Flow Regime Calculations (Typical Physical Units) ............................................... 51 Table 3 PTA Variables & Constants Using Internal Program (Typical Physical Units) ........................ 52 Table 4 PTA Spherical Flow Regime Calculations (SI Units) ................................................................ 53 Table 5 PTA Radial Flow Regime Calculations (SI Units) ..................................................................... 53 Table 6 PTA Variables & Constants Using Internal Program SI Units .................................................. 54 RTS Theory References ........................................................................................................................... 55 Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 4 Overview At the request of Pioneer Natural Resources, Inc , the GeoTap 6-3/4” tool was run in the ODSN-29 well, Oooguruk field, USA in a 9.5 inch hole for formation pressures. Eleven tests were taken. All pressure points were taken while drilling with “pumps on” mode. Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 5 Log Header Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 6 Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 7 Houston Technology Center OD S N ‐29 14 January 2013 Co n f i d e n t i a l Page 8 Te s t Su m m a r y PR E S S U R E TE S T SU M M A R Y Te s t Id e n t i f i c a t i o n Hy d r o s t a t i c Pr e s . Eq . Mu d Wt . Te s t Pr e s s u r e s ‐ Te m p e r a t u r e s Te s t Times Remarks Te s t No . Fi l e No . MD (f t ) TV D (f t ) Ph y d s 1 (p s i a ) Ph y d s 2 (p s i a ) Eq F m M w (l b s / g a l ) Eq B h M w (l b s / g a l ) Ps d d (p s i a ) Pe d d (p s i a ) Ps t o p (p s i a ) dP o b (p s i a ) Te m p (d e g F ) dT d d (s e c ) dTbu (sec) 1. 0 70 0 ‐ 1. 0 83 2 6 . 5 4 61 7 3 . 7 9 41 5 6 . 0 4 41 2 3 . 1 0 3. 5 9 12 . 8 4 Low Perm, Still Building 2. 0 70 0 ‐ 2. 0 83 2 4 . 5 3 61 7 2 . 7 1 41 5 3 . 8 9 41 1 3 . 5 5 12 . 6 0 12 . 8 2 Low Perm, Still Building 3. 0 70 0 ‐ 3. 0 83 2 2 . 4 9 61 7 1 . 6 1 41 5 2 . 0 4 41 0 6 . 2 5 12 . 8 2 12 . 8 0 Potential Mud Set 4. 0 70 0 ‐ 4. 0 83 1 7 . 0 3 61 6 8 . 6 8 40 9 9 . 8 8 41 1 3 . 5 6 12 . 8 2 12 . 8 2 Potential Mud Set 5. 0 70 0 ‐ 5. 0 83 1 3 . 0 3 61 6 6 . 5 2 41 3 2 . 3 5 41 1 3 . 8 7 10 . 9 4 12 . 8 3 Fair Buildup Stability 5. 1 70 0 ‐ 5. 1 83 1 3 . 0 3 61 6 6 . 5 2 41 3 2 . 3 5 41 1 3 . 8 7 10 . 9 4 12 . 8 3 41 0 3 . 6 1 57 . 9 0 35 0 6 . 4 3 60 7 . 4 4 12 3 . 4 0 4. 0 1 156.71 Fair Buildup Stability 5. 2 70 0 ‐ 5. 2 83 1 3 . 0 3 61 6 6 . 5 2 41 3 2 . 3 5 41 1 3 . 8 7 10 . 9 4 12 . 8 3 34 9 8 . 7 9 22 5 . 6 9 35 0 8 . 0 9 60 5 . 7 8 12 3 . 4 0 4. 2 1 155.50 Fair Buildup Stability 5. 3 70 0 ‐ 5. 3 83 1 3 . 0 3 61 6 6 . 5 2 41 3 2 . 3 5 41 1 3 . 8 7 10 . 9 3 12 . 8 3 35 0 8 . 0 6 15 4 . 7 1 35 0 4 . 7 1 60 9 . 1 6 12 3 . 4 0 4. 8 2 155.50 Fair Buildup Stability 6. 0 70 0 ‐ 6. 0 83 0 8 . 9 8 61 6 4 . 3 2 41 0 1 . 5 0 41 0 9 . 7 9 10 . 9 4 12 . 8 2 Good Buildup Stability 6. 1 70 0 ‐ 6. 1 83 0 8 . 9 8 61 6 4 . 3 2 41 0 1 . 5 0 41 0 9 . 7 9 10 . 9 4 12 . 8 2 40 6 0 . 2 1 21 3 . 4 4 35 0 7 . 0 8 60 2 . 7 1 12 3 . 2 4 1. 8 1 158.31 Good Buildup Stability 6. 2 70 0 ‐ 6. 2 83 0 8 . 9 8 61 6 4 . 3 2 41 0 1 . 5 0 41 0 9 . 7 9 10 . 9 4 12 . 8 2 34 9 7 . 0 1 11 0 . 6 8 35 0 6 . 7 3 60 3 . 0 6 12 3 . 2 4 2. 0 1 159.11 Good Buildup Stability 6. 3 70 0 ‐ 6. 3 83 0 8 . 9 8 61 6 4 . 3 2 41 0 1 . 5 0 41 0 9 . 7 9 10 . 9 4 12 . 8 2 35 0 6 . 0 9 15 7 . 8 2 35 0 6 . 8 2 60 2 . 9 7 12 3 . 2 4 1. 8 1 159.31 Good Buildup Stability 7. 0 70 0 ‐ 7. 0 82 9 8 . 5 1 61 5 8 . 6 0 40 9 8 . 4 4 41 1 3 . 2 1 1. 1 4 12 . 8 4 Dry/Tight Test 8. 0 70 0 ‐ 8. 0 82 9 5 . 5 2 61 5 6 . 9 6 40 9 9 . 3 5 41 1 0 . 9 0 10 . 9 1 12 . 8 4 Good Buildup Stability 8. 1 70 0 ‐ 8. 1 82 9 5 . 5 2 61 5 6 . 9 6 40 9 9 . 3 5 41 1 0 . 9 0 10 . 9 1 12 . 8 4 41 5 8 . 0 5 28 7 5 . 9 9 34 9 4 . 2 0 61 6 . 7 0 12 3 . 9 4 9. 8 3 159.29 Good Buildup Stability 8. 2 70 0 ‐ 8. 2 82 9 5 . 5 2 61 5 6 . 9 6 40 9 9 . 3 5 41 1 0 . 9 0 10 . 9 1 12 . 8 4 34 9 5 . 0 0 28 1 8 . 8 2 34 9 4 . 3 4 61 6 . 5 7 12 3 . 9 4 10 . 0 3 158.69 Good Buildup Stability Houston Technology Center OD S N ‐29 14 January 2013 Co n f i d e n t i a l Page 9 PR E S S U R E TE S T SU M M A R Y Te s t Id e n t i f i c a t i o n Hy d r o s t a t i c Pr e s . Eq . Mu d Wt . Te s t Pr e s s u r e s ‐ Te m p e r a t u r e s Te s t Times Remarks Te s t No . Fi l e No . MD (f t ) TV D (f t ) Ph y d s 1 (p s i a ) Ph y d s 2 (p s i a ) Eq F m M w (l b s / g a l ) Eq B h M w (l b s / g a l ) Ps d d (p s i a ) Pe d d (p s i a ) Ps t o p (p s i a ) dP o b (p s i a ) Te m p (d e g F ) dT d d (s e c ) dTbu (sec) 8. 3 70 0 ‐ 8. 3 82 9 5 . 5 2 61 5 6 . 9 6 40 9 9 . 3 5 41 1 0 . 9 0 10 . 9 1 12 . 8 4 34 9 4 . 1 9 28 1 0 . 6 3 34 9 4 . 1 5 61 6 . 7 5 12 3 . 9 4 10 . 0 3 159.29 Good Buildup Stability 9. 0 70 0 ‐ 9. 0 82 9 2 . 0 3 61 5 5 . 0 4 40 9 6 . 9 2 41 1 0 . 7 0 10 . 9 2 12 . 8 4 Excellent Buildup Stability 9. 1 70 0 ‐ 9. 1 82 9 2 . 0 3 61 5 5 . 0 4 40 9 6 . 9 2 41 1 0 . 7 0 10 . 9 2 12 . 8 4 41 5 1 . 8 9 34 3 9 . 3 7 34 9 4 . 1 9 61 6 . 5 1 12 3 . 8 9 9. 6 3 159.69 Excellent Buildup Stability 9. 2 70 0 ‐ 9. 2 82 9 2 . 0 3 61 5 5 . 0 4 40 9 6 . 9 2 41 1 0 . 7 0 10 . 9 2 12 . 8 4 34 9 4 . 2 2 34 7 6 . 5 7 34 9 4 . 0 7 61 6 . 6 4 12 3 . 8 9 10 . 0 3 159.09 Excellent Buildup Stability 9. 3 70 0 ‐ 9. 3 82 9 2 . 0 3 61 5 5 . 0 4 40 9 6 . 9 2 41 1 0 . 7 0 10 . 9 2 12 . 8 4 34 9 4 . 0 9 34 7 8 . 1 0 34 9 3 . 9 8 61 6 . 7 2 12 3 . 8 9 10 . 0 3 159.29 Excellent Buildup Stability 10 . 0 70 0 ‐ 10 . 0 82 8 8 . 0 1 61 5 2 . 8 3 41 0 1 . 2 3 41 2 1 . 3 0 10 . 9 2 12 . 8 8 Excellent Buildup Stability 10 . 1 70 0 ‐ 10 . 1 82 8 8 . 0 1 61 5 2 . 8 3 41 0 1 . 2 3 41 2 1 . 3 0 10 . 9 2 12 . 8 8 39 6 2 . 8 1 34 8 4 . 2 7 34 9 4 . 0 9 62 7 . 2 0 12 3 . 8 9 6. 6 2 127.67 Excellent Buildup Stability 10 . 2 70 0 ‐ 10 . 2 82 8 8 . 0 1 61 5 2 . 8 3 41 0 1 . 2 3 41 2 1 . 3 0 10 . 9 2 12 . 8 8 34 9 4 . 1 5 34 8 9 . 4 3 34 9 3 . 8 4 62 7 . 4 5 12 3 . 8 9 6. 8 2 127.07 Excellent Buildup Stability 10 . 3 70 0 ‐ 10 . 3 82 8 8 . 0 1 61 5 2 . 8 3 41 0 1 . 2 3 41 2 1 . 3 0 10 . 9 2 12 . 8 8 34 9 3 . 8 5 34 8 7 . 3 1 34 9 4 . 1 1 62 7 . 1 9 12 3 . 8 9 7. 0 3 127.27 Excellent Buildup Stability 11 . 0 70 0 ‐ 11 . 0 82 8 6 . 0 2 61 5 1 . 7 4 41 2 1 . 3 4 41 3 5 . 7 5 10 . 9 2 12 . 9 3 Good Buildup Stability 11 . 1 70 0 ‐ 11 . 1 82 8 6 . 0 2 61 5 1 . 7 4 41 2 1 . 3 4 41 3 5 . 7 5 10 . 9 2 12 . 9 3 42 2 3 . 6 2 33 1 4 . 5 9 34 9 4 . 1 1 64 1 . 6 4 12 2 . 3 2 9. 6 3 159.69 Good Buildup Stability 11 . 2 70 0 ‐ 11 . 2 82 8 6 . 0 2 61 5 1 . 7 4 41 2 1 . 3 4 41 3 5 . 7 5 10 . 9 2 12 . 9 3 34 9 4 . 1 0 33 5 5 . 7 8 34 9 3 . 9 2 64 1 . 8 3 12 2 . 3 2 10 . 2 3 159.69 Good Buildup Stability 11 . 3 70 0 ‐ 11 . 3 82 8 6 . 0 2 61 5 1 . 7 4 41 2 1 . 3 4 41 3 5 . 7 5 10 . 9 2 12 . 9 3 34 9 3 . 8 0 33 9 2 . 6 6 34 9 3 . 9 6 64 1 . 7 9 12 2 . 3 2 10 . 2 3 158.89 Good Buildup Stability Le g e n d : Ph y d s 1 : In i t i a l Hy d r o s t a t i c Pr e s s u r e Ph y d s 2 : Fi n a l Hy d r o s t a t i c Pr e s s u r e Eq F m M w : E q u i v a l e n t Fo r m a t i o n Mu d We i g h t (P s t o p / (T V D * Co n s t a n t ) ) Eq B h M w : Eq u i v a l e n t Bo r e h o l e Mu d We i g h t (P h y d s 2 / (T V D * Co n s t a n t ) ) Ps d d : In i t i a l Dr a w d o w n Pr e s s u r e Pe d d : Fi n a l Dr a w d o w n or En d Dr a w d o w n Pr e s s u r e Ps t o p : Fi n a l Bu i l d u p Pr e s s u r e Houston Technology Center OD S N ‐29 14 January 2013 Co n f i d e n t i a l Page 10 PR E S S U R E TE S T SU M M A R Y Te s t Id e n t i f i c a t i o n Hy d r o s t a t i c Pr e s . Eq . Mu d Wt . Te s t Pr e s s u r e s ‐ Te m p e r a t u r e s Te s t Times Remarks Te s t No . Fi l e No . MD (f t ) TV D (f t ) Ph y d s 1 (p s i a ) Ph y d s 2 (p s i a ) Eq F m M w (l b s / g a l ) Eq B h M w (l b s / g a l ) Ps d d (p s i a ) Pe d d (p s i a ) Ps t o p (p s i a ) dP o b (p s i a ) Te m p (d e g F ) dT d d (s e c ) dTbu (sec) Te m p : Fi n a l Te m p e r a t u r e dT d d = Te d d ‐Ts d d : Te d d ‐ En d of Dr a w d o w n Ti m e ; Ts d d ‐ In i t i a l Dr a w d o w n Ti m e dT b u = T s t o p ‐ Te d d : B u i l d u p Ti m e , Te d d ‐ En d of Dr a w d o w n Ti m e , Ts t o p ‐ Fi n a l Bu i l d u p Ti m e dP o b = Ph y d s 2 ‐ Ps t o p : Ov e r Ba l a n c e Houston Technology Center OD S N ‐29 14 January 2013 Co n f i d e n t i a l Page 11 PR E S S U R E TR A N S I E N T SU M M A R Y Te s t Id e n t i f i c a t i o n Bu i l d u p St a b i l i t y PT A Pr e s s u r e PT A Mo b i l i t i e s Remarks Te s t No . Fi l e No . MD (f t ) TV D (f t ) Pu m p s (o n / o f f ) Ex p o s u r e (p s i a ) St a b i l i t y (p s i a / m i n ) St a b i l i t y (d e g F / m i n ) Pe x a c t (p s i a ) Ps t d e v (p s i a ) Me x a c t (m d / c p ) Msdd (md/cp) 1. 0 70 0 ‐1. 0 83 2 6 . 5 4 61 7 3 . 7 9 Low Perm, Still Building 2. 0 70 0 ‐2. 0 83 2 4 . 5 3 61 7 2 . 7 1 Low Perm, Still Building 3. 0 70 0 ‐3. 0 83 2 2 . 4 9 61 7 1 . 6 1 Potential Mud Set 4. 0 70 0 ‐4. 0 83 1 7 . 0 3 61 6 8 . 6 8 Potential Mud Set 5. 0 70 0 ‐5. 0 83 1 3 . 0 3 61 6 6 . 5 2 Fair Buildup Stability 5. 1 70 0 ‐5. 1 83 1 3 . 0 3 61 6 6 . 5 2 On 10 3 4 . 9 0 ‐ 0. 2 4 0 71 . 3 7 4 35 0 6 . 4 3 4. 8 4 0. 8 1 7 1.66 Fair Buildup Stability 5. 2 70 0 ‐5. 2 83 1 3 . 0 3 61 6 6 . 5 2 On 10 3 4 . 9 0 1. 0 0 9 71 . 3 7 4 35 0 8 . 1 0 3. 0 4 0. 7 9 7 1.75 Fair Buildup Stability 5. 3 70 0 ‐5. 3 83 1 3 . 0 3 61 6 6 . 5 2 On 10 3 4 . 9 0 5. 8 3 8 71 . 3 7 4 35 0 4 . 7 1 25 . 7 4 0. 6 0 2 1.71 Fair Buildup Stability 6. 0 70 0 ‐6. 0 83 0 8 . 9 8 61 6 4 . 3 2 Good Buildup Stability 6. 1 70 0 ‐6. 1 83 0 8 . 9 8 61 6 4 . 3 2 On 10 6 1 . 6 0 ‐ 0. 3 3 2 71 . 3 6 1 35 0 7 . 0 8 0. 2 8 1. 4 7 1.74 Good Buildup Stability 6. 2 70 0 ‐6. 2 83 0 8 . 9 8 61 6 4 . 3 2 On 10 6 1 . 6 0 0. 1 5 5 71 . 3 6 9 35 0 6 . 7 3 0. 2 4 1. 4 3 1.69 Good Buildup Stability 6. 3 70 0 ‐6. 3 83 0 8 . 9 8 61 6 4 . 3 2 On 10 6 1 . 6 0 ‐ 0. 4 2 3 71 . 3 6 3 35 0 6 . 8 2 0. 2 4 1. 7 1 1.71 Good Buildup Stability 7. 0 70 0 ‐7. 0 82 9 8 . 5 1 61 5 8 . 6 0 Dry/Tight Test 8. 0 70 0 ‐8. 0 82 9 5 . 5 2 61 5 6 . 9 6 Good Buildup Stability 8. 1 70 0 ‐8. 1 82 9 5 . 5 2 61 5 6 . 9 6 On 11 2 7 . 9 7 ‐ 0. 6 4 5 71 . 4 0 8 34 9 4 . 2 0 0. 5 5 9. 2 8 9.28 Good Buildup Stability 8. 2 70 0 ‐8. 2 82 9 5 . 5 2 61 5 6 . 9 6 On 11 2 7 . 9 7 0. 0 8 8 71 . 4 0 7 34 9 4 . 3 4 0. 2 0 8. 4 9 8.49 Good Buildup Stability 8. 3 70 0 ‐8. 3 82 9 5 . 5 2 61 5 6 . 9 6 On 11 2 7 . 9 7 ‐ 0. 5 9 0 71 . 4 0 8 34 9 4 . 1 5 0. 2 8 8. 3 9 8.39 Good Buildup Stability 9. 0 70 0 ‐9. 0 82 9 2 . 0 3 61 5 5 . 0 4 Excellent Buildup Stability 9. 1 70 0 ‐9. 1 82 9 2 . 0 3 61 5 5 . 0 4 On 11 5 5 . 9 4 ‐ 0. 0 2 3 71 . 3 9 8 34 9 4 . 1 9 0. 1 9 10 3 104 Excellent Buildup Stability 9. 2 70 0 ‐9. 2 82 9 2 . 0 3 61 5 5 . 0 4 On 11 5 5 . 9 4 0. 0 8 5 71 . 4 0 2 34 9 4 . 0 7 0. 1 0 32 7 327 Excellent Buildup Stability 9. 3 70 0 ‐9. 3 82 9 2 . 0 3 61 5 5 . 0 4 On 11 5 5 . 9 4 0. 0 0 6 71 . 4 0 6 34 9 3 . 9 8 0. 1 0 36 1 361 Excellent Buildup Stability 10 . 0 70 0 ‐ 10 . 0 82 8 8 . 0 1 61 5 2 . 8 3 Excellent Buildup Stability 10 . 1 70 0 ‐ 10 . 1 82 8 8 . 0 1 61 5 2 . 8 3 On 11 9 4 . 9 1 0. 0 8 5 71 . 4 1 0 34 9 4 . 0 9 0. 1 3 87 5 875 Excellent Buildup Stability 10 . 2 70 0 ‐ 10 . 2 82 8 8 . 0 1 61 5 2 . 8 3 On 11 9 4 . 9 1 0. 0 5 6 71 . 4 1 5 34 9 3 . 8 4 0. 0 7 19 4 0 1940 Excellent Buildup Stability 10 . 3 70 0 ‐ 10 . 3 82 8 8 . 0 1 61 5 2 . 8 3 On 11 9 4 . 9 1 0. 2 0 9 71 . 4 0 4 34 9 4 . 1 1 0. 1 9 12 6 0 1260 Excellent Buildup Stability 11 . 0 70 0 ‐ 11 . 0 82 8 6 . 0 2 61 5 1 . 7 4 Good Buildup Stability Houston Technology Center OD S N ‐29 14 January 2013 Co n f i d e n t i a l Page 12 PR E S S U R E TR A N S I E N T SU M M A R Y Te s t Id e n t i f i c a t i o n Bu i l d u p St a b i l i t y PT A Pr e s s u r e PT A Mo b i l i t i e s Remarks Te s t No . Fi l e No . MD (f t ) TV D (f t ) Pu m p s (o n / o f f ) Ex p o s u r e (p s i a ) St a b i l i t y (p s i a / m i n ) St a b i l i t y (d e g F / m i n ) Pe x a c t (p s i a ) Ps t d e v (p s i a ) Me x a c t (m d / c p ) Msdd (md/cp) 11 . 1 70 0 ‐ 11 . 1 82 8 6 . 0 2 61 5 1 . 7 4 On 12 2 0 . 1 3 0. 0 2 6 71 . 3 2 0 34 9 4 . 1 1 0. 1 3 31 . 9 31.9 Good Buildup Stability 11 . 2 70 0 ‐ 11 . 2 82 8 6 . 0 2 61 5 1 . 7 4 On 12 2 0 . 1 3 0. 0 6 7 71 . 3 0 4 34 9 3 . 9 2 0. 1 3 41 . 5 41.5 Good Buildup Stability 11 . 3 70 0 ‐ 11 . 3 82 8 6 . 0 2 61 5 1 . 7 4 On 12 2 0 . 1 3 0. 0 2 0 71 . 2 9 0 34 9 3 . 9 6 0. 1 1 56 . 6 56.6 Good Buildup Stability Le g e n d : Pe x a c t : Pr o j e c t e d fo r m a t i o n pr e s s u r e ba s e d on ex a c t mo d e l . Ps t d e v : St a n d a r d de v i a t i o n of ac t u a l pr e s s u r e s fr o m ex a c t mo d e l Me x a c t : Sp h e r i c a l Mo b i l i t y ba s e d on ex a c t mo d e l Ms d d : Sp h e r i c a l Dr a w d o w n Mo b i l i t y Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 13 Gradients Gradient 0 Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 14 Gradient Group Gradient (psia/ft) Equivalent Fluid Density lbs/gal g/cc Disclaimer: All equivalent fluid densities are calculated from TVD pressure gradients Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 15 Plots Test No. 1.0; MD: 8326.54 ft; TVD: 6173.79 ft GeoTap Pretest File # 700‐1.0 Date: 03‐Nov‐12 15:50:14 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 8326.54 4156.04 4123.10 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.23 1.00 0.22 0.15 2.36e‐006 42.50 REMARKS Low Perm, Still Building Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 16 Test No. 2.0; MD: 8324.53 ft; TVD: 6172.71 ft GeoTap Pretest File # 700‐2.0 Date: 03‐Nov‐12 16:13:18 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 8324.53 4153.89 4113.55 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 2.00 1.00 0.22 0.15 2.84e‐006 42.50 REMARKS Low Perm, Still Building Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 17 Test No. 3.0; MD: 8322.49 ft; TVD: 6171.61 ft GeoTap Pretest File # 700‐3.0 Date: 03‐Nov‐12 16:40:55 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 8322.49 4152.04 4106.25 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 9.53 0.50 0.22 0.15 1.70e‐003 42.50 REMARKS Potential Mud Set Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 18 Test No. 4.0; MD: 8317.03 ft; TVD: 6168.68 ft GeoTap Pretest File # 700‐4.0 Date: 03‐Nov‐12 17:10:28 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 8317.03 4099.88 4113.56 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 9.53 0.50 0.22 0.15 1.87e‐003 42.50 REMARKS Potential Mud Set Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 19 Test No. 5.0; MD: 8313.03 ft; TVD: 6166.52 ft GeoTap Pretest File # 700‐5.0 Date: 03‐Nov‐12 18:02:49 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 8313.03 4132.35 4113.87 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 2.01 1.00 0.22 0.15 2.95e‐006 42.50 REMARKS Fair Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 20 Test No. 5.1; MD: 8313.03 ft; TVD: 6166.52 ft GeoTap Pretest File # 700‐5.1 Date: 03‐Nov‐12 18:02:49 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 8313.03 6166.52 57.90 3506.43 3506.43 0.817 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 4.01 1.00 0.22 0.15 2.95e‐006 42.50 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 4.84 ‐0.24 71.37 On 1034.90 ‐25.42 REMARKS Fair Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 21 Test No. 5.2; MD: 8313.03 ft; TVD: 6166.52 ft GeoTap Pretest File # 700‐5.2 Date: 03‐Nov‐12 18:02:49 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 8313.03 6166.52 225.69 3508.10 3508.10 0.797 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 4.21 1.00 0.22 0.15 2.59e‐006 42.50 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 3.04 1.01 71.37 On 1034.90 ‐25.42 REMARKS Fair Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 22 Test No. 5.3; MD: 8313.03 ft; TVD: 6166.52 ft GeoTap Pretest File # 700‐5.3 Date: 03‐Nov‐12 18:02:49 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 8313.03 6166.52 154.71 3504.71 3504.71 0.602 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 4.82 1.00 0.22 0.15 4.36e‐006 42.50 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 25.74 5.84 71.37 On 1034.90 ‐25.42 REMARKS Fair Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 23 Test No. 6.0; MD: 8308.98 ft; TVD: 6164.32 ft GeoTap Pretest File # 700‐6.0 Date: 03‐Nov‐12 18:24:39 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 8308.98 4101.50 4109.79 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 2.01 1.00 0.22 0.15 4.97e‐006 42.50 REMARKS Good Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 24 Test No. 6.1; MD: 8308.98 ft; TVD: 6164.32 ft GeoTap Pretest File # 700‐6.1 Date: 03‐Nov‐12 18:24:39 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 8308.98 6164.32 213.44 3507.08 3507.08 1.47 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.81 1.00 0.22 0.15 4.97e‐006 42.50 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.28 ‐0.33 71.36 On 1061.60 ‐28.35 REMARKS Good Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 25 Test No. 6.2; MD: 8308.98 ft; TVD: 6164.32 ft GeoTap Pretest File # 700‐6.2 Date: 03‐Nov‐12 18:24:39 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 8308.98 6164.32 110.68 3506.73 3506.73 1.43 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 2.01 1.00 0.22 0.15 5.86e‐006 42.50 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.24 0.16 71.37 On 1061.60 ‐28.35 REMARKS Good Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 26 Test No. 6.3; MD: 8308.98 ft; TVD: 6164.32 ft GeoTap Pretest File # 700‐6.3 Date: 03‐Nov‐12 18:24:39 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 8308.98 6164.32 157.82 3506.82 3506.82 1.71 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 1.81 1.00 0.22 0.15 5.30e‐006 42.50 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.24 ‐0.42 71.36 On 1061.60 ‐28.35 REMARKS Good Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 27 Test No. 7.0; MD: 8298.51 ft; TVD: 6158.60 ft GeoTap Pretest File # 700‐7.0 Date: 03‐Nov‐12 18:49:27 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 8298.51 4098.44 4113.21 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 2.01 1.00 0.22 0.15 4.49e‐006 42.50 REMARKS Dry/Tight Test Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 28 Test No. 8.0; MD: 8295.52 ft; TVD: 6156.96 ft GeoTap Pretest File # 700‐8.0 Date: 03‐Nov‐12 19:14:58 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 8295.52 4099.35 4110.90 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 11.03 1.00 0.22 0.15 5.86e‐006 42.50 REMARKS Good Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 29 Test No. 8.1; MD: 8295.52 ft; TVD: 6156.96 ft GeoTap Pretest File # 700‐8.1 Date: 03‐Nov‐12 19:14:58 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 8295.52 6156.96 2875.99 3494.20 3494.20 9.28 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 9.83 1.00 0.22 0.15 5.86e‐006 42.50 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.55 ‐0.64 71.41 On 1127.97 ‐31.28 REMARKS Good Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 30 Test No. 8.2; MD: 8295.52 ft; TVD: 6156.96 ft GeoTap Pretest File # 700‐8.2 Date: 03‐Nov‐12 19:14:58 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 8295.52 6156.96 2818.82 3494.34 3494.34 8.49 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.03 1.00 0.22 0.15 1.45e‐005 42.50 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.20 0.09 71.41 On 1127.97 ‐31.28 REMARKS Good Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 31 Test No. 8.3; MD: 8295.52 ft; TVD: 6156.96 ft GeoTap Pretest File # 700‐8.3 Date: 03‐Nov‐12 19:14:58 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 8295.52 6156.96 2810.63 3494.15 3494.15 8.39 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.03 1.00 0.22 0.15 1.92e‐005 42.50 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.28 ‐0.59 71.41 On 1127.97 ‐31.28 REMARKS Good Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 32 Test No. 9.0; MD: 8292.03 ft; TVD: 6155.04 ft GeoTap Pretest File # 700‐9.0 Date: 03‐Nov‐12 19:39:45 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 8292.03 4096.92 4110.70 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.03 1.00 0.22 0.15 7.19e‐006 42.50 REMARKS Excellent Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 33 Test No. 9.1; MD: 8292.03 ft; TVD: 6155.04 ft GeoTap Pretest File # 700‐9.1 Date: 03‐Nov‐12 19:39:45 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 8292.03 6155.04 3439.37 3494.19 3494.19 103 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 9.63 1.00 0.22 0.15 7.19e‐006 42.50 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.19 ‐0.02 71.40 On 1155.94 ‐31.28 REMARKS Excellent Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 34 Test No. 9.2; MD: 8292.03 ft; TVD: 6155.04 ft GeoTap Pretest File # 700‐9.2 Date: 03‐Nov‐12 19:39:45 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 8292.03 6155.04 3476.57 3494.07 3494.07 327 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.03 1.00 0.22 0.15 1.97e‐004 42.50 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.10 0.08 71.40 On 1155.94 ‐31.28 REMARKS Excellent Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 35 Test No. 9.3; MD: 8292.03 ft; TVD: 6155.04 ft GeoTap Pretest File # 700‐9.3 Date: 03‐Nov‐12 19:39:45 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 8292.03 6155.04 3478.10 3493.98 3493.98 361 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.03 1.00 0.22 0.15 4.67e‐004 42.50 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.10 0.01 71.41 On 1155.94 ‐31.28 REMARKS Excellent Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 36 Test No. 10.0; MD: 8288.01 ft; TVD: 6152.83 ft GeoTap Pretest File # 700‐10.0 Date: 03‐Nov‐12 20:08:51 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 8288.01 4101.23 4121.30 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.54 1.50 0.22 0.15 1.90e‐005 42.50 REMARKS Excellent Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 37 Test No. 10.1; MD: 8288.01 ft; TVD: 6152.83 ft GeoTap Pretest File # 700‐10.1 Date: 03‐Nov‐12 20:08:51 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 8288.01 6152.83 3484.27 3494.09 3494.09 875 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 9.94 1.50 0.22 0.15 1.90e‐005 42.50 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.13 0.09 71.41 On 1194.91 ‐31.28 REMARKS Excellent Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 38 Test No. 10.2; MD: 8288.01 ft; TVD: 6152.83 ft GeoTap Pretest File # 700‐10.2 Date: 03‐Nov‐12 20:08:51 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 8288.01 6152.83 3489.43 3493.84 3493.84 1940 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.24 1.50 0.22 0.15 1.72e‐003 42.50 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.07 0.06 71.42 On 1194.91 ‐31.28 REMARKS Excellent Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 39 Test No. 10.3; MD: 8288.01 ft; TVD: 6152.83 ft GeoTap Pretest File # 700‐10.3 Date: 03‐Nov‐12 20:08:51 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 8288.01 6152.83 3487.31 3494.11 3494.11 1260 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.54 1.50 0.22 0.15 1.47e‐003 42.50 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.19 0.21 71.40 On 1194.91 ‐31.28 REMARKS Excellent Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 40 Test No. 11.0; MD: 8286.02 ft; TVD: 6151.74 ft GeoTap Pretest File # 700‐11.0 Date: 03‐Nov‐12 20:33:07 PRESSURE/TIME PLOT SUMMARY Depth Hydrostatic Pretest Pressures Pretest Times Mobility MD (ft) Phyds1 (psia) Phyds2 (psia) Psdd (psia) Pedd (psia) Pstop (psia) Tsdd (sec) Tedd (sec) Tstop (sec) Mdd (md/cp) 8286.02 4121.34 4135.75 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 11.03 1.00 0.22 0.15 6.01e‐006 42.50 REMARKS Good Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 41 Test No. 11.1; MD: 8286.02 ft; TVD: 6151.74 ft GeoTap Pretest File # 700‐11.1 Date: 03‐Nov‐12 20:33:07 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 8286.02 6151.74 3314.59 3494.11 3494.11 31.9 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 9.63 1.00 0.22 0.15 6.01e‐006 42.50 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.13 0.03 71.32 On 1220.13 ‐34.20 REMARKS Good Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 42 Test No. 11.2; MD: 8286.02 ft; TVD: 6151.74 ft GeoTap Pretest File # 700‐11.2 Date: 03‐Nov‐12 20:33:07 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 8286.02 6151.74 3355.78 3493.92 3493.92 41.5 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.23 1.00 0.22 0.15 4.91e‐005 42.50 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.13 0.07 71.30 On 1220.13 ‐34.20 REMARKS Good Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 43 Test No. 11.3; MD: 8286.02 ft; TVD: 6151.74 ft GeoTap Pretest File # 700‐11.3 Date: 03‐Nov‐12 20:33:07 EXACT PRESSURE / TIME PLOT SUMMARY MD (ft) TVD (ft) Pedd (psia)Pstop (psia)Pexact (psia) Mexact(md/cp) 8286.02 6151.74 3392.66 3493.96 3493.96 56.6 CONSTANTS ‐SPHERICAL FLOW Volume (cc) Rate (cc/sec). Rsnorkel (in) Porosity (fraction) Ct (1/psia) Flow‐line Storage (cc) 10.23 1.00 0.22 0.15 9.42e‐005 42.50 TEST CONDITIONS & STATUS +/‐ stdev (psia) Stability (psia/min) Stability (degF/min) Pump Status Exposure Time (min). Tool Face (deg). 0.11 0.02 71.29 On 1220.13 ‐34.20 REMARKS Good Buildup Stability Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 44 Disclaimer DATA, RECOMMENDATIONS, INTERPRETATIONS LIMITATIONS Because of the uncertainty of variable well conditions the necessity of relying on facts and supporting services furnished by others, Halliburton IS UNABLE TO GUARANTEE THE EFFECTIVENESS OF THE PRODUCTS, SUPPLIES OR MATERIALS, NOR THE RESULTS OF ANY TREATMENT OR SERVICE, NOR THE ACCURACY OF ANY CHART INTERPRETATION, RESEARCH ANALYSIS, JOB RECOMMENDATION OR OTHER DATA FURNISHED BY Halliburton. Halliburton personnel will use their best efforts in gathering such information and their best judgment in interpreting it, but Customer agrees that Halliburton shall not be liable for and Customer SHALL RELEASE, DEFEND AND INDEMNIFY Halliburton against any damages or liability arising from the use of such information even if such damages are contributed to or caused by the negligence, fault or strict liability of Halliburton. Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 45 Drawdown Buildup Analysis During the pretest a small amount of fluid is withdrawn from the formation through the snorkel and into the tool at a known rate. This causes the pressure pulse called a pretest drawdown. The combination off low rate and snorkel D determines an effective range of operation. The maximum drawdown pressure pulse can be determined from the well‐known spherical flow equation where Pdd is the final drawdown pressure differential at time t=. fp pdd dd kr q = P 2696,14 Where: Pdd ............................................................................. drawdown differential pressure (psi) qo .............................................................................................. drawdown flow rate (cc/sec) ks ................................................................................ formation spherical permeability(md) ....................................................................................................................... viscosity (cp) rp ................................................................................................................ probe radius(cm) p .................................................................................... probe flow coefficient (1.37to0.95) With a 0.10cc/sec to 1.5cc/sec drawdown flow rate and a 1.0cm probe employed, it is possible to test formations ranging from 1000 to 0.5 md with pressure differentials ranging from 2 to 5000 psi. Exact Mobility Analysis By analyzing the drawdown curve and the build‐up curve it is possible to calculate the mobility of the formation. The mobility is defined as the permeability divided by the viscosity (md/cp). Therefore if the viscosity of the fluid being drawn is known, it is also possible to determine the formation permeability. The fluid being drawn into the pretest is normally assumed to be the mud filtrate so if the mud type is known it is possible to estimate the filtrate viscosity. The two methods of determining the mobility are shown by the two equations below. First is the drawdown mobility Mdd that uses the drawdown pressure differential (i.e.,Pdd=Pstop‐Pdd_end) and is the most common method used in the industry. It is normally referred to as the steady‐state spherical method. The second is the exact spherical mobility Mexact that typically uses the buildup curve. A simplified form of the exact method is shown in Figure‐1 which is an exponential with a magnitude of (pressure, psi) and a time constant of (sec). Both the drawdown and buildup curves can be analyzed but normally the buildup is used. The curve fit parameters alpha and beta are used to determine the mobility. Generally these Mdd and Mexact are very similar except in low mobility zones where the mobility is < 1 md/cp. In this case the Exact method yields the most accurate estimate of Mobility. Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 46 Mdd= p p dd o rP q 2 696,14 Drawdown spherical mobility (md/cp) Mexact= pt p po er q 12 696,14 Exact spherical mobility (md/cp) Where: tp ................................................................. draw down production time(tdd_end-tdd_start ,sec) ...................................................................................... Exact curve fit time constant (sec) ................................................................................ Exact curve fit build up constant (psi) Pr e s s u r e ( p s i ) Time (sec)tstop Q tdd_end tdd TPdd_end t = T – tdd_end tdd_start t fbu eP(t)P * Pdd_start Pdd=Pstop-Pdd_end Pstop Phyds Fig–1 Buildup function where formation pressure (Pf*), Alpha ( ) and beta () are determined from the Exact curve fit and Pf* is normally reported a PExaxt. Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 47 Test Quality Parameters There are two different measurements of test quality. The first is called the sigma which is a measure of how closely the data conforms to the Exact model and is reported in ± pressure units (normally psi). The sigma is determined by calculating the standard deviation of the data from the theoretical curve as follows. )1( )()(p)( 2 n iPi=P bu bu ........... standard deviation ± pressure units (normally psi) Where: Pbu ........................................................... buildup pressure from Exact curve fit (see Fig. 1) p(i) ............................................................................................. measured buildup pressures i ............................................................................................................... index of data point n .................................................................................. total number of pressure points used The second method of measuring the test quality is the pressure and temperature stability. The “Pressure Stability” and “Temperature Stability are determined using a linear regression over the time period specified (i.e., default of 30 sec) and reported for each selected stop pressure. The stability can be either positive or negative. The stability period can be modified if desired in RTS. The source data for this derivative is the pressure gauge selected by the engineer for formation pressure which is normally the Quartz gauge closest to the probe. There are some exceptions to the stability period during buildups which are outlined below. 1. Start of buildup continue stability calculation until the buildup time reaches the stability period (i.e., 30 default). 2. Reset stability period to 1/3 of the buildup time (10 seconds default). 3. As the buildup progresses increase the stability period using 1/3 of the buildup time until the specified stability time is reached (30 sec default). Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 48 Automatic Test Comments Automatic test comments are generated based on the sigma quality parameter and the logic below. Test are classified by types and are normally Type A, B, C, and D. Any test that is not Type A, B, C or D is type F. The logic below determines the test type automatically but as explained below the RTS analysis can always override these comments and classify the tests as he sees fit. If Abs(Pstop - Phyd2) < 50 psi, “Potential Mud set” If Pstop < 1000 psi and alpha > 30 sec, “Dry/Tight test” If sigma <= 0.1: “Excellent Buildup Stability” (Type A) elseif sigma <= 1.0: “Good Buildup Stability” (Type B) elseif sigma <= 10.0: “Fair Buildup Stability” (Type C) else: if beta > 500 and alpha > 30: “Low Perm, still building” else: “Unstable Buildup (Type D)” The RTS analysts can override these comments based on his discretion, but if the key words Excellent, Good, Fair or Unstable are used the test comments the type associated with these key words used to apply the test type. The color coding to the test types are as follows. Type A Green Type B Orange Type C Pink Type D Red Type F Black Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 49 Dual Probe Anisotropy Analysis (Vertical Interference Testing) When one of the probes is isolated it may be possible to determine the horizontal permeability and anisotropy from the isolated (observation) probe that is spaced at a vertical distance from the source probe (lv) Mh_exact= v pt v vo v el Q 12 1696,14 Exact Horizontal Mobility (md/cp) 3 _ _ exacth exacts exacth v exact M M k k Exact anisotropy Anisotropy Dip-angle Corrections The calculation for anisotropy assumes the bedding plane is oriented relative to the borehole. The correction chart shown below can be used to find the anisotropy when the relative dip angle is known. Entering the chart from the left hand side with the real‐time anisotropy and following one of the lines to the right determines the correction with increasing dip‐angle. For example, using a real‐time anisotropy of 10 and with a dip‐angle of 700 the corrected anisotropy is slightly less than 0.1. This would be the case of a nearly horizontal well. Notice that as the dip‐angle approaches 450 the lines converge. This means that measurements taken close to a 450 dip‐angle are not very sensitive to anisotropy. 0.00001 0.0001 0.001 0.01 0.1 1 10 100 1000 0 1 02 03 04 05 06 07 08 09 0 Dip Angle (deg) An i s o t r o p y ( k v / k h ) 300 100 30 10 1 0.1 0.01 0.001 0.0001 0.00001 Real-Time Anisotropy Fig. 2 Anisotropy Dip‐angle Correction Chart. Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 50 Flow Rate Determination There are three methods of determining the drawdown (and pumping) flow rates which can be selected in the Job Parameters. In the newer tools the flow rate is measured and the “Automatic Method” is the preferred default. In older tools the flow rate or test volume can be specified but the values must be entered manually. With any of these three options it is rare that the volumes and rates exactly match that specified by the engineer since there is variability in the actual execution of a pretest and the rates and volume in RTS are determined from actual events and measured data. Automatic Flow Rate Option The automatic flow rate option determines rate from the measured rate curve(s) directly. For pretesting the averaged rage between the selected starting and ending times of the drawdown is used (i.e., Tstard_dd and Tend_dd). It is possible to select a Tend_dd that may not fall within the drawdown period and still estimate the mobility using the averaged rate for the drawdown period chosen. When this happens the simulated drawdown curve is turned off. For both pumping and pretesting the rate should be determined from the active rate curves. Since some tools like the RDT can have more than one pretest module or pump the total average from all the rate curves are used to for the “Automatic Rate” calculation. Then the volume for the drawdown is determined by using this averaged rate times the drawdown time (i.e., AvgRate/(Tend_dd‐Tstart_dd)). However, the time used to average should not exceed 30 minutes which would apply to pumpouts or miniDST testing and it is desirable to determine the rate just prior to the buildup. In this case the averaged rate would be from Tdd‐30 minutes to Tdd. Also, rates less than 0.02 cc/sec from Meas PT Rate are filtered out (set to 0 values) and rates less than 0.1 cc/sec for Pump Rates are set to 0 before averaging. Manual Flow Rate Option With this option selection in the Job Parameters the rate is fixed to the value entered. The volume of the pretest is determined by multiplying this rate time the drawdown time period selected (i.e., Tstard_dd and Tend_dd). Manual Volume Option With this option selection in the Job Parameters the volume is fixed to the value entered. The rate of the pretest is determined by dividing this volume by the drawdown time period selected (i.e., Tstard_dd and Tend_dd). Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 51 RTS Mobility Drawdown and Buildup Calculation Summary Table 1 PTA Spherical Flow Regime Calculations (Typical Physical Units) Mdd= p p dd o rP q 2 696,14 ........................................ Drawdown Mobility, Pressure/Time Plot (md/cp) Ms_exact= pt p po er Q 12 696,14 ........................... Exact Mobility, Pressure/Time Plot (md/cp) Mloglog= 5.1 1 5.2 5.1 4 696,14 dt dpt cV fo ....................................... FasTest Mobility, Log-Log Plot (md/cp) Mfast= 5.1 1 5.1 4 696,14 fast fo m cV ............................................. FasTest Mobility, FasTest Plot (md/cp) Msphere= 5.1 1 4 696,14 sphere fo m cq .................................................. Spherical Mobility, FastPlot (md/cp) Table 2 PTA Radial Flow Regime Calculations (Typical Physical Units) Mdd= p wf o dd dd o t rc q hPLambertWhP q 2 4 696,14 ...................... Drawdown Mobility (md/cp) Mloglog= dt dpth V eLog o 2)(4 696,14 ................................................ FasTest Mobility, Log-Log Plot (md) Mfast= fast o mh V eLog)(4 696,14 .......................................................... FasTest Mobility, FasTest Plot (md) Mradial= radial o mh q eLog)(4 696,14 ................................................................ Radial Mobility, FastPlot (md) Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 52 Table 3 PTA Variables & Constants Using Internal Program (Typical Physical Units) qo ................................................................................................................. drawdown flow rate (cc/sec) Vo ........................................................................................................................... drawdown volume(cc) Vs ................................................................................................................................ storage volume(cc) ................................................................................................................................................... porosity ........................................................................................................................................... viscosity(cp) cf ..................................................................................................................... fluid compressibility(1/psi) Pdd .................................................................................................. drawdown differential pressure(psi) p ........................................................................................................ prove flow coefficient (1.37to0.95) rp .................................................................................................................................... probe radius(cm) rw .............................................................................................................................. wellbore radius(cm) h ..................................................................................................................................... zone height (cm) T .............................................................................................................................. actual testtime(T,sec) t ..................................................................................................... shut in or buildup time ((tdd_end-T,sec) t’ ......................................................................................... production or drawdown time (tdd_start-T,sec) tp ..................................................................... production or drawdown time period (tdd_end-tdd_start,sec) dp/dt ................................................................................. Log-Log Plot buildup time derivative(psi/sec) mfast .............................................................................................................................. FasTest Plot slope msphere ........................................................................................................................ Spherical Plot slope mradial ............................................................................................................................. Radial Plot slope ................................................................................................................ Exact Plot time constant (sec) .................................................................................................................. Exact curve fit constant (psi) ............................................................................................................................ Eulier’sconstant (1.78) Log(e) ........................................................................................ logbase10conversionconstant (0.43429) Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 53 Table 4 PTA Spherical Flow Regime Calculations (SI Units) Mdd= p p dd o rP q 2 1013 ........................................... Drawdown Mobility, Pressure/Time Plot (md/cp) Ms_exact= pt p po er Q 12 1013 .............................. Exact Mobility, Pressure/Time Plot (md/cp) Mloglog= 5.1 1 5.2 5.1 4 1013 dt dpt cV fo ........................................... FasTest Mobility, Log-Log Plot (md/cp) Mfast= 5.1 1 5.1 4 1013 fast fo m cV ................................................. FasTest Mobility ,FasTest Plot (md/cp) Msphere= 5.1 1 4 1013 sphere fo m cq ...................................................... Spherical Mobility, FastPlot (md/cp) Table 5 PTA Radial Flow Regime Calculations (SI Units) Mdd= p wf o dd dd o t rc q hPLambertWhP q 2 4 1013 ......................... Draw down Mobility (md/cp) Mloglog= dt dpth Vo 24 1013 .......................................................... FasTest Mobility, Log-Log Plot (md) Mfast= fast o mh V 4 1013 ................................................................... FasTest Mobility, FasTest Plot (md) Mradial= radial o mh q eLog)(4 1013 ........................................................... Radial Mobility, FastPlot (md) Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 54 Table 6 PTA Variables & Constants Using Internal Program SI Units qo ................................................................................................................. drawdown flow rate(m2/sec) Vo .......................................................................................................................... drawdown volume(m2) Vs ............................................................................................................................... storage volume(m2) ................................................................................................................................................... porosity ................................................................................................................................. viscosity (cp, Pa-s) cf ..................................................................................................................... fluid compressibility(1/Pa) Pdd .................................................................................................. drawdown differential pressure(Pa) p ........................................................................................................ prove flow coefficient (1.37to0.95) rp ...................................................................................................................................... probe radius(m) rw ................................................................................................................................ wellbore radius(m) h ....................................................................................................................................... zone height (m) T ............................................................................................................................ actual test time (T,sec) t ....................................................................................................... shutin or buildup time((tdd_end-T,sec) t’ .......................................................................................... production or drawdown time(tdd_start-T,sec) tp ...................................................................... production or drawdown time period(tdd_end-tdd_start,sec) dp/dt ................................................................................. Log-Log Plot buildup time derivative(Pa/sec) mfast .............................................................................................................................. FasTest Plot slope msphere ........................................................................................................................ Spherical Plot slope mradial ............................................................................................................................. Radial Plot slope ................................................................................................................ Exact Plot time constant (sec) .................................................................................................................. Exact curve fit constant (Pa) ........................................................................................................................... Eulier’s constant (1.78) Log(e) ..................................................................................... logbase 10 conversion constant (0.43429) Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 55 RTS Theory References An Integrated Approach to Reservoir Connectivity and Fluid Contact Estimates by Applying Statistical Analysis Methods to Pressure Gradients, SPWLA 2007_HH paper presented at the 48th Annual Logging Symposium, June 3 - 6, 2007 , Austin, Texas. Formation Pressure Testing in the Dynamic Drilling Environment, SPE 112816 presentation was an SPE Distinguished Lecture during 2006-2007. Formation Testing and Sampling Using an Oval Pad in Al Hamd Field, Egypt, SPE 102366 presented at the SPE Annual Technical Conference and Exhibition, 24-27 September 2006, San Antonio, Texas, USA. Formation Tester While Drilling Experience in Caspian Development Projects, SPE 96719 paper presented at the SPE Annual Technical Conference and Exhibition, 9-12 October 2005, Dallas, Texas. Experience Using the First Commercial Pad and Probe Style Formation Tester While Drilling Service Has Led To Value Creation at the Valhall Flank Development, SPE 92712 paper presented at the SPE/IADC Drilling Conference, 23-25 February 2005, Amsterdam, Netherlands The Influence of Water-Base Mud Properties and Petrophysical Parameters on Mudcake Growth, Filtrate Invasion, and Formation Pressure, Petrophysics Volume 46, Number 1, January - February, 2005. Formation Tester Immiscible and Miscible Flow Modeling for Job Planning Applications, SPWLA 2005-L paper presented at the SPWLA 46th Annual Logging Symposium, 2005 Results of Laboratory Experiments to Simulate the Downhole Environment of Formation Testing While Drilling. SPWLA 2005R paper was presented at the SPWLA 45th Annual Logging Symposium held in Noordwijk, The Netherlands, June 6–9, 2004. Formation Testing In The Dynamic Drilling Environment, SPWLA 2005N paper was presented at the SPWLA 45th Annual Logging Symposium held in Noordwijk, The Netherlands, June 6–9, 2004. Formation Pressure Testing In the Dynamic Drilling Environment. SPE 87090 was presentated at the IADC/SPE Drilling Conference held in Dallas, Texas, U.S.A., 2–4 March 2004. Formation Testing While Drilling, a New Era in Formation Testing. SPE 84087 was presentated at the 2003 SPE Annual Technical Conference and Exhibition held in Denver, Colorado, USA, 5-8 October 2003. Formation Testing While Drilling, a New Technique for Acquiring Pressure Data, Paper presented at the SPE Nigerian Annual International Conference and Exhibition 4-8 August 2003. A New Inversion Technique Determines In-Situ Relative Permeabilities And Capillary Pressure Parameters From Pumpout Wireline Formation Tester Data, Spwla Forty-Fourth Annual Logging Symposium, Galveston, Texas, June 22-25, 2003. Performance Optimization of Perforated Completions Using a New 3D Finite-Element Wellbore Inflow Model and Artificial Neural Network, ExiPet Petroleum Congress, held in Veracruz, Mexico, February 16 - 18, 2003. Well Test Analysis Review, and Future Development, ExiPet Petroleum Congress, held in Veracruz, Mexico, February 16 - 18, 2003. Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 56 Sample Quality Prediction with Integrated Oil and Water-based Mud Invasion Modeling, SPE paper 77964 presented at the SPE Asia Pacific Oil and Gas Conference and Exhibition held in Melbourne, Australia, 8–10 October 2002. Inversion of Multi-Phase Petrophysical Properties Using Pumpout Sampling Data Acquired with a Wireline Formation Tester, SPE paper 77345 presented at the SPE Annual Technical Conference and Exhibition held in San Antonio, Texas, 29 September–2 October 2002. Multiple Factors that Influence Wireline Formation Tester Pressure Measurements and Fluid Contact Estimates, SPE paper 71566 presented at the 2001 SPE Annual Technical Conference and Exhibition held in New Orleans, Louisiana, 30 September–3 October 2001. New Wireline Formation Testing Tool with Advanced Sampling Technology, SPE paper 71317, SPE Reservoir Evaluation and Engineering Journal, April 2001. Testing of Gas Condensate Reservoirs — Sampling, Test Design and Analysis, SPE paper 68668 presented at the SPE Asia Pacific Oil and Gas Conference and Exhibition held in Jakarta, Indonesia, 17–19 April 2001. Advanced Dual Probe Formation Tester with Transient, Harmonic, and Pulsed Time-Delay Testing Methods Determines Permeability, Skin, and Anisotropy, SPE paper 64650 presented at the SPE International Oil and Gas Conference and Exhibition in China held in Beijing, China, 7–10 November 2000 Advanced Permeability and Anisotropy Measurements While Testing and Sampling in Real-time Using a Dual Probe Formation Tester, SPE paper 62919 presented at the 2000 SPE Annual Technical Conference and Exhibition held in Dallas, Texas, 1–4 October 2000. New Dual-Probe Wireline Formation Testing and Sampling Tool Enables Real-Time Permeability and Anisotropy Measurements, SPE paper 59701 presented at the SPE Permian Basin Oil and Gas Recovery Conference held in Midland, Texas, 21–23 March 2000. New Wireline Formation Testing Tool with Advanced Sampling Technology, SPE paper 56711 presented at the 1999 SPE Annual Technical Conference and Exhibition, Houston, Texas, 3–6 October 1999 Exact Spherical Flow Solution with Storage for Early-Time Test Interpretation, SPE Journal of Petroleum Technology, Nov. 1998 New Exact Spherical Flow Solution with Storage and Skin for Early-Time Interpretation, with Applications to Wireline Formation and Early-Evaluation Drillstem Testing, SPE Paper No. 49140, 1998 SPE Annual Technical Conference and Exhibition, New Orleans, La., Sept. 1998 New Exact Spherical Flow Solution for Early-Time Well Test Interpretation with Applications to Wireline Formation Testing and Early-Evaluation Drillstem Testing, SPE Paper No. 39915, SPE Rocky Mountain Regional Meeting/Low Permeability Reservoirs Symposium, Denver, Co., April 1998 New Exact Spherical Flow Solution for Early-Time Well Test Interpretation with Applications to Wireline Formation Testing and Early-Evaluation Drillstem Testing, SPE Paper No. 39768, SPE Permian Basin Oil and Gas Recovery Conference, Midland, Texas, March 1998 Pressure Test Validity Shown by Comparing Field Tests and Simulations, Part II: Formation Pressure Test Tools, Oil & Gas Journal, Jan. 12, 1998 Houston Technology Center ODSN‐29 14 January 2013 Confidential Page 57 Testing System Combines Advantages of Wireline and Drillstem Testers, Part I: Formation Pressure Test Tools, Oil & Gas Journal, Jan. 5, 1998 Low Permeability Interpretation Using a New Wireline Formation Tester ‘Tight Zone’ Pressure Transient Analysis, SPWLA 94 III Paper, presented at the 35th Annual Symposium in Tulsa, Oklahoma, June (1994). Real Time Pressure Transient Analysis Methods Applied to Wireline Formation Test Data, SPE paper 28449, presented at the 69th Annual Technical Conference of SPE in New Orleans, La., Sep. 25-28, 1994. Interpretation of Wireline Formation Tester Pressure Response, Mud Super-charging and Mud Invasion Effects, SPWLA 92 HH Paper, presented at the 33rd Annual Symposium in Oklahoma City, Oklahoma, June (1992). Improved Models for Interpreting the Pressure Response of Formation Testers, SPE paper 22754, presented at the 66th SPE Annual Technical Conference and Exhibition, Dallas, Texas, October 1991
