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211-140
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, May 23, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Eni US Operating Co. Inc. OI20-07 NIKAITCHUQ OI20-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/23/2023 OI20-07 50-029-23459-00-00 211-140-0 W SPT 3345 2111400 1500 5 5 5 5 134 266 210 205 INITAL P Guy Cook 4/25/2023 Post rig workover MIT-IA. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:NIKAITCHUQ OI20-07 Inspection Date: Tubing OA Packer Depth 430 1660 1645 1640IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230425060001 BBL Pumped:3.6 BBL Returned:3.6 Tuesday, May 23, 2023 Page 1 of 1 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: _Packer Changeout__ 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 18,952 feet N/A feet true vertical 3,143 feet N/A feet Effective Depth measured 17,164 feet 11,500 feet true vertical 3,339 feet 3,348 feet Perforation depth Measured depth 11,830'-19,952' feet True Vertical depth 3,373'-3,143' feet Tubing (size, grade, measured and true vertical depth)4.5 L-80 11,480' 3347' Packers and SSSV (type, measured and true vertical depth)SLB/HES TRMAXX/PHL 2,319'/11,500' 1,947'/3,348' 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:Schrader Bluff 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 Giorgio Iannucci 4/25/2023 Digital Signature with Date:Contact Name:Amjad Chaudhry Contact Email:amjad.chaudhry@eni.com Authorized Title:Well Operations Project Manager Contact Phone:907-865-3379 4790 160 9.625" Liner 11797 5563 Casing Structural 6890 4-1/2" 11830 11,601'-17,164'3,355'-3,339' 2759 2160 20" 13.375" Size 5210 6890 measured TVD Production Plugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 211-140 50-029-23459-00-00 3700 Centerpoint Dr. Ste 500, Anchorage, AK, 99503 3. Address: OI20-07 MD Burst Collapse measured true vertical Packer N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 355024, 373301, 391283,388577 Nikaitchuq/Schrader Bluff Oil Pool Eni US Operating Co. Inc. Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure N/A 4014245 N/A Length 160 2577 160Conductor Surface Intermediate 2480 323-114 Sr Pet Eng: Blank liner w/ICD's Sr Pet Geo:Sr Res Eng: WINJ WAG N/A Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf 504 52N/A 0 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A 580 Blank liner w/ICD's p k ft t Fra O s 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 Iannucci 4/25 By Kayla Junke at 11:02 am, Apr 25, 2023 DSR-4/26/23 RBDMS JSB 050223 13-3/8" 68 ppf, Surf. Casing, 2,759' MD, 2,160' TVD67º Inc9-5/8" 40 ppf, H563,Intermediate Casing, 11,830' MD, 3,373' TVD, 85º Inc4-½”,12.6 ppf, H563, XT15 CoatedProduction Tubing4-½” 11.6 ppf, H521Production Liner, 17,164' MD, 3,339' TVD91º IncZonal Isolation PackersInjection Control DevicesPHL Retr. Packer, 11,500' MD, 3,348' TVD, 85º IncConfidential FM 04/19/23Nikaitchuq Field – Oliktok Point PadAs run04/13/20232,319' MD / 1,947' TVD TRMaxx Safety Valve: 3.812 X Profile11,537' MD / 3,351' TVD HAL Mirage Plug with Auto-fill valveOI20-07 Injector Monobore with Injection Control11,593' MD / 3,355' TVD Bottom of Mule Shoe11523' MD / 3350' TVD 3.81" XN (No-go 2.725")11,601' MD, 3,355' TVD – Top of SLZXP Liner Hanger/Packer 4-½” Ecc-Nose Guide ShoeItemMD (ft)4-1/2" Swell Pkr #1171554-1/2" Swell Pkr #2171024-1/2" Swell Pkr #3162774-1/2" Swell Pkr #4152884-1/2" Swell Pkr #5143394-1/2" Swell Pkr #613340ItemMD (ft)ItemMD (ft)ICD #116836ICD #714033ICD #216532ICD #813679ICD #315971ICD #912961ICD #415626ICD #1012580ICD #514985ICD #1112197ICD #61463811436' MD / 3342' TVD 4-½” Solid Gauge Mandrel Well Name: OI20-07 OR Wellbore Name: OI20-07 Well Code: 26484 Job: WORKOVER WCEI: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 3/30/2023 Report #: 1 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 0.00 Ground Level (ft) 12.20 First Flange (ft) 15.85 RKB - Base Flange (ft) -15.85 RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) 3.2 Wind E @ 22 MPH Days LTI (days) 2,031.00 Days RI (days) POB 37.0 Daily Summary Operations 24h Forecast Finish berm and fill pits with 8.6 ppg brine. Rig up to bull head tubing. Bull head tubing. Monitor tubing for 1 hour. Set BPV and nipple down tree. Nipple up BOPE and test. 24h Summary Move rig from OP03 to OI20. Level and center over well. Set in cuttings box and berm all areas for spill containment. Operation at 07.00 Well kill operations. 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 PROD- MAN M 1 P Set mats for rig move. Complete pre-move checklist. Load hot water to rig. Function test and inspect walking system. House keeping. 06:00 07:30 1.50 7.50 W.O. M 2 P PJSM. Jack up and move rig from well bay. Vault performed pre-workover pressure testing. 07:30 12:00 4.50 12.00 W.O. M 2 P Turn stompers 90 degrees to walk side ways towards OI20 and walk down 95'. 12:00 15:30 3.50 15.50 W.O. M 2 P Crew change PJSM. Review procedure and perform pre-move checklist. Move rig side ways 73' towards OI20. 15:30 17:30 2.00 17.50 W.O. M 2 P Rotate walker feet to move rig towards well center and make final adjustments. Remove well bay hatch. Check rig for level at rotary table. Rig up plumb bob to center over well OI20-07. 17:30 21:30 4.00 21.50 W.O. M 1 P Move and store mat boards. Clean up herculite and dunnage. Scope BOP enclosure down to seal well bay and weatherize. Lay out herculite for cuttings box, set mat and berm. 21:30 00:00 2.50 24.00 W.O. M 1 P Clear out rear yard to accommodate bed truck for setting cuttings box. Stage miscellaneous pipe and equipment to ODS. Continue to berm in areas. Spot cuttings box with bed truck. Lower cuttings chute into box. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 11,601.0 17,164.0 3,341.5 7/26/2012 Well Name: OI20-07 OR Wellbore Name: OI20-07 Well Code: 26484 Job: WORKOVER WCEI: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 3/31/2023 Report #: 2 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 0.00 Ground Level (ft) 12.20 First Flange (ft) 15.85 RKB - Base Flange (ft) -15.85 RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -6.3 Wind SW @ 12 MPH Days LTI (days) 2,032.00 Days RI (days) POB 37.0 Daily Summary Operations 24h Forecast Nipple up BOPE and test with 4" and 4.5" test joints. Make up landing joint to tubing hanger and pull loose. Rig up Halliburton E-line equipment and prepare to perform work with Welltec services. 24h Summary Completed rig set up and running on Hi-line power. Bull head tubing and monitor pressures. Set BPV and nipple down tree. Vault clean and inspect multibowl and tubing hanger area. 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 02:00 2.00 2.00 PROD- MAN M 1 P Pull Hi-line cable and spot Hi-line building. ENI electrician hooked up cable and energized breaker. 02:00 05:30 3.50 5.50 PROD- MAN M 2 P Pull out cuttings box and replace torn spill containment. Reset cuttings box and berm in. 05:30 06:00 0.50 6.00 PROD- MAN M 1 P PJSM with operations and open unit work permit to work in well bay. 06:00 07:30 1.50 7.50 PROD- MAN M 5 P Rig up bull head line to tubing. PJSM with Worley and MI engineer on bull heading tubing. 07:30 08:00 0.50 8.00 PROD- MAN M 1 P Swap rig to Hi-line power. 08:00 10:30 2.50 10.50 PROD- MAN M 9 P Bull head tubing with 250 bbls of 8.6 ppg brine at 2.6 bpm, 350 psi. Monitored A Annulus and B Annulus throughout job. 10:30 12:00 1.50 12.00 PROD- MAN M 11 P Monitor well, Initial; Tbg-60 psi, A Annulus-0, B Annulus-120 psi. 12:00 reading; Tbg-15, A Annulus-0, B Annulus-120. 12:00 14:00 2.00 14.00 W.O. M 11 P Monitor well, at 14:00: Tbg-3.9 psi, A Annulus-0, B Annulus-120 psi. 14:00 16:30 2.50 16.50 W.O. M 11 P Monitor well shut in for 30 min. Tbg-8.5, A Annulus-0, B Annulus-120. Consult with town. Rig hand install new man rider cable through crown sheaves. Monitor well at 16:30; Tbg-9.4, A Annulus-25, B Annulus-120. 16:30 18:00 1.50 18.00 W.O. M 11 P Monitor well shut in for 30 min. Tbg-8.7, A Annulus-50, B Annulus-120. At 18:00; Tbg-8, A Annulus-50, B Annulus-120. 18:00 20:00 2.00 20.00 W.O. M 5 P PJSM Rig up bleed hose to A Annulus and bleed pressure to 0 psi. Shut in Annulus and rig up bleed hose to tubing. Bleed down tubing to 2.8 psi and shut in tubing. At 19:30; Tbg-3.4, A Annulus-0, B Annulus 120. At 20:00; Tbg-2.9 psi. 20:00 22:00 2.00 22.00 W.O. M 1 P Bleed tubing to 0 psi and monitor for 1 hour. No flow. 22:00 00:00 2.00 24.00 W.O. M 1 P PJSM with Vault and Operations. Open well bay permit. Set BPV and nipple down tree. Vault clean and inspect multibowl and tubing hanger area. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 11,601.0 17,164.0 3,341.5 7/26/2012 Well Name: OI20-07 OR Wellbore Name: OI20-07 Well Code: 26484 Job: WORKOVER WCEI: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 4/1/2023 Report #: 3 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 0.00 Ground Level (ft) 12.20 First Flange (ft) 15.85 RKB - Base Flange (ft) -15.85 RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -6.3 Wind S @ 7 MPH Days LTI (days) 2,033.00 Days RI (days) POB 37.0 Daily Summary Operations 24h Forecast Rig up Halliburton and Welltec equipment and perform operations as per well plan. When E-line is complete, rig down and release. Prep for decompletion and pull tubing string. 24h Summary Nipple up BOPE equipment and test with 4" and 4-1/2" test joints. Witness waived by Bob Noble. Make up landing joint to tubing hanger and pull free at 248k. Set slips with 85k, neutral weight. Prep for wire line operations. Operation at 07.00 Prep to run in hole with Halliburton E-line. 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. M 1 P PJSM for nippling up BOPE. Install floor plates. Nipple up single gate and tie into double gate and annular with bridge crane. Fill out fluid transfer and offload brine from pits to Worley truck to jack up rig for nippling up BOPE. 02:30 07:30 5.00 7.50 W.O. C 5 P PJSM. Jack up rig and install double gate and annular. Lower rig. Make up kill/choke valves and hoses. Connect koomey hoses and center up stack. Install flow box riser. Clean BOP enclosure. Grease choke manifold. 07:30 13:30 6.00 13.50 W.O. C 12 P Pick up test joint and function test BOP's (good test). Perform shell test (good test). Rig up 4-1/2" test joint and testing equipment. Flood stack and all lines. Test BOPE as per AOGCC specs to 250/3500 psi with 4" and 4-1/2" test joints. Witness waived by Bob Noble. 13:30 21:00 7.50 21.00 W.O. C 12 P When changing test joint to 4", attempted to pressure up and collar was leaking. Rig test joint down and made up 4" drill pipe to complete testing (good test). Gas alarms and PVT totalizers were tested (good test). 21:00 21:30 0.50 21.50 W.O. C 5 P Vault pulled blanking plug, then BPV. 21:30 23:00 1.50 23.00 W.O. M 5 P PJSM. Make up 4-1/2" W563 landing joint to tubing hanger. Make up top drive to landing joint and back out lock down screws. Work tubing hanger via pulling and slacking off. Hanger pulled free at 248k. 23:00 23:30 0.50 23.50 W.O. M 5 P Lay down W563 landing joint and pick up 4-1/2" IBT landing joint. Make up to tubing hanger and pull up and set slips with 85k as per K&M neutral calculations. 23:30 00:00 0.50 24.00 W.O. R 5 P PJSM. Stab on E-Line FOSV to landing joint. Mobilize Halliburton E-line equipment to rig floor. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. OPPdiilling@eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 11,601.0 17,164.0 3,341.5 7/26/2012 Well Name: OI20-07 OR Wellbore Name: OI20-07 Well Code: 26484 Job: WORKOVER WCEI: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 4/2/2023 Report #: 4 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 0.00 Ground Level (ft) 12.20 First Flange (ft) 15.85 RKB - Base Flange (ft) -15.85 RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) 1.0 Wind E @ 22 MPH Days LTI (days) 2,034.00 Days RI (days) POB 42.0 Daily Summary Operations 24h Forecast Make up BHA #2 with tubing cutter/CCL. Make correlation logs. Set cutter at specified depth and cut tubing. Pull out of hole and rig down Halliburton and Welltec tools and equipment. Pull up on tubing string to confirm good cut. Bull head A Annulus. 24h Summary Rig up Halliburton E-line with Welltec BHA #1 with 2.85" centralizer, gamma perforating small tool and 2.5" tractor. Run in hole and tractor from 3160' to 11,491'. Perform correlation pass. Pull out of hole and lay down and service Welltec tools. Operation at 07.00 Logging with Halliburton BHA #2 tubing cutter and CCL. 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 5 P PJSM. Rig up Halliburton E-line and pressure control equipment. Function test wireline valves (good test). Pressure test lubricator to 350 PSI low and 1000 PSI high for 5 minutes, good test. 05:00 09:00 4.00 9.00 W.O. R 5 P E-line Run #1, make up 2.85" centralizer, gamma perforating small tool, Welltec 2.5" tractor, CCL. Function test Welltec tractor (good test). 09:00 21:00 12.00 21.00 W.O. R 15 P Run in hole with 2.85" centralizer to 3,160' before deviating out. Engage Welltec tractor and tractor in hole from 3,160' to 11,491' XN-nipple at 30 FPM. Perform correlation pass. Pull out of hole with 2.85" centralizer. Centralizer hanging up at 9,556.7', bottom of upper tubing patch. Attempt to work through without success. Engage rig pump at 1 BPM with 62 PSI and stage up to 2 BPM with 150 PSI, pumped 62 BBLs of 8.6 PPG Brine total. Once stabilizer pulled up against bottom of tubing patch pressure increase to 200 PSI. Slack off and re-attempt without pumps and was able to get inside to tubing patch, Max 3,277# line tension pulled, 1,073# normal line tension. Pull out of hole with E-Line. 21:00 00:00 3.00 24.00 W.O. R 5 P PJSM with E-line and Welltec. Rig down packoff assembly and lay down Welltec BHA #1. Service Welltec tools. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. OPPdiilling@eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 11,601.0 17,164.0 3,341.5 7/26/2012 Well Name: OI20-07 OR Wellbore Name: OI20-07 Well Code: 26484 Job: WORKOVER WCEI: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 4/3/2023 Report #: 5 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 0.00 Ground Level (ft) 12.20 First Flange (ft) 15.85 RKB - Base Flange (ft) -15.85 RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) 1.6 Wind SW @ 16 MPH Days LTI (days) 2,035.00 Days RI (days) POB 42.0 Daily Summary Operations 24h Forecast Complete bull heading A Annulus with 840 bbls of 8.6 ppg brine. Monitor well for 1 hour. Pull tubing string laying it down in pipe shed. 24h Summary Make up BHA #2 with Welltec cutter and run in hole on E-line. Perform correlation logs. Welltec cut 4.5" tubing at 11,446.28'. Pull out of hole and lay tools down on rig floor. Pick up tubing 4' to ensure cut. Lay down all Halliburton tools. Pull tubing hanger to floor and lay down. Secure well and start bull heading operations down A Annulus. Operation at 07.00 Well kill 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. R 5 P PJSM. Make up E-line BHA #2 with Welltec 212 tractor, 238 mechanical cutter, CCL, and wireline release device. Max OD 2.5", 490.57#, 42.98' total length. Function test tractor and cutter (good test). Pressure test quick test sub to 1500 PSI, good test. 02:00 15:00 13.00 15.00 W.O. R 15 P Run in hole with 238 mechanical cutter to 3,150' before deviating out. Engage tractor and tractor in hole at 30 FPM to XN nipple at 11,491'. Made three correlation passes and determine cut depth. Pull up to 11,409.61' CCL depth plus 36.67' offset to 11,446.28' cutter depth. Engage Welltec tubing cutter and cut tubing at 11,446.28'. Pull out of hole with E-line. Inspect cutter and determined cutter arms reached 13.71 MM, 4.824". 15:00 22:00 7.00 22.00 W.O. R 5 P PJSM, rig down Halliburton wireline and pressure control equipment to side of rig floor. Pickup tubing string 4' to verify tubing cut. Continue rigging down wireline and pressure control equipment while monitoring well. Clear floor and pipe shed of all E- line equipment. Released Halliburton. 22:00 00:00 2.00 24.00 W.O. M 5 P Rig up GBR power tongs. Pull tubing hanger to floor and lay down landing joint and hanger. Make up safety valve on tubing. Start bull heading operations down A Annulus. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. OPPdiilling@eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 11,601.0 17,164.0 3,341.5 7/26/2012 Well Name: OI20-07 OR Wellbore Name: OI20-07 Well Code: 26484 Job: WORKOVER WCEI: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 4/4/2023 Report #: 6 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 0.00 Ground Level (ft) 12.20 First Flange (ft) 15.85 RKB - Base Flange (ft) -15.85 RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Overcast Temperature (°F) -7.4 Wind W @ 10 MPH Days LTI (days) 2,036.00 Days RI (days) POB 42.0 Daily Summary Operations 24h Forecast Finish laying down completion tubing. Make up Baker clean out assembly and single in hole to 20' above tubing stump at 11,446'. 24h Summary Bull head A Annulus with 836 bbls of 8.6 ppg brine and monitor well. Let pressures stabilize and begin to bleed off pressures. Close in and pressure was building. Bull headed another 836 bbls. Monitor pressures and bled well down to 0 psi. Flow check good. Pull out of hole with 4.5" completion. Operation at 07.00 Pulling out of the hole with 4-1/2" completion tubing. 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. M 9 P PJSM Bull head A Annulus with 836 bbls of 8.6 ppg brine at 3 bpm, 385 psi while monitoring B Annulus. 04:30 06:00 1.50 6.00 W.O. M 1 P Monitoring A Annulus at 80 psi. Bleed down annulus and returns are 30 bbls of mostly diesel. Close choke. ICP 20 psi. 15 minutes raised to 50 psi 06:00 08:30 2.50 8.50 W.O. M 9 P Bull head 836 bbls of 8.6 ppg brine down A Annulus at 5 bpm, 600 psi. Monitoring B Annulus. 08:30 12:00 3.50 12.00 W.O. M 1 P Monitor pressures; A Annulus bled down to 110 psi after 1 hour and built back to 120 psi and stabilized. ITP 75 psi and bled down to 0 psi in 1 hour and maintained 0 psi. 12:00 16:00 4.00 16.00 W.O. M 1 P A Annulus at 65 psi, bled off 20 bbls and closed in. A Annulus at 78 psi, Tbg 0 psi. At 13:30, Bled off 20 bbls and closed in A Annulus at 29 psi, Tbg 0 psi. At 14:00, opened choke and continuously bled A Annulus while monitoring returns and pressure. At 16:00, shut in A Annulus and no pressure increase. 16:00 17:00 1.00 17.00 W.O. M 1 P Open A Annulus and tubing and check for flow. Monitor for 30 minute. Open BOP annular and flow check- Stable. 17:00 18:00 1.00 18.00 W.O. M 5 P PJSM Rig down circ hose and pumping equipment. Blow down choke and surface lines. Rig up GBR power tongs. 18:00 00:00 6.00 24.00 W.O. L 4 P Pull out of hole laying down 4.5" completion tubing from 11,415' to 6590', PUW 95k. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 11,601.0 17,164.0 3,341.5 7/26/2012 Well Name: OI20-07 OR Wellbore Name: OI20-07 Well Code: 26484 Job: WORKOVER WCEI: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 4/5/2023 Report #: 7 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 0.00 Ground Level (ft) 12.20 First Flange (ft) 15.85 RKB - Base Flange (ft) -15.85 RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Overcast Temperature (°F) -18.9 Wind SW @ 18 MPH Days LTI (days) 2,037.00 Days RI (days) POB 41.0 Daily Summary Operations 24h Forecast Pull out of the hole with Baker clean out assembly as per well plan. Lay down BHA #1 and make up BHA #2 with test packer. 24h Summary Pull out of hole laying down completion string. Load in pipe shed Baker tool string components, drill pipe and HWDP. Make up Baker clean out assembly and single in hole with 4" drill pipe to 1720'. Operation at 07.00 Run in hole with Baker clean out assembly. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 08:30 8.50 8.50 W.O. L 4 P Pull out of hole laying down 4-1/2" completion tubing from 6,590' MD to cut. (last tubing jt = 18.90') Add 10 bbls/hr plus pipe displacement of 8.6 ppg 3% KCL. 08:30 11:30 3.00 11.50 W.O. M 5 P Rig down 4-1/2" handling equipment. Remove 4-1/2" tubing from pipe shed. Clear and clean rig floor and pipe shed of diesel from trip out hole. 11:30 19:00 7.50 19.00 W.O. C 5 P Vault installed wear bushing. SIMOPS: Load Baker clean out assembly BHA and stage. Fill pipe shed with remainder of 4" drill pipe and heavy weight drill pipe and process. Continue adding 10 bbls/hr of 8.6ppg 3% KCL. 19:00 22:00 3.00 22.00 W.O. M 5 P PJSM and make up clean out BHA #1, Taper Mill, 9 5/8" Scraper, 2-Boot Baskets, Bit Sub, 2-Magnets, Bumper Sub, Oil Jars, XO, 12 Joints of 4" HWDP, XO, Accelerator, XO. 22:00 00:00 2.00 24.00 W.O. M 4 P Single 4" drill pipe in hole with Baker clean out assembly BHA #1 from 463' to 1720', SOW 65k. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 11,601.0 17,164.0 3,341.5 7/26/2012 Well Name: OI20-07 OR Wellbore Name: OI20-07 Well Code: 26484 Job: WORKOVER WCEI: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 4/6/2023 Report #: 8 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 0.00 Ground Level (ft) 12.20 First Flange (ft) 15.85 RKB - Base Flange (ft) -15.85 RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -20.6 Wind S @ 12 MPH Days LTI (days) 2,038.00 Days RI (days) POB 40.0 Daily Summary Operations 24h Forecast Run in hole with overshot to tubing stump and latch. Unseat Halliburton PHL packer and pull free. Circulate bottoms up through choke with annular closed. Monitor well. Pull out of hole with packer and lower completion. Make up Baker test packer and run in hole. 24h Summary Run in hole with Baker BHA #1, clean out assembly and scrape 9 5/8" casing from 11,126' to 11,432' 3- times. Pull out of hole and change out to BHA #2, overshot assembly. Run in hole to 4765'. Operation at 07.00 Halliburton packer released. Circulating bottoms up through choke with annular closed. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 11:00 11.00 11.00 W.O. M 4 P Continue to single 4" drill pipe in hole with Baker clean out assembly BHA #1 from 1,720' MD to 11,410' MD. Pick up single and make top drive connection. Add 10 bbls/hr of 8.6ppg 3% KCL. 11:00 12:00 1.00 12.00 W.O. M 7 P Bring on rig pumps at 3 BPM -130 PSI. Obtain pressure with 15 bbls pumped and observe diesel returns at 30 bbls pumped. Obtain parameters P/U WT = 115K, S/O WT = 51K at 3 BPM. Pump in the hole from 11,410' MD to 11,432' MD (taper mill depth) Take diesel returns to outside cuttings tank. 12:00 13:30 1.50 13.50 W.O. M 4 P Scrape with pumps from 11,432' MD to 11,126' MD 3 times. Taking diesel returns to outside cuttings tank. 13:30 14:00 0.50 14.00 W.O. M 11 P Shut down pumps and monitor well, (on losses) Blow down top drive. 14:00 20:30 6.50 20.50 W.O. M 4 P Pull out of hole racking back drill pipe and HWDP in derrick from 11,126' MD to 98'. Add 10 bbls/hr 8.6ppg 3% KCL. Lay down BHA #1 and clean magnets with 16lbs of fine metal. 20:30 21:30 1.00 21.50 W.O. M 5 P PJSM Pick up BHA #2; (Oversized Guide, 5.75" overshot with 4.5" Grapple, XO, pump out sub, bumper sub, oil jars, XO, 12 Joints HWDP, XO, accelerator, XO) total 429.45' length. Inspect handling equipment and iron roughneck. 21:30 00:00 2.50 24.00 W.O. M 4 P Run in hole with BHA #2 on 4" drill pipe stands from 49' to 4765', SOW 60k. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 11,601.0 17,164.0 3,341.5 7/26/2012 Well Name: OI20-07 OR Wellbore Name: OI20-07 Well Code: 26484 Job: WORKOVER WCEI: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 4/7/2023 Report #: 9 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 0.00 Ground Level (ft) 12.20 First Flange (ft) 15.85 RKB - Base Flange (ft) -15.85 RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Overcast Temperature (°F) -6.0 Wind W @ 12 MPH Days LTI (days) 2,039.00 Days RI (days) POB 40.0 Daily Summary Operations 24h Forecast Rig up and perform BOPE testing. Make up Baker test packer and run in hole. Pressure test A Annulus. Release test packer and pull out of hole laying down 4" drill pipe. 24h Summary Run in the hole with overshot assembly and latched tubing stump at 22,446'. Verify a good latch and pulled PHL packer free with 200k. Let packer elements relax and circulated bottoms ups through gas buster. Pull packer assembly out of hole and layed down all completion and Baker tools. 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 04:30 4.50 4.50 W.O. M 4 P Continue running in hole with BHA #2 on 4" drill pipe stands from 4,765' to 11,446'. P/U = 121K S/O = 45K. Add 10 bbls/hr 8.6 ppg 3% KCl. 04:30 10:30 6.00 10.50 W.O. M 19 P Work over top of tubing with overshot and set down 10K. Pick up to 126K, then slack off to 42K. (block weight). Pick up to 140K and allow oil jars to bled off to 121K. Pick up with oil jars bled off for straight pull and observe packer release at 200K. Allow packer elements to relax. Slack off and set 5K on liner top to verify fish on. Space out tool joints and circulate bottoms up thru gas buster at 3 BPM with full open choke. 10:30 11:00 0.50 11.00 W.O. M 1 P Flow check (static) and blow down top drive. 11:00 19:00 8.00 19.00 W.O. M 4 P POOH from 11,446' MD to BHA while adding 10 bbls/hr 8.6 ppg 3% KCl. 19:00 00:00 5.00 24.00 W.O. M 5 P PJSM Lay down accelerator. Lay down overshot assembly, Halliburton packer with pups, mirage plug assembly, 2 joints of 4.5" tubing and no-go sub, XN nipple and tie back entry guide. Total of 184'. Pick up and breakout jars, bumper sub, XO's, overshot and Baker fishing tools. Offload Baker BHA to be sent to town for inspection. Off load all decompletion from pipe shed. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 11,601.0 17,164.0 3,341.5 7/26/2012 Well Name: OI20-07 OR Wellbore Name: OI20-07 Well Code: 26484 Job: WORKOVER WCEI: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 4/8/2023 Report #: 10 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 0.00 Ground Level (ft) 12.20 First Flange (ft) 15.85 RKB - Base Flange (ft) -15.85 RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -25.0 Wind S @ 12 MPH Days LTI (days) 2,040.00 Days RI (days) POB 44.0 Daily Summary Operations 24h Forecast Identified a loose connection in the 4" drill pipe. Pulling out of hole with test packer tightening all connections while racking back drill pipe. 24h Summary Vault pulled wear bushing and installed test plug. Rig up and tested BOPE. Make up Baker test packer and run in hole and set at 11,426'. Pressure test failed. Move up hole to 11,361' test again. Failed. Operation at 07.00 Pull out of hole tightening all connections on 4" drill pipe. 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 Finish pulling out of hole with Baker fishing tools and old completion. 01:00 03:30 2.50 3.50 W.O. C 5 P PJSM Pull out wear bushing, set test plug. Install 4.5" test joint and rig up for testing BOPE. Verify valve alignments and fluid pack system. 03:30 09:30 6.00 9.50 W.O. C 12 P PJSM Test BOPE as per AOGCC specs to 250/3500 psi with 4.5" and 4" test joints. Witness waived by Brian Bixby. Tested gas alarms and PVT totalizers. 09:30 10:30 1.00 10.50 W.O. C 5 P PJSM Pull out test plug. Rig down all testing equipment and organize floor. Blow down choke manifold. Vault install wear bushing. Bring in drums for mixing packer fluid. 10:30 12:00 1.50 12.00 W.O. M 5 P PJSM Make up BHA #3, Baker test packer assembly. 12:00 20:00 8.00 20.00 W.O. M 4 P PJSM Run in hole with Baker test packer from 145' to 11,063' at 90 fpm, SOW 48k. Run in hole with 4" HWDP from 11,063' to 11,405'. 20:00 00:00 4.00 24.00 W.O. M 11 U PJSM Set test packer as per Baker at 11,426' COE. Rig up to perform casing test as per plan and pressure was leaking off. Eliminated potential surface bleed off problems and tried multiple times with the same results. Unseated packer and pull up to 11,361' and set packer. Attempted again to get A Annulus to hold pressure with no success. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 11,601.0 17,164.0 3,341.5 7/26/2012 Well Name: OI20-07 OR Wellbore Name: OI20-07 Well Code: 26484 Job: WORKOVER WCEI: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 4/9/2023 Report #: 11 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 0.00 Ground Level (ft) 12.20 First Flange (ft) 15.85 RKB - Base Flange (ft) -15.85 RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Overcast Temperature (°F) -4.0 Wind N @ 15 MPH Days LTI (days) 2,041.00 Days RI (days) POB 44.0 Daily Summary Operations 24h Forecast Run in hole and set packer. Perform casing integrity test. Unseat packer and pull out of hole laying down 4" drill pipe and test packer. Off load all 4" and load in 4.5" completion tubing. 24h Summary Attempted to perform casing integrity test. Pulled up hole to reset the Retrievamatic test packer and observed a drill pipe connection was loose. Pull out of hole re tightening all tool joint connections. Lay down packer and make up Baker TST3 test packer. Run in hole to 8225'. Operation at 07.00 Pulling out of hole test packer. 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. M 11 U After packer was unseated, pull up to 11,361' and set packer. Continue to attempt to get A Annulus to hold pressure with no success. Pressure up to 1500 psi, pressure decreased to 1200 psi in 25 minutes. 01:30 15:30 14.00 15.50 W.O. M 4 U Release packer and pull up to 11,247' and observe loose connection on drill pipe. Set slips and torque connection. Pull out of hole checking torque on all connections from 11,247' to 21'. Add 10 bbls/hr of 8.6ppg 3% KCL. P/U WT = 130 K, S/O WT = 50 K, RT WT = 90 K 15:30 16:00 0.50 16.00 W.O. M 5 U Inspect and lay down Baker Retrievamatic service packer. 16:00 18:00 2.00 18.00 W.O. M 1 U PJSM Load Baker TST3 test packer and inspect. Load 18 Joints of HWDP, strap and tally. Service, grease and change iron roughneck dies. Make BHA #4 running tally and clean and organize rig floor. 18:00 18:30 0.50 18.50 W.O. M 5 U PJSM Make up Baker BHA #4, test packer. 18:30 00:00 5.50 24.00 W.O. M 4 P PJSM Run in hole with test packer at 60 fpm from 21' to 8225', SOW 50k. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 11,601.0 17,164.0 3,341.5 7/26/2012 Well Name: OI20-07 OR Wellbore Name: OI20-07 Well Code: 26484 Job: WORKOVER WCEI: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 4/10/2023 Report #: 12 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 0.00 Ground Level (ft) 12.20 First Flange (ft) 15.85 RKB - Base Flange (ft) -15.85 RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Overcast Temperature (°F) -5.0 Wind SW @ 15 MPH Days LTI (days) 2,042.00 Days RI (days) POB 45.0 Daily Summary Operations 24h Forecast Slip and cut drill line. Load 4.5" W563 tubing, drift, strap and tally. Load completion BHA into shed and inspect. Crane completion spools to floor and ready them for completion run. Run completion as per program. 24h Summary Run in hole with Baker test packer and set at 11,427'. Perform casing integrity test. Unseat packer and pull out of hole laying down drill pipe and packer. Pull wear bushing and hang blocks for slip and cut drill line. Operation at 07.00 Loading pipe shed with 4.5 " completion tubing. 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. M 1 P Grease iron roughneck. Check handling equipment. Fill out derrick work permit. 00:30 04:00 3.50 4.00 W.O. M 4 P PJSM Run in hole with test packer, BHA #4 from 8825' to 10,117'. Reduced running rate do to string float. Single in 18 Joints of 4" HWDP from 10,117' to 10,670'. Run in hole from 10,670' to 11,427'. 04:00 07:00 3.00 7.00 W.O. M 12 P PJSM Set test packer at 11,427' as per Baker with PUW 132k, SOW 50k, ROTW 90k, 5 RPM, 8.6k TQ. Set with 20k. Fill A Annulus and fluid packer system for testing. Perform casing integrity test by pressuring up to 500, 1000, 1500 and 2000psi for 30 charted minutes. Blow down choke and top drive. Prep pipe shed for laying down drill pipe. 07:00 20:00 13.00 20.00 W.O. M 4 P PJSM Baker release packer and fluid level in Annulus dropped. Pull drill string loose at 145k. Let elements relax. Pull out of hole laying down 4" work string from 11,427' to 21'. 20:00 20:30 0.50 20.50 W.O. M 25 P Change out iron roughneck carriers with new dies. Grease iron roughneck. 20:30 22:00 1.50 22.00 W.O. M 5 P PJSM Lay down test packer BHA #4. Run in hole 6 stands of 4" drill pipe and pull out and lay down the same. 22:00 22:30 0.50 22.50 W.O. C 5 P PJSM Vault pulled wear bushing. 22:30 23:30 1.00 23.50 W.O. M 1 P PJSM Off load Baker packer and load in tubing hanger Prep to load 4.5" tubing. 23:30 00:00 0.50 24.00 W.O. M 25 P PJSM Hang blocks for slip and cut drill line. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Craig Smith ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 11,601.0 17,164.0 3,341.5 7/26/2012 Well Name: OI20-07 OR Wellbore Name: OI20-07 Well Code: 26484 Job: WORKOVER WCEI: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 4/11/2023 Report #: 13 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 0.00 Ground Level (ft) 12.20 First Flange (ft) 15.85 RKB - Base Flange (ft) -15.85 RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -9.0 Wind SW @ 10 MPH Days LTI (days) 2,043.00 Days RI (days) POB 45.0 Daily Summary Operations 24h Forecast Rig up all equipment and run 4.5" injection completion as per tally. 24h Summary Cut and slip drill line. Loading and processing 4.5" 563 coated tubing. Crane Schlumberger spools to rig floor. Continue to load and process tubing. Begin set up for running injection completion. Operation at 07.00 Run injection completion. 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 25 P PJSM for cut and slip. Disconnect iron rough neck hydraulics. Cut and slip 100' of drill line. Calibrate blocks. 02:00 14:00 12.00 14.00 W.O. M 20 P PJSM Load in 4" test joint and tubing hanger. Loading W563 coated tubing, drift, strap and tally. Arctic Solutions certified man rider and manlift. Continue to load and process tubing. 14:00 15:00 1.00 15.00 W.O. M 1 P PJSM Lift meeting with personnel. Crane Schumberger spoolers onto rig. 15:00 00:00 9.00 24.00 W.O. M 20 P Load and process tubing. Schlumberger string lines over sheaves. PJSM with GBR pipe handling service. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Craig Smith ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 11,601.0 17,164.0 3,341.5 7/26/2012 Well Name: OI20-07 OR Wellbore Name: OI20-07 Well Code: 26484 Job: WORKOVER WCEI: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 4/12/2023 Report #: 14 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 0.00 Ground Level (ft) 12.20 First Flange (ft) 15.85 RKB - Base Flange (ft) -15.85 RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -22.7 Wind SW @ 18 MPH Days LTI (days) 2,044.00 Days RI (days) POB 43.0 Daily Summary Operations 24h Forecast Pump lube pill and spot at 11,122'. Run in the hole with 4.5" upper completion from 11,122' to 11,601'. Space out upper completion to land hanger, make up tubing hanger, pump freeze protection and packer fluid land hanger. Test upper and lower seals. Set packer as per Halliburton rep, nipple down BOPS and nipple up tree. 24h Summary Rig up and run 4.5" upper completion assembly. Operation at 07.00 Land 4.5" tubing. 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 1 P PJSM. Continue rigging up 4 1/2" upper completion equipment. Bring cross collar clamps to rig floor. Add 10 bbls/hr of 8.6ppg 3% KCL. 02:00 03:30 1.50 3.50 W.O. M 12 P PJSM. Install Schlumberger lines to gas mandrel. Test lines to 5,000 psi for 15 min. Good test. 03:30 08:00 4.50 8.00 W.O. K 4 P PJSM. Run in the hole with 4.5" completion tubing from 193' to 4021' at 90 fpm. Add 10 bbls/hr of 8.6ppg 3% KCL. 08:00 09:00 1.00 9.00 W.O. K 20 P PJSM. Lay down joint 95 & 96 bad collars. Pick up 2 new joints strap and drift new 4.5" completion tubing. 09:00 16:30 7.50 16.50 W.O. K 4 P PJSM. Run in the hole from 4021' to 9288' at 90 fpm. PUW = 69k; SOW = 45k. Add 10 bbls/hr of 8.6ppg 3% KCL. 16:30 17:30 1.00 17.50 W.O. K 12 P PJSM. Pick up TRSCSSSV, SLB connect cap line and test to 4,800 psi. Good test. 17:30 22:30 5.00 22.50 W.O. K 4 P PJSM. Run in the hole from 9288' to 11122'. Fill tubing every 8 stands. 4.5” completion is floating in the hole with a slack off weight zero down weight. PUW = 111K; SOW = zero. Unable to move 4.5” completion down past 11,122'. Work pipe few time up/down while filling A-Annulus. Lay down joint #268, fill tubing with fill hose. Monitor well. Add 10 bbls/hr of 8.6ppg 3% KCL. 22:30 00:00 1.50 24.00 W.O. K 8 P PJSM. Mix 60 bbl. Lube pill, Received 300 bbl. in the pits 8.6 brine with 3% KCL. Add 10 bbls/hr of 8.6ppg 3% KCL. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Craig Smith ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 11,601.0 17,164.0 3,341.5 7/26/2012 Well Name: OI20-07 OR Wellbore Name: OI20-07 Well Code: 26484 Job: WORKOVER WCEI: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 4/13/2023 Report #: 15 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 0.00 Ground Level (ft) 12.20 First Flange (ft) 15.85 RKB - Base Flange (ft) -15.85 RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -16.0 Wind SW @ 13 MPH Days LTI (days) 2,045.00 Days RI (days) POB 41.0 Daily Summary Operations 24h Forecast Continue nipple up tree, perform passport test with Vault rep. Secure well. Rig move from OI20-07 to OI13-03. 24h Summary Continue mix 60 bbl lube pill. Pump and spot lube pill at 11,122'. Run in the hole with 4.5” upper completion to 11,621’. Space out upper completion to land hanger, make up tubing hanger, pump completion and packer fluid land hanger. Test upper/lower seals. Set packer as per Halliburton rep, nipple down BOP and nipple up tree. Operation at 07.00 Rig move from OI20-07 to OI13-03. 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. K 9 P PJSM. Continue mix 60 bbl lube pill. Transfer 8.6 ppg brine to the pits. Bull head down A-Annulus 60bbl lube pill. Chased with 617 bbl at 3 bpm at 150 psi. Bleed off tubing and A-Annulus (no flow). 05:00 07:00 2.00 7.00 W.O. K 4 P PJSM. Run in hole from 11,114' to 11,571'. Fill tubing. Continue run in hole to 11,620’. Sheared pins on fluted locator sub at 8K stack out on the no/go at 11,621' with 10K, PUW = 110K; SOW = 50K. Perform space out to lay down 3 joints. Pick up 15' pup joint. Bottom of upper completion set at 11,619.56'. Total cross coupling clamps: mid clamps total 2, stand off clamps total 2. 07:00 09:30 2.50 9.50 W.O. K 19 P PJSM. Make up tubing hanger and landing joint, bleed pressure and terminate Schlumberger tec lines with Vault tech. Install lines into hanger, land hanger run in lock down screws. Perform upper and lower seal test on hanger void with 5,000 psi for 15 min. Good test. 09:30 12:00 2.50 12.00 W.O. K 9 P PJSM. Rig up FOSV and XO to landing joint, Make up 2" hose to pump down tubing. Bull head 500 bbl down A Annulus at 5 bpm with 320 psi. Pump 125 bbl freeze protect at 5 bpm with 300 psi. Rig off high line power at 10:00 am. 12:00 17:00 5.00 17.00 W.O. K 12 P PJSM. Rig up to set 9-5/8” Halliburton completion packer. Pressure test surface lines to 5k. Change out circulation 2" hose on rig floor. Pump down tubing. Pressure up to 3,500 psi, set packer and charted 30 min. Good test. Close 4.5” Trimaxx safety valve, bleed pressure down to 2,000 psi. Conduct inflow test charted 30 min. Good test. Perform packer test on back side 2,000 psi charted 30 min. Good test. Bleed pressure down to 0 psi. Pump down tubing shear Mirage plug at 4,600 psi. Bleed pressure to a 0 psi. 17:00 21:30 4.50 21.50 W.O. K 5 P PJSM. Remove land joint. Install BPV in well head profile as per Vault rep. Remove choke and kill lines. Nipple down BOP stack. 21:30 00:00 2.50 24.00 W.O. K 5 P PJSM. Obtain well bay permit. Remove riser. Terminate Schlumberger cap line. Nipple up tree. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Craig Smith ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 11,601.0 17,164.0 3,341.5 7/26/2012 Well Name: OI20-07 OR Wellbore Name: OI20-07 Well Code: 26484 Job: WORKOVER WCEI: N/A Selected table has no valid attachments that can be displayed Daily Report Date: 4/14/2023 Report #: 16 Page: 1 of 1 Well Header Permit/Concession N° ADL-388583 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 0.00 Ground Level (ft) 12.20 First Flange (ft) 15.85 RKB - Base Flange (ft) -15.85 RKB - Tubing Spool (ft) Rig Information Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Daily Information Weather Clear Temperature (°F) -16.0 Wind SW @ 6 MPH Days LTI (days) 2,046.00 Days RI (days) POB 36.0 Daily Summary Operations 24h Forecast Rig move from OI20-07 to OI13-03. 24h Summary Perform passport test with Vault rep. Secure well. Rig move from OI20-07 to OI13-03. Operation at 07.00 Release rig at 04:00 on 4-14-2023 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. A 2 P Perform passport test with Vault rep. Secure well. Rig move from OI20-07 to OI13-03. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Justin Hays ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Craig Smith ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Greg Lomax ASRC Energy Services HSE Greg.Lomax@enternal.eni.com 970-685-6622 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push George Orloff Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 L80 11,601.0 17,164.0 3,341.5 7/26/2012 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Packer Changeout_ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No OI20-07 9. Property Designation (Lease Number): 10. Field: Current Pools: Nikaitchuq Schrader Bluff 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 18,952'1,163 N/A N/A Casing Collapse Structural Conductor N/A Surface 2,480 Intermediate 4,790 Production Liner Blank liner w/ICD's Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Stefano Pierfelici Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 11,830'-19,952' 4-1/2" 3,373'-3,143' 11,601'-17,164'5,563' 4.5" 3,355'-3,339' 20 13-3/8" 160 2,577' Perforation Depth MD (ft): 9-5/8"11,797' MD 6,890 N/A 5,210 160 2160 3370 160 2759 11830 Length Size Proposed Pools: TVD Burst Schrader Bluff 3,143'17,164'3,339' PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 355024, 373301, 391283,388577 211-140 3700 Centerpoint Drive Suite 500, Anchorage 99503 50-029-23459-00-00 Eni US Operating Co. Inc. Blank liner w/ICD's Tubing Grade:Tubing MD (ft): 11,471' /3,345' Perforation Depth TVD (ft):Tubing Size: L-80 11,420' march 10t, 2023 Halliburton PHL 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 and Digital Signature with Date: AOGCC USE ONLY Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3379 Well Operations project Manager 2/21/2023 m n P s 66 t _ Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov ci By Samantha Carlisle at 12:06 pm, Feb 22, 2023 323-114 SFD 3/1/2023BJM 3/1/23 BOP test to 2500 psi. 10-407 DSR-2/22/23 X JLC 3/2/2023 3/2/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.03.02 11:27:45 -09'00' RBDMS JSB 030223 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 Email: Stefano.pierfelici@eni.com February 21st 2023 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OI20-07 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OI20-07 ENI Petroleum at Oliktok Point completed OI20-07 in August 2012 as a Schrader bluff injector. In March 2021 well failed a routine 4 years state required MIT. In April 2021, a rig less job was performed for leak investigation with a caliper log/ACX Herein the result of the analysis, showing potential tubing leak ACX data shows TxIA communications at 9,766.6’. A tubing patch was set and well passed MIT. On May 20, 2022, the well experienced slow tubing by inner annulus (TxIA) pressure communication and was reported to AOGCC. Eni has completed workovers installing new tubing patches, but the well continues to fail the standard MITIA test criteria. Eni performed diagnostics and monitoring including a passing non- state witnessed combination MIT of the tubing and inner annulus on July 1, 2022 which confirms integrity of the 9-5/8”casing to the packer at 11,471 ft MD. Eni applied for administrative approval AIO no.36.007 for continue injection and it was granted om August 24t, 2022. It is now planned to perform a rig workover and replace tubing and run a new packer to restore full integrity of the well. The estimated date for beginning this work is March 10,2023. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907- 865-3379. Sincerely, Stefano Pierfelici Well Operations Project Manager OI20-07 Workover – Summary Page PTD#:211-140 Status Well, OI20-07 is currently on injection. Scope of Work Scope of this workover is pull out existing tubing and injection packer and run new tubing and new packer. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 1500 psi (3,373’ TVD) during the time of workover. Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/Blind/2-7/8” x 5” VBR/4-1/2” Pipe Ram TIFL/MIT-IA/MIT-OA: Performed combo MIT on June 1st, 2022, to 1200 psi. and it passed. Well type: Injector Estimated start date: March 10th, 2023 Drilling rig: Nordic-4 Senior Drilling Engineer Amjad Chaudhry Amjad.chaudhry@eni.com Work: 907-865-3379 Well Operations project Manager Stefano Pierfelici Stefano.pierfelici@eni.com Work: 907-865-3320 Procedure: 1. Pump in bull heading 8.6 to 9.0 ppg KCL/NaCl brine (TBC) through tree. 2. Ensure well is killed. Set BPV. 3. MIRU Rig Nordic-4. 4. ND tree and NU BOP and test. 5. Set plug in XN nipple below packer 6. Cut 4-1/2” tubing at the middle of first joint above packer at 11,471’ MD. 7. Circ through tubing cut displacing 4-1/2” x 9-5/8” annular fluids with KCL/NaCl brine. 8. RIH and pull plug from XN nipple. 9. POOH with tubing and LD the same. 10. Drift 9-5/8” casing to the top of tubing cut and POOH. 11. RIH with fishing BHA, unseat packer and POOH with 4-1/2” injection completion string. 12. MU/PU CO scraper assembly and RIH CO to the top of the liner. POOH 13. MU 4 ½” tubing and new 4 ½” x 9 5/8” packer and RIH to the proposed setting depth of packer +/- 11,466’ MD. Note: Packer setting depth is more than 200’ from the top of formation, proposed setting depth is almost the same (+/- feet different from original setting depth) Original packer was set more than 200’ above the formation as per AIO 36 Rule#2 (Sonic vision indicates cement top is at 9,507’ MD) 14. Land tubing hanger 15. Circ freeze protection and corrosion inhibited KCL/NaCl brine completion fluid to 4-1/2” x 9-5/8” annulus 16. Set 4-1/2” x 9-5/8” new packers 17. Pressure test 4-1/2” x 9-5/8” annulus to 1500 psi, charted 18. Pull tubing plug in XN nipple below packer 19. Install BPV and nipple down BOP. 20. NU tubing adapter and tree. 21. Pull BPV, install test plug and test tree. 22. RDMO. Below the current schematic of the well: Proposed Schematic Nordic-4 BOP Well Head 9-5/8" casing. Typo on the log per Amjad Chaudry. -bjm 9-5/8" 9-5/8" 9-5/8" 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OI20-07 (PTD# 211-140) TxIA Communication Date:Thursday, July 14, 2022 9:03:06 AM Attachments:image001.png From: Lopez Keith <Keith.Lopez@eni.com> Sent: Thursday, July 14, 2022 9:01 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Hart David <David.Hart@eni.com>; Giraud Hector <Hector.Giraud@eni.com>; Rupert Stephanie <Stephanie.Rupert@eni.com>; Pierfelici Stefano <Stefano.Pierfelici@eni.com>; Lyden Dan <Dan.Lyden@eni.com>; Dexheimer Stephen <Stephen.Dexheimer@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Brown Timothy <Timothy.Brown@eni.com>; Hanson Samuel <Sam.Hanson@eni.com>; Carballo Nelson <Nelson.Carballo@eni.com>; Lopez Keith <Keith.Lopez@eni.com> Subject: RE: OI20-07 (PTD# 211-140) TxIA Communication Mr. Wallace, OI20-07’s IA failed to hold pressure when we attempted an in-house MIT last night. The injector will be shut in until further intervention can be planned. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 Keith.Lopez@eni.com From: Lopez Keith <Keith.Lopez@eni.com> Sent: Monday, July 11, 2022 11:15 AM To: chris.wallace@alaska.gov; Regg, James B (CED) <jim.regg@alaska.gov> Cc: Hart David <David.Hart@eni.com>; Giraud Hector <Hector.Giraud@eni.com>; Rupert Stephanie <Stephanie.Rupert@eni.com>; Pierfelici Stefano <Stefano.Pierfelici@eni.com>; Lyden Dan <Dan.Lyden@eni.com>; Dexheimer Stephen <Stephen.Dexheimer@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Brown Timothy <Timothy.Brown@eni.com>; Hanson Samuel <Sam.Hanson@eni.com>; Lopez Keith <Keith.Lopez@eni.com>; Carballo Nelson <Nelson.Carballo@eni.com> Subject: RE: OI20-07 (PTD# 211-140) TxIA Communication Mr. Wallace, ENI set a second tubing patch in the injector OI20-07 and brought the well on injection on 7/7/22. We have been monitoring the well for thermal stabilization and any signs of continued TxIA communication, however, the tubing pressure has only climbed to 4 psi and the annulus pressure remains on a vacuum. Today we pumped 34 bbls of diesel down the IA and increased the IA pressure to ~100 psi. We will continue to watch the well for stabilization so that we can conduct the state witnessed MIT in a timely manner. Thank you and please let me know if you have any questions or concerns. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 Keith.Lopez@eni.com From: Lopez Keith <Keith.Lopez@eni.com> Sent: Friday, May 20, 2022 10:44 AM To: chris.wallace@alaska.gov; Regg, James B (CED) <jim.regg@alaska.gov> Cc: Hart David <David.Hart@eni.com>; Giraud Hector <Hector.Giraud@eni.com>; Rupert Stephanie <Stephanie.Rupert@eni.com>; Pierfelici Stefano <Stefano.Pierfelici@eni.com>; Lyden Dan <Dan.Lyden@eni.com>; Dexheimer Stephen <Stephen.Dexheimer@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Lopez Keith <Keith.Lopez@eni.com> Subject: OI20-07 (PTD# 211-140) TxIA Communication Mr. Wallace, Yesterday (05-20-22), ENI noticed a concern with tubing by inner annulus communication on OI20-07. The IA pressure increased from -6 psi to 300 psi over a 5 hour period. The injector was shut in and the IA pressure immediately began bleeding off. The well will remain shut in until further diagnostics can be conducted with slickline/eline. OI20-07 failed its last 4-year MIT on 03/21/21 but passed at AOGCC witnessed MIT on 06/04/21 after a tubing patch was set. Please let me know of any concerns or further data the AOGCC requires. Thank you. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 Keith.Lopez@eni.com ------------------------------------------------------------------------------------------------------------------------------------------------------------------------ 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OI20-07 (PTD# 211-140) TxIA Communication Date:Tuesday, July 12, 2022 11:46:21 AM Attachments:image002.png From: Lopez Keith <Keith.Lopez@eni.com> Sent: Monday, July 11, 2022 11:15 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Hart David <David.Hart@eni.com>; Giraud Hector <Hector.Giraud@eni.com>; Rupert Stephanie <Stephanie.Rupert@eni.com>; Pierfelici Stefano <Stefano.Pierfelici@eni.com>; Lyden Dan <Dan.Lyden@eni.com>; Dexheimer Stephen <Stephen.Dexheimer@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Brown Timothy <Timothy.Brown@eni.com>; Hanson Samuel <Sam.Hanson@eni.com>; Lopez Keith <Keith.Lopez@eni.com>; Carballo Nelson <Nelson.Carballo@eni.com> Subject: RE: OI20-07 (PTD# 211-140) TxIA Communication Mr. Wallace, ENI set a second tubing patch in the injector OI20-07 and brought the well on injection on 7/7/22. We have been monitoring the well for thermal stabilization and any signs of continued TxIA communication, however, the tubing pressure has only climbed to 4 psi and the annulus pressure remains on a vacuum. Today we pumped 34 bbls of diesel down the IA and increased the IA pressure to ~100 psi. We will continue to watch the well for stabilization so that we can conduct the state witnessed MIT in a timely manner. Thank you and please let me know if you have any questions or concerns. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 Keith.Lopez@eni.com From: Lopez Keith <Keith.Lopez@eni.com> Sent: Friday, May 20, 2022 10:44 AM To: chris.wallace@alaska.gov; Regg, James B (CED) <jim.regg@alaska.gov> Cc: Hart David <David.Hart@eni.com>; Giraud Hector <Hector.Giraud@eni.com>; Rupert Stephanie <Stephanie.Rupert@eni.com>; Pierfelici Stefano <Stefano.Pierfelici@eni.com>; Lyden Dan <Dan.Lyden@eni.com>; Dexheimer Stephen <Stephen.Dexheimer@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Lopez Keith <Keith.Lopez@eni.com> Subject: OI20-07 (PTD# 211-140) TxIA Communication Mr. Wallace, Yesterday (05-20-22), ENI noticed a concern with tubing by inner annulus communication on OI20-07. The IA pressure increased from -6 psi to 300 psi over a 5 hour period. The injector was shut in and the IA pressure immediately began bleeding off. The well will remain shut in until further diagnostics can be conducted with slickline/eline. OI20-07 failed its last 4-year MIT on 03/21/21 but passed at AOGCC witnessed MIT on 06/04/21 after a tubing patch was set. Please let me know of any concerns or further data the AOGCC requires. Thank you. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 Keith.Lopez@eni.com ------------------------------------------------------------------------------------------------------------------------------------------------------------------------ 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OI20-07 (PTD# 211-140) TxIA Communication Date:Wednesday, May 25, 2022 9:28:58 AM Attachments:image005.png OI20-07 Schematic_Updated_06-03-21.pdf From: Lopez Keith <Keith.Lopez@eni.com> Sent: Friday, May 20, 2022 10:44 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Hart David <David.Hart@eni.com>; Giraud Hector <Hector.Giraud@eni.com>; Rupert Stephanie <Stephanie.Rupert@eni.com>; Pierfelici Stefano <Stefano.Pierfelici@eni.com>; Lyden Dan <Dan.Lyden@eni.com>; Dexheimer Stephen <Stephen.Dexheimer@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Lopez Keith <Keith.Lopez@eni.com> Subject: OI20-07 (PTD# 211-140) TxIA Communication Mr. Wallace, Yesterday (05-20-22), ENI noticed a concern with tubing by inner annulus communication on OI20-07. The IA pressure increased from -6 psi to 300 psi over a 5 hour period. The injector was shut in and the IA pressure immediately began bleeding off. The well will remain shut in until further diagnostics can be conducted with slickline/eline. OI20-07 failed its last 4-year MIT on 03/21/21 but passed at AOGCC witnessed MIT on 06/04/21 after a tubing patch was set. Please let me know of any concerns or further data the AOGCC requires. Thank you. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 Keith.Lopez@eni.com ------------------------------------------------------------------------------------------------------------------------------------------------------------------------ 13-3/8" 68 ppf,Surf. Casing,2,759' MD, '2,160' TVD67º Inc9-5/8" 40 ppf, H563,Intermediate Casing,11,830' MD, 3,373'TVD, 85º Inc4-½”,12.6 ppf,H563, ProductionTubing4-½” 11.6 ppf, H521Production Liner,17,164' MD, 3,339' TVD91º IncZonal IsolationPackersInjection Control DevicesPHL Retr. Packer,11,471' MD, 3,345' TVD,85º IncConfidentialAC 06/03/21Nikaitchuq Field–Oliktok Point PadAs Completed8/1/2012Patch 06/01/20212,058' MD, 1,782' TVD, 46ºInc - 4-½” x 1" KBMG GLM, 2,000 psi A to Tshear valve1,967 MD, 1,718 TVD - 3.81" X-nipple for possible injection valve11,504' MD HAL Mirage Plug with Auto-fill valve11,419' MD - 3.81" X-nippleVIT, 3 joints, 4-½” x 6", approx 100'OI20-07 InjectorMonobore with Injection Control11,630' MD , 3,357' TVD–Bottom of entry guide11,491' MD - 3.81" XN (No-go 3.725")(inserted Nipple reducer 2-7/8" 6.4# XN StyleNipple with2.205"NoGo XN Profile 27/8" 6.4# Hydril 511 Box x Full Mule Shoe down11,601' MD, 3,355' TVD–Top of SLZXP Liner Hanger/Packer4-½” Ecc-Nose GuideShoeItemMD (ft)4-1/2" Swell Pkr #1171554-1/2" Swell Pkr #2171024-1/2" Swell Pkr #3162774-1/2" Swell Pkr #4152884-1/2" Swell Pkr #5143394-1/2" Swell Pkr #613340ItemMD (ft)ItemMD (ft)ICD #116836ICD #714033ICD #216532ICD #813679ICD #315971ICD #912961ICD #415626ICD #1012580ICD #514985ICD #1112197ICD #614638Patch ID=2.992"Patch #1=TOPE= 9,745.28'BOPE=9,777' MEMORANDUM TO: Jim Regg qq/ P.I. Supervisor I , �1��'��t� FROM: Jeff Jones Petroleum Inspector Well Name NIKAITCHUQ 0120-07 Insp Num: mitJJ210628160420 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 7, 2021 SUBJECT: Mechanical Integrity Tests Em US Operating Company Inc. 0120-07 NIKAITCHUQ 0120-07 Sre: Inspector Reviewed By: P.I. Supry �J/- Comm AI'I Well Number 50-029-23459-00-00 Inspector Name: Jeff Jones Permit Number: 211-140-0 Inspection Date: 6/4/2021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 0120-07 Type lnj TVD 3345 'Tubing 265 265 - 265 - 265 PTD 2111400 ' Type Test SPT ~Test psi 1500 - IA 1072 1698 1687 - 1685 BBL Pumped: I''i 1.8 - BBL Returned: 1.8 OA 1 160 160 180 165 — -- ---- -- — L -- Interval 4YRTST IP/F P Notes: I well inspected, no exceptions noted. Tubing patch installed after failed 4 year MIT 3/21/21. ✓ Wednesday, July 7, 2021 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday, April 2, 2021 P.L Supervisor �efj <� 9I I�jl7irJZ,' SUBJECT: Mechanical Integrity Tests L Em US Operating Company Inc. 0120-07 FROM: Matt Herrera NIRAITCHUQ 0120-07 Petroleum Inspector Sre: Inspector Reviewed By: P.I.Supry NON -CONFIDENTIAL Comm Well Name NBCAPTCHUQ 0120-07 API Well Number 50-029-23459-00-00 Inspector Name: Man Herrera Permit Number: 211-140-0 Inspection Date: 3/21/2021• Insp Num: mitMFH210323110347 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well O12o-o7 - Type lnj w- TVD,334s •Tubing s7s Well 372--T— , PTD 2111400 - Type Test I SPT- Test psi 1500 1 LA 1 479 1710, 500 BBL Pumped: u ' BBL Returned: I OA 145. Iso , 145, Interval 4YRTST I P/P F Notes: MIT -IA pressure was to be tested to minimum test pressure but could not be sustained Tubing pressure increase and continuous pumping indicated communication between IA and tubing. Integrity Test was deemed a FAIL and Operator was notified to perform well ✓ diagnostics to determine cause of integrity loss. Friday, April 2, 2021 Page 1 of I zI J 1400 Regg, James B (DOA) From: Smagge Lorne <Lorne.Smagge@enipetroleum.com> Sent: Wednesday,January 11, 2017 5:06 PM �T< 9,r; (ii�,�(7 To: Regg,James B (DOA) ((``�� Cc: Brooks, Phoebe L (DOA);Wallace, Chris D (DOA); Gauer Cody; Sonne Jennifer; Dexheimer Stephen; Lyden Dan;Atkins Mark Subject: FW: ENI OPP MITs Attachments: doc01961620170110200056.pdf; 0I20-07 -01-11-2017.xlsx Greetings Jim, Per your request I attached an excel workbook capturing pressures 90 days prior to the MIT along with a PDF showing the IA pressure trending up after we bypassed train 1 heat exchanger for maintenance. Bypassing the exchanger is allowing 170/175 degree water directly into injection header. Based on these findings we are witnessing thermal expansion due to the temperature increase of the water we are injecting downhole. Regards, Lorne E. Smagge/ Mark Atkins Production Supervisor eni US operating co. inc. 3800 Centerpoint Dr. Suite 300 SCANNED MAY 0 Z.J*III Anchorage, AK 99503 Direct: 907-670-8632 Mobile: 907-252-6972 Email: lorne.smagae@enipetroleum.com From: Regg, James B (DOA) [mailto jim.regg(aalaska.gov] Sent: Tuesday, January 10, 2017 11:07 AM To: Smagge Lorne Cc: Brooks, Phoebe L (DOA); Wallace, Chris D (DO ) Subject: RE: ENI OPP MITs Please explain reason for high pre-test pressure observ-• in the IA of Well 0120-07 (PTD 2111400). Provide tubing, inner annulus and outer annulus pressures for 90days prior to 4 IT. 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. 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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: Smagge Lorne [mailto:Lorne.Smagge@enipetroleum.comj Sent: Monday,January 09, 2017 8:18 PM To: Brooks, Phoebe L(DOA) <phoebe.brooks@alaska.gov> Cc: Sonne Jennifer<Jennifer.Sonne@enipetroleum.com>; Atkins Mark<Mark.Atkins@enipetroleum.com>; Regg,James B (DOA) <jim.regg@alaska.gov>; King Patrick<Patrick.King@enipetroleum.com>; Lyden Dan <Dan.Lyden@enipetroleum.com>; Dexheimer Stephen <Stephen.Dexheimer@enipetroleum.com>; Gauer Cody <Cody.Gauer@enipetroleum.com>; Hardy Scott<Scott.Hardy@enipetroleum.com> Subject: ENI OPP MITs Hi Phoebe, Attached is the OPP report you requested. I combined this report into one and added the trailing zero to the PTD. Regards, Lorne E. Smagge/ Mark Atkins Production Supervisor eni US operating co. inc. 3800 Centerpoint Dr. Suite 300 Anchorage, AK 99503 Direct: 907-670-8632 Mobile: 907-252-6972 Email: Iorne.smaggeOenioetroleum.com 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq@alaska.gov: AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov chris.wallace(caalaska.gov OPERATOR: ENI Petroleum US Operating Co.Alaska FIELD/UNIT/PAD: Nikaitchuq-OPP &tet II 030 DATE: 12/09/16 OPERATOR REP: Dwayne Weythman AOGCC REP: Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min, 60 Min. Well 01-02 Type Inj. W TVD 3,404' Tubing 380 388 388 388 Interval 4 P.T.D. 2061440 Type test P Test psi 1,500 Casing 352 1,706 1,678 1,676 P/F P Notes: 1.1 B/D Pumped OA 260 300 260 270 Well 016-05 Type Inj. W TVD 3,689' Tubing 486 486 486 _ 486 Interval 4 P.T.D. 2101650 Type test P Test psi 1,500 Casing 375 1,657 1,649 1,646 P/F P Notes: 1.1 B/D OA 200 280 270 270 Well 017-04 Type Inj. W TVD 3,470' Tubing 244 242 241 241 Interval 4 P.T.D. 2101530 Type test P Test psi 1,500 Casing 823 1,650 1,623 1,615 P/F P Notes: 1.1 B/D OA 200 280 280 280 Well 0111-01 Type Inj. W TVD 3,486' Tubing 417 416 416 416 Interval 4 P.T.D. 2101060 Type test P Test psi 1,500 Casing 334 1,647 1,627 1,617 P/F P Notes: 1.8 BID OA 210 240 220 220 Well 0113-03 Type Inj. W TVD 3,529' Tubing 458 458 458 458 Interval 4 P.T.D. 2111000 Type test P Test psi 1,500 Casing 364 1,654 1,648 1,647 P/F P Notes: 3.2 B/D OA 200 200 200 200 Well 0115-S4 Type Inj. W TVD 3,675' Tubing 458 458 458 458 Interval 4 P.T.D. 2111410 Type test P Test psi 1,500 Casing 613 1,651 1,642 1,640 P/F P Notes: 2.5 B/D pumped OA 260 270 270 270 Well 0120-07 Type Inj. W TVD 3,310' Tubing 431 - 431 431 431 Interval 4 P.T.D. 2111400 Type test P Test psi 1,500 Casing 1,173 1,651 1,693 1,692 P/F P Notes: 1.5 B/D OA 240 240 240 240 Well 0124-08 Type lnj. W TVD _ 3,498' Tubing 449 448 448 448 Interval 4 P.T.D. 2111300 Type test P Test psi 1,500 Casing 488 1,673 1,660 1,655 P/F P Notes: 2.7 B/D OA 200 200 200 200 TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT NIK SI 12-09-16.xls • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,December 28,2016 TO: Jim Regg P.I.Supervisor Ql e r Z1 zgI fio SUBJECT: Mechanical Integrity Tests ( ENI US OPERATING CO INC 0I20-07 FROM: Jeff Jones NIKAITCHUQ 0120-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J —� NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ 0120-07 API Well Number 50-029-23459-00-00 Inspector Name: Jeff Jones Permit Number: 211-140-0 Inspection Date: 12/9/2016 Insp Num: mitJJ161212130603 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min I we'll 0120-07 rType Inj W 'ITVD 3345 Tubing 431 7 431 431 431 PTD 2111400 (Type Test SPT1Test psi 1500 • IA I 1173 1 1695 - 1693 , 1692 - Interval 4YRTST Pah' P -' OA i 230 240 -! 240 - 240 Notes: 1.5 barrels diesel pumped. 1 well inspected,no exceptions noted. SCANNED APR 0 $ 201,7 Wednesday,December 28,2016 Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. sC _J 1 - J 4-.Q Well History File Identifier Organizing (done) Two-sided ❑ Rescan Needed R AN: OVERSIZED: NOTES: V °' Items: ❑ ps: Grayscale Items: Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: {a- Date: 3:79.21 'LI. /s/ IldP Project Proofing BY: AIM Date: 1 (:)...8. �U / /s/ (/11 f Scanning Preparation 7 x 30 = al + a .3 = TOTAL PAGES 3 r (Count does not include cover sheet)BY: Maria Date: J .3'JILt. /s/ Production Scanning Stage 1 Page Count from Scanned File: x,'39' (Count does include cover heet) Page Count Matches Number in Scanning Praration: YES NO BY: Maria Date: g/a2J1Lt. /s/ 144f) Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. 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D pOj O N V w coz d (0 U Q OIZp - p } ;111g i i , RECEIVED MA R262l114 3 . 0211- 140 �40Tp _tom( it I' INAL SVP%VE Y Guhl, Meredith D (DOA) From: Maugeri Giuseppe [Giuseppe.Maugeri@enipetroleum.com] Sent: Monday, March 24, 2014 1:11 PM To: Guhl, Meredith D (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: Final Definitive Survey required Nikaitchuq 0120-07, PBI and PB2 Attachments: 0120-07PB1 ASP Final Survey.xlsx; 0120-07PB2 ASP Final Survey.xlsx; 0120-07 ASP Final Survey.xlsx Dear Mrs. Guhl, Here the surveys requested. I'll send you a cd with those survey tomorrow. Best regards, Giuseppe Maugeri Completion Engineer Eni Petroleum Office: (907) 865-3328 Cell: (907) 947-9110 Email: giuseppe.maugeri@enipetroleum.com 3800 Centerpoint Drive, Anchorage, AK, USA From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Friday, March 07, 2014 11:45 AM To: Maugeri Giuseppe Cc: Davies, Stephen F (DOA) Subject: Final Definitive Survey required Nikaitchuq OI20-07, PB1 and PB2 Dear Mr. Maugeri: I am completing the final compliance review for Nikaitchuq 0120-07, PTD 211-140,API 50-029-23459-00-00,completed on 7/31/12. As required by Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.050 the operator shall file with the Commission (d)... a complete digital copy of each inclination and directional survey not previously filed must be filed with the commission in a format acceptable to the commission. At this time an ASCII or Excel version of the final definitive survey is required for 0120-07, 0120-07 PB1 and 0120-07 PB2. We have received PDF and paper copies of those surveys. Please provide the requested survey files on a CD by April 7, 2014. If you have any questions, please contact me. Sincerely, 1 Meredith Guhl Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907) 793-1235 This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 2 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Friday, March 07, 2014 11:45 AM To: 'giuseppe.maugeri@enipetroleum.com' Cc: Davies, Stephen F (DOA) Subject: Final Definitive Survey required Nikaitchuq 0120-07, PB1 and PB2 Dear Mr. Maugeri: I am completing the final compliance review for Nikaitchuq 0120-07, PTD 211-140,API 50-029-23459-00-00,completed on 7/31/12. As required by Statute AS 31.05.030(d)(2)(B)and Regulation 20 AAC 25.050 the operator shall file with the Commission (d)... a complete digital copy of each inclination and directional survey not previously filed must be filed with the commission in a format acceptable to the commission. At this time an ASCII or Excel version of the final definitive survey is required for 0120-07,0120-07 PB1 and 0120-07 PB2. We have received PDF and paper copies of those surveys. Please provide the requested survey files on a CD by April 7,2014. If you have any questions, please contact me. Sincerely, Meredith Guhl Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907)793-1235 1 STATE OF ALASKA ALAJrvA OIL AND GAS CONSERVATION COMMIaSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Developme t Ll Exploratory ❑ GINJ ❑ WINJ 2. WAG El WDSPL El No.of Completions: &4v1 Service Z*3\IStratigraphic Test ❑ 2.Operator Name: 5.Date Com usp.,or 141+ 12.Permit to Drill Number: ENI US Operating Co.Inc. Aband.:( 012 211-140 3.Address: 6.Date Spudded: 13.API Number: Z 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 6/14/2012 50-029-23459-00-00• • 1$ 4a.Location of Well(Governmental Section): •7.Date TD Reached: 14.Well Name and Number: oat ti Surface: 3141.3 FSL 1682.3 FEL S5 T13N R9E UM 7/19/2012 0120-07. x Top of Productive Horizon: 8.KB(ft above MSL): 53.2• 15.Field/Pool(s): 502 FSL 1308 FEL 36 T14N R8E UM GL(ft above MSL): 12.2 Total Depth: 9.Plug Back Depth(MD+TVD): Nikaitchuq/Schrader Bluff Oil Pool. 4111 FSL 2056 FEL 35 T14N R8E UM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 516597.99 _ y-6036494.32 Zone- 4 18,952'MD/3,142'TVD• ADL 355024,373301,391283,388577 TPI: x- 506535.65 y-6039119.39 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 500505.06 y-6042724.46 Zone- 4 N/A ADL 417493 18.Directional Survey: Yes IJ No LJ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MDITVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 2,348'MD/1,964'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: GR/RES/NEU/Den/Sonic/ 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 20 178.89 X-65 37 160 37 160 Driven N/A N/A 13.375 68 L-80 35 2759 35 2135 16 10.7 ppg ASL: 557 bbls N/A 12.5 ooa LiteCRETE:63 bbls 9.625 40 L-80 33 11830. 33 3516 -• 12.25 12.5 ppg LiteCRETE:204 bbls N/A 4.5 11.6 L-80 11601 17164 • 3355 3339 • 8.75 Blank Liner with ICD's N/A ' 7G-/,z„3 24.Open to production or injection? Yes 2/ Nod ., If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): 1 SIZE DEPTH SET(MD) PACKER SET(MD/TVD) /I 83�i - 11•1(oY ' rt u (/ivI. 5( PF�S� 4.5 11630 11,471'MD/3,345'TVD � w 35/4,' - ' 3 3`(' • ?IT26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. _,.Dunk-TIN 'M` ,. n DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1 !a Ill 7,.. , w_AriAtir 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A N/A Test Period N/A N/A N/A N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: , Water-Bbl: Oil Gravity-API(corr): Press. N/A N/A 24-Hour Rate -. N/A N/A N/A N/A 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No Q. 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. RECEIVED SEP 0 4 2012 RE3®MS SEP 0 4 201.....41E121_. AOGCC Form 10-407 Revised 12/2009 >'Ka 10311 CONTINUED ON REVERSE lb-Zo /3 Submit original only • 29. GEOLOGIC MARKERS (List all formations and markers encountered): + 30. FORMATION TESTS NAME MD TVD Well tested? U Yes Ld\lo If yes,list intervals and formations tested, Permafrost-Top surf surf briefly summarizing test results.Attach separate sheets to this form,if SV4 719 715 needed,and submit detailed test information per 20 AAC 25.071. SV3 982 958 SV2 1282 1216 SV1 1955 1711 Permafrost-Base 2348 1964 Ugnu Top 2350 1965 UG-2 Coal Bed Marker 4339 2428 Lower Ugnu 8839 3007 Schrader Bluff Top 10377 3220 N Sequence Top 10536 3238 N top 10884 3278 N bottom 11488 3347 N Sequence base 11555 3352 OA sand top 12229 3402 OA sand bottom 17871 3365 OA top 18155 3324 N Sequence base 18417 3264 N bottom 18674 3202 N top 18813 3174 Formation at total depth: OA sand 16461 3418 31. List of Attachments: Directional Survey,As Run Wellbore Schematic,Well Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Michele Cesari Printed Name: Davi e Simeone Title: Well Operation Project Manager Signatur : Phone: (907)865-3338 Date: 8/27/2012 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 12/2009 a) 0 0 C Z s c a U , CO VN , 9 0 " d N d F- CD LIJ -0 ILO W tl; N = c CD a) L N J M UG. el C VA 0 CU c6 eL � }' ( e�- m (_) > — r (,.) 1C "le' N Iv 4a7 0) o •�o c o > � 0 N Q) X D •c> ` V1 N 01 o _1 a) o cinN ;DLam U (6 4- E a) o 0 c 0 2 U IN M c0 +.+ N Mt x a n x _ : REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 Oliktok fiOLIKTOK yob Point INTAKE DOCK Opp THIS I MODULE . PIS P� ? _ SURVEY rk _O �pr��� ..\ DS-3R Q DEW UrJ E 9'' /416 , , sITE ........ STP I , OUKTOK POINT MODULES I NOC STAGING AREA',. T13N, R9E , DS-30 I �� 10 ,1 �. • 'O 15 1" SCALE: r---)150' �+ r� DS=30 19r. _ i 21� A �p l �' r \ STP PA3VICINITY MAP oo \'� SCALE: 1" = 1 Mile 0 o 3?-.0 `. o�000 °o o 1 o\a\ ,.\\\ \ 0000'o (513r co�� oQ 0-0 o 90'3 090'3 Oc)v' o -O00 ' \O\c*\ p -O oi�O � S Gm ,� 1 Z / 0 \ 2 OLIKTOK 0-0 POINT PAD \ \ o� \ ,-Ds \ \\ to l `IA \ \ i \ \ SEE SHEET 3 FOR NOTES / \ \\ Existing Conductor ^ LOUNSBURY / 0 & ASSOCIATES, INC. • Conductor Asbuilt this survey / SURVEYORS ENGINEERS PLANNERS 141)/ AREA: MODULE: UNIT: AtIi • IL Enu PetFolleum OLIKTOK POIINT OR NT PAD WELL COBrill ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: I PART: REV: LK680D1 10/9/08 NSK 6.80-d1 1 OF 3 I 2 REV DATE BY CK APP DESCRIPTION REV DATE , BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 PROTRACTED SECTION 5, T. 13 N., R. 9 E., UMIAT MERIDIAN AK STATE PLANE(NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD 0.G. WELL NO. 'y' 'x NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP-11 6,036,332.70 1,656,791.89 70°30'39.015" 149°51'57.587" 2,052 1,519 12.1 4.0 OP-12 6,036,328.85 1,656,784.83 70°30'38.977" 149°51'57.795" 2,056 1,526 12.2 4.0 0P03-P05 6,036,325.10 1,656,777.76 70°30'38.940" 149°51'58.004" 2,059 1,533 12.2 4.0 0PO4-P07 6,036,321.43 1,656,770.69 70°30'38.904" 149°51'58.212" 2,063 1,541 12.2 3.8 OP05 6,036,317.71 1,656,763.67 70°30'38.868" 149°51'58.419" 2,067 1,548 12.2 3.7 OP06 6,036,313.96 1,656,756.55 70°30'38.831" 149°51'58.629" 2,070 1,555 12.2 3.6 OP07 6,036,306.41 1,656,742.45 70°30'38.757" 149°51'59.045" 2,078 1,569 12.2 3.5 OP08 6,036,302.66 1,656,735.36 70°30'38.720" 149°51'59.254" 2,082 1,576 12.2 3.5 OP09 6,036,298.90 1,656,728.32 70°30'38.683" 149°51'59.462" 2,085 1,583 12.2 3.5 OP10 6,036,295.16 1,656,721.26 70°30'38.647" 149°51'59.670" 2,089 1,590 12.2 3.7 OP11 6,036,291.38 1,656,714.21 70°30'38.610" 149°51'59.878" 2,093 1,597 12.2 3.8 OP12 6,036,287.63 1,656,707.14 70°30'38.573" 149°52'00.086" 2,097 1,604 12.2 4.0 OP13 6,036,276.37 1,656,685.97 70°30'38.463" 149°52'00.711" 2,108 1,626 12.2 3.6 OP14 6,036,272.66 1,656,678.89 70°30'38.426" 149°52'00.920" 2,112 1,633 12.2 3.5 OP15 6,036,268.88 1,656,671.79 70°30'38.389" 149°52'01.129" 2,115 1,640 12.2 3.4 OP16 6,036,265.11 1,656,664.75 70°30'38.353" 149°52'01.337" 2,119 1,647 12.2 3.3 OP17 6,036,261.36 1,656,657.70 70°30'38.316" 149°52'01.545" 2,123 1,654 12.2 3.2 OP18 6,036,257.62 1,656,650.62 70°30'38.279" 149°52'01.753" 2,127 1,681 12.2 3.1 OP19 6,036,250.09 1,656,636.50 70°30'38.205" 149°52'02.170" 2,134 1,675 12.2 2.5 OP20 6,036,246.31 1,656,629.41 70°30'38.168" 149°52'02.379" 2,138 1,682 12.2 2.2 OP21 6,036,242.57 1,656,622.39 70°30'38.132" 149°52'02.586" 2,141 1,689 12.2 1.9 OP22 6,036,238.82 1,656,615.39 70°30'38.095" 149°52'02.793" 2,145 1,696 12.2 1.7 OP23 6,036,235.05 1,656,608.27 70°30'38.058" 149°52'03.003" 2,149 1,703 12.2 1.5 OP24 6,036,231.36 1,656,601.27 70°30'38.022" 149°52'03.209" 2,153 1,710 12.2 1.3 • DISPOSAL WELLS AK STATE PLANE (NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD 0.G. WELL NO. 'y' ')C NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP25 6,036,004.35 1,656,510.91 70°30'35.791" 149°52'05.885" 2,380 1,802 12.2 -2.7 OP26 6,036,012.10 1,656,525.47 70°30'35.867" 149°52'05.456" 2,372 1,787 12.2 -2.7 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: 111=2 Broil PcieiroOeum OLIKTWELL OCONDUCTOR K POINT D Cif ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80-d1 2 OF 3 2 REV DATE BY CK APP DESCRIPTION REV_ DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductos 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 NOTES 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, NAD 83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD 83. 3. BASIS OF LOCATIONS ARE DERIVED FROM OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 5, TOWNSHIP 13 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 5. ALL ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. SEE LOUNSBURY DOCUMENT L-2539 FOR NAD27 INFORMATION. �4• �� OF q�-9t++i Ar SURVEYOR'S CERTIFICATE • �, : rt j$ I HEREBY CERTIFY THAT I AM PROPERLY i h REGISTERED AND LICENSED TO PRACTICE 0 /,•• .,. �• LAND SURVEYING IN 77-IE STA 7E OF ROOKUS rALASKA AND THAT THIS PLAT REPRESENTS %=V ' frJ S-803 „. _ A SURVEY DONE BY ME OR UNDER MY JQ-,� DIRECT SUPERVISION AND 7NA T ALL p.42.1ND ,,, ,�'Pio:)* DIMENSIONS ASND 07HER DETAILS ARE OF DECEMBER 23, 2008. +,,1h"`sr.*��• 0LOUNSBURY . & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: ita •En!' Peur01'euiOLIKTOK POINT WELL C D CONDUCTOR Eno ASBUILT LOCATIONS _ CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80-di 3 OF 3 2 11* Eni E&P Division .} !Well Name:0120-07 EN!Petroleum Co.Inc. Daily Report Well Code:26484 Field Name: Nikatchuq • APIIUWI:50-029-23459-00-00 2�, Date:6/12/2012 - Report#: 1 'f ��11 page 1 of 1 wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5.924.40 970.78 5.504.08 245.06 22.5 -1.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0,00 86.0 -0.6 Overcast WC 21' NE @ 9.2 MPH Daily summary operation 24h Summary Rig move to 0120-07-N/U Starting head and drilling riser Operation at 07.00 Loading pipe shed with DP and BHA,prepare to pick up pipe 24h Forecast Complete to R/U Katch-Kan-Load pipe shed-P/U and M/U 5"DPs Std-Mix spud mud-Pre-spud Safety meeting-P/U and M/U BHA#1-Wash out 20"C.P.-M/U BHA#2-Spud well 0120-07 Lithology Shows MAASP(kgflcm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan _ Oper.Descr. 00-.00 07.00 i 7.00 7.00 MOB A 2 P Secure well-Move cuttings box and continue preparing for rig move-Set ng mats-C/O brake bands on draw works- Swap power-RID inner connection-Jack up drill module and move to end of well bay 07.00 10.00 ' 3.00 10.00 MOB A 20 P Clear pad of old ng mats and herculite-Breakup ice and clean to level pad 1000 19'00 - 9.00- 19.00 MOB A 2 P Lay herculite-Set ng mats-Spot/center sub module over well 0120-07-Set sub on mats and check level-Spot utility module to sub and marry up-Set on mats and check level 19.00 00,00 5.00 i 24.00 MOB C 5 P N/U starting head and pressure test to 500 psi x 10 min-N/U drilling riser,flow and fill-up lines-Set and connect CCB- Instat Katch-Kan in progress Daily Contacts Position Contact Name Company Title E-mail Office _ Mobile Eni representative Ben Perry iEni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Drlg Spvr. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Ken Bogner Eni Petroleum Materials Coordinate Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X65 0.00 48.77 6/12/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(g(L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division Well Name:0120-07 Iffi* ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq •ii Date:6/13/2012 - Report#: 2 APIIIJWI:50-029-23459-00-00 2" " page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator EM Share)%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00. 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 0.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 84.0 2.2 Clear WC 28" NE @ 11.5 MPH Daily summary operation 24h Summary P/U and M/U 5"DPs Std-Mix spud mud Operation at 07.00 P/U and MJU BHA#1 24h Forecast Complete to P/U and M/U 5"DPs Std-Pre-spud Safety meeting-P/U and M/U BHA#1-Wash out 20"C.P.-M/U BHA#2-Spud well 0120-07 Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1048.5 Time Log Start End Cum Time Time Our(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 '04:30 4.50 4.50 PREP M 5 'P Complete to install Katch-Kan and R/U CCB-Load pipe shed with 381 Jts 5"DP-Pull bushings and set mouse hole in rotary table 04:30 06:30 2.00 6.50 DRILL E 5 P P/U,M/U and R/B stands of 5"DPs 06:30 07:30 1.00 7.50 DRILL E -25 TR99 Troubleshoot:Repair iron roughneck(replace spinner roller) 07:30 '22:00 14.50 22.00 DRILL E '5 •P P/U,M/U and R/B stands of 5"DPs 22:00 22:30 0.50 22.50 DRILL E 25 P Service and inspect skate,draw works and iron roughneck 22:30 00.00 1.50 24.00 DRILL E 5 P P/U,M/U and R/B stands of 5"DPs(102 Std in Demck]In progress-Mix spud mud Daily Contacts Position Contact Name Company Title _ E-mail _ Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907.685-1493 Eni representative Mirko Musumeci Eni Petroleum Drlg Spur. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Cnswet Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X65 0.00 48.77 6/12/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P Lea kOff(kgf/cm') ill* Eni E&P Division I Well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • Date:6114/2012 - Report#: 3 APIIUWI:50-029-23459-00-00 2" 'r II page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 402100 ENI PETROLEUM 100.00,HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 1.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 217.63 216.04 168.86 4.33 39.0 91.0 4.4 Clear WC 37' NNE @ 5 MPH Daily summary operation 24h Summary Complete to P/U and M/U 5"DPs Old-Pre-spud Safety meeting-P/U and M/U BHA#1-Wash out 20"C.P.-M/U BHA#2-Spud well 0120-07-Drill 16"section to 714' Operation at 07.00 Drill 16"section to 970' 24h Forecast Dell 16"section as per wellplan(TD @ 2764') Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1072.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 DRILL E 5 P P/U,M/U and R/B stands of 5"DPs[127 Std in Derrick]-Mix spud mud 03:30 04:00 0.50 4.00 DRILL E 25 P Rig service 04:00 06:00 2.00 6.00 DRILL E 5 P P/U and M/U BHA#1[16"Hughes MX-1(s/n 5212127)Jets 3x20,1016(TFA=1.116)+PDM(1.83 bend)+NM Stab+XO( -Fill hole with spud mud-Check all lines and mud system for leaks 06:00 07:00 1.00 7.00 DRILL E 6 P Wash and ream 20"C.P.to 160'(550 gpm @ 500 gpm/40 rpm @ 0.8k ftlbs)-POOH BHA#1 07.00 '09:30 2.50 9.50 DRILL E 5 P P/U BHA#2(16"Hughes MX-1(s/n 5212127)Jets 3x20,1x16(TFA=1.116)+PDM(1.83 bend)+NM Stab+2x NM X0+ Gyro Pulse collar+8"PowerPulse+ARC 825+UBHO+NM Stab+NMDC+X0+x 2 Std HWDP(-Set Gyro tool on collar and orient tools 09:30 13:00 3.50 13.00 DRILL E 3 P Held Pre-Spud Safety Meeting with all parts involved-Spud well 0120-07 @ 10:00 hrs-Drilling Sliding 0 16"section f/160' 1/336'1500 gpm @ 650 psi\WOB=20+25k lb\Up wt 80k lb-Dw wt 80k lb-Rot wt 80k lb\Mud wt=8.7 ppg-Take survey every 30' 13:00 14:00 1.00 14.00 DRILL E 5 P P/U and R/B x2 Std HWDP-P/U and M/U x2 DCs+Float+Jar(WTF s/n 14171141) 14 00 00:00 10.00 24.00 DRILL E 3 P Drilling Rotary/Sliding 0 16"section f/336'1!714'\500?450 gpm @ 6507880 psi\WOB=20+30k lb\Up wt 90k lb-Dw wt 85k lb-Rot wt 85k lb\Mud wt=8.8 ppg-Take survey every 30' [ART=0.33-AST.4 hrs-JAR=93.3 hrs] NOTE: Took survey frequently and review directional plan several times to avoid anti collision boundaries-No hard line crossed Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirka Musumeci Eni Petroleum Ddg Spot. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Dulling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Dulling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X65 0.00 48.77 6/12/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') r. * Eni E&P Division [Well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • API/UWI:50-029-23459-00-00 2^ii Date:6115/2012 - Report#: 4 I' II page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 2.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 807.72 645.19 590.09 13.65 43.2 91.0 8.9 Clear WC 48` ENE @ 6MPH Daily summary operation 24h Summary Drill 16"section f/714'02630' Operation at 07.00 Clean up cycle @ 2.600' 24h Forecast Drill 16"section to TD(2770'MD-2166'ND)-Clean up cycle-BROOH-POOH and LID BHA#2-13 3/8"casing hanger dummy run-R/U csg running equipment-13 3/8"Csg job-Condition mud-13 3/8"Cement job Lithology Shows MAASP(kgflem') Mud Weight(gIL) 1072.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 DRILL E -3 P Drilling Rotary/Sliding 0 16"section(/714'01102'\4507500 gpm @ 88071000 psi\40 rpm @ 2.5'-4k ft-lbs\WOB 10+28k lb\Up wt 956 Ib-Dw wt 88k lb-Rot wt 90k lb\Mud wt=8.9 ppg-Take survey as needed 06:00 12:00 6.00 12.00 DRILL E 3 P Drilling Rotary/Sliding 0 16"section 81102'V1600'15007600 gpm @ 1000?1300 psi\40 rpm @ 3.5.4k Bibs\WOB 10.35k lb\Up wt 100k lb-Dw wt 90k lb-Rot wt 95k lb\Mud wt=8.9 ppg-Take survey as needed 12:00 18:00 6.00 18.00 DRILL E 3 P Drilling Rotary/Sliding 0 16"section f/1600'5/2117'1600 gpm @ 130071400 psi/40 rpm @ 4.56 Nibs\WOB 5.30k lb\Up wt 120k lb-Dw wt 90k lb-Rot wt 100k lb\Mud wt=9.2 ppg-Take survey every Std-Back ream full Std every connection 18:00 00:00 6.00 24.00 DRILL E 3 P Drilling Rotary/Sliding 0 16"section 1/2117'5/2630'\600?700 gpm @ 140071800 psi\40 rpm @ 5+6k Nibs\WOB 5.30k lb\Up wt 125k lb-Dw wt 90k lb-Rot wt 100k lb\Mud wt=9.2 ppg-Take survey every Std-Back ream full Std every connection [ART=4.06-AST=9.59 hrs-JAR=13.42 hrs] Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Eni representative James Thompson Eni Petroleum Sr.Dig.Spur. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Dig Spur. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Drilling 'Tool Pusher 907-670-1492 Toot Push Brian Tiedemann Nabors Alaska Dolling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X65 0.00 48.77 6/12/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') ifi* Eni E&P Division I Well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq API/t1Wl:50-029-23459-00-00 2^ 11 Date:6/16/2012 - Report#: 5 II II page 1 of 1 Wellbore name: 0120707 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mihr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 3.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 844.30 660.21 36.58 1.41 25.9 92.0 5.6 Overcast WC 35` NW @ 14 MPH Daily summary operation 24h Summary Drill 16"section to TD(2770'MD-2166'TVD)-Clean up cycle-BROOH-POOH and UD BHA#2-13 3/8"casing hanger dummy run-R/U csg running equipment Operation at 07.00 RIH 13 3/8"Csg @ 593' 24h Forecast Complete to R/U csg running equipment-13 3/8"Csg job-Condition mud-13 3/8"Cement job Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1072.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 -02:00 2.00 2.00 DRILL E 3 P Drilling Rotary/Sliding 0 16"section 1/2630'1/2770'/700 gpm @ 1800?1950 psi\40 rpm @ 4.5+5.5k ft'lbs\WOB 5+35k lb \Up w1125k lb-Dw wt 90k lb-Rot wt 100k lb\Mud wt=9.4 ppg-Take survey as needed-Back ream full Std every connection [ART=1.02-AST=0.39 hrs-JAR=108.1 hrsj 02:00 04.00 2.00 4.00 DRILL E '7 P Clean up cycle:Circulate x3 BU(800 gpm @ 1700 psi-80 rpm @ 4.5 albs)Rack back e1 Std each BU(/2770'1/2500' 04:00 12:30 8.50 12.50 DRILL E 6 P BROOH f/2500'1/253'(800 gpm @ 170071200 psi-80 rpm @ 4.571k ft'lbs) 12:30 13:00 0.50 13.00 DRILL E 7 P Circulate hole clean(800 gpm @ 1200 psi-80 rpm @ 0.8k ft'lbs) 13:00 14:30 1.50 14.50 DRILL E 6 P RIH on elevator(253'02770'-No fill on bottom-Worked trough tight spot @ 562'(150 gpm-20 rpm) 14:30 16:30 2.00 16.50 DRILL E 7 P Circulate and condition mud(700 gpm @ 1350 psi-60 rpm @ 4.5k S'lbs) 16:30 18:30 2.00 18.50'DRILL E 4 P POOH on elevators 1/2770'0253'-No tight spots encountered 18:3021:30 3.00 21.50 DRILL E 5 P POOH and UD BHA#2(1-1-WT-A-E-1-NO-TD) 21:30 22:00 0.50 22.00 DRILL G 19 P 13 3/8"casing hanger dummy run 2200 00.00 2.00 24.00 DRILL G .2 P R/U 13 3/8"casing running equipment-In progress Daily Contacts _ Position Contact Name Company Title E-mail Office Mobile Eni representative James Thompson Eni Petroleum Sr.Ddg.Spvr. '907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinate Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Drilling 'Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CONDUCTOR 20 18.250 X65 0.00 48.77 6/12/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') Eni E&P Division 'Well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • APIIUWI:50-029-23459-00-00 2^o Date:6/17/2012 - Report#: 6 �I II page 1 of 1 wellbore name: 0120-07 Well Header PermiliConcession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(IVO...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 4.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 844.30 660.21 0.00 89.0 3.3 Clear WC 33" SSE @ 7 MPH Daily summary operation 24h Summary Complete to R/U csg running equipment-13 3/8"Csg job-Condition mud-13 3/8"Cement job-R/D running equipment-N/D Riser in progress Operation at 07.00 N/U WellHead @ 0400 24h Forecast N/D Riser and starting head-N/U compact wellhead and test-N/U BOP Stack-BOP Test-Set wear bushing-M/U BHA#3 Lithology Shows MAASP(kgflcm°) Mud Weight(g/L) 1114.4 Time Log _ Start End Cum Time Time Dur(hr) Due(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL G 2 P Complete to R/U 13 3/8"casing running equipment 00.30 09:30 9.00 9.50 DRILL G 5 P PJSM-P/U,M/U Shoe track w/Baker Lock-Check float equipment-P/U,M/U&RIH Casing 13 3/8"68#L80 BTC(7k fl'lbs M/U torque)V2760'-Fill each Jt on fly,top off every 10 Jt-Proper displacement-M/U Hanger and Landing Jr- Remove casing slip and land hanger (Shoe @ 2760'-Float Collar @ 2680'-Up v4 210k lbs,Ow wt 140k lbs] 09:30 12:30 3.00 12.50 DRILL H 7 P Circulation to condition mud for cement job(1?5.5 bpm @ 200 psi)YP=17 MW=9.4 ppg-No losses 12:30 15:00 2.50 15.00 DRILL H 2 P L/D circulating tool-R/U cement head and load with two plugs(witness by ENI and SLB rep)-Prepare for cement job- Held PJSM 15:00 16:00 1.00 16.00 DRILL H 25 TS03 Troubleshoot:Fix flowmeter on Slb pumping unit 16:00 20:30 4.50 20.50 DRILL H 9 P SLB pump 10 bbl Mud Push 11 and test lines to 3700 psi-SLB pump 90 bbl Mud Push II @ 10.1 ppg(5 bpm @ 300 psi)- Drop Bottom Plug-SLB mix and pump 557 bbl Lead Slurry @ 10.7 ppg(Class Artic Set Lite 1345 sacks.2.35 Yield mix • fluid 10.611 gaVsk)(5 bpm @ 450 psi)-Followed by 63 bbl Tail Slurry @ 12.5 ppg(LiteCRETE 250 sacks,1.57 Yield,mix SO` ,/ fluid 5.494 gaVsk](3 bpm @ 200 psi)-Drop Top Plug-SLB pump 10 bbl water-Switch to Rig Pump and Displace with 386 µI bbl @ 9.4 ppg mud(5.5 bpm @ 160?420 psi)-[Bump plug @ 20:30]-Pressure casing up to 900 psi(500 psi over FCP)- G Release pressure and check float equipment-No losses during job-Recovered 100 bbl lead slurry on surface 20:30 22.30 2.00 22.50 DRILL H 5 P R/D and L/D cement head-Back out and L/D Landing Jt-R/D Casing handling and cementing equipment 22:30 00.00 1.50 24.00 DRILL C 5 P R/D KatchKan,mouse hole,flow lines-N/D Riser and starting head-In progress Daily Contacts Position I Contact Name Company 1 Title E-mail Office Mobile Eni representative James Thompson Eni Petroleum Sr.Ddg.Spur. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Drlg Spur. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter .907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Dnlling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 • Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff)kgflcm') Eni E&P Division I Well Name:0120-07 Pi* EN!Petroleum Co.Inc. Daily Report Well Code:26484 Field Name: Nikatchuq e Date:6/18/2012 - Report#: 7 API/LMA:50-029-23459-00-00 en[I page 1 of 1 wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 5.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 844.30 660.21 0.00 89.0 15.0 Light Rain WC 59' WSW @ 13 MPH Daily summary operation 24h Summary N/D Riser and starting head-N/U compact wellhead and test-N/U BOP Stack-BOP Test-Set wear bushing-M/U BHA#3 Operation at 07.00 Slip and cut drill line 24h Forecast RIH BHA#3 to float collar-Slip and cut DL-Circulate BU-Casing pressure test-Drill out float equipment,shoe and 20'new formation-Displace spud mud with LSND 9.2 ppg new mud-LOT-Drill 12 1/C section as per wellplan Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Decor. 00:00 02:30 2.50 2.50 DRILL C 5 P Complete to R/D KatchKan,mouse hole,flow lines-N/D Riser and starting head 02:30 08:30 6.00 8.50 DRILL C 5 P N/U Wellhead and valves-Pressure test Wellhead/Csg Hanger 5k psi 30 min 08:30 14:00 5.50 14.00 DRILL C 5 P N/U 13 5/8"Riser and BOP Stack-Install choke/kill lines,Bell nipple.Flow line,KatchKanO 14:00 15:00 1.00 15.00 DRILL C 5 P M/U 5"test Joint-Set test plug-Fill Stack and lines w/water-Purge air out of system 6G5 15:00 18:00 3.00 18.00 DRILL 'C 12 P Test BOP as per AOGCC requirements-Annular @ 250?2500 psi-Rams,choke manifold,floor and top drive valves @ 25073500 psi-Chart record-BOP test waived by AOGCC rep.Jeff Jones 18:00 19:00 1.00 19.00 DRILL C 5 P Set Wear Ring-L/D setting tool 19:00 20:00 1.00 20.00 DRILL E 25 P Inspect and maintenance TDS and Draw works 20:00 21:00 1.00 21.00 DRILL E 5 P L/D x4 Std HWDP5 21:00 00:00 3,00 24.00 DRILL E 5 P P/U,M/U and RIH BHA#3[Bit 12'''A'PDC Smith MDSi716 TFA:1.167(s/n JF9464)+Xceed900 wi float+Telescope+NM Stab+ARC 825+Roller Reamer+NMDC+NM Flex DC+AST+NM Flex DC+Float Sub+7 IA"Jar(s/n 1417-1141)+ x2 5"HWDP+x24 5"DPs+12 Z-Ghost Reamer] Daily Contacts Position Contact Name Company Title E-mail Office _ Mobile Eni representative James Thompson Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Drlg Spvr. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Dulling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') I If 9#41 E&P Division 'Well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • Date:6/19/2012 - Report#: 8 APIIUWI:50-029-23459-00-00 2" "11 page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL - Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 6.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,170.13 721.16 325.83 6.62 49.2 88.0 16.1 Clear WC 61 W @ 8 MPH Daily summary operation 24h Summary RIH BHA#3 to float collar-Circulate BU-Casing pressure test-Slip and cut DL-Drill out float equipment,shoe and 20'new formation-Displace spud mud with LSND 9.2 ppg new mud-LOT-Drill 12 1/4"section to 3839 Operation at 07.00 Drill 12''/."section @ 4,235' 24h Forecast Drill 12'/."section to planned TD(12063') Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01:30 1.50 1.50 DRILL E 4 P Shallow test-Down link Xceed-RIH on elevators 8/2672'(tag cement) 01:30 02:00 0.50 2.00 DRILL G 7 P Circulate BU reciprocating and rotating string till 9.25 ppg MW in/out(650 gpm @ 880 psi,45 rpm©5+7k ftlbs) 02:00 03:00 1.00 3.00 DRILL G 11 P Pressure test 13 3/8"Csg @ 2500 psi for 30 min(chart record) 03.00 05:00 2.00 5.00 DRILL E 25 P Slip and Cut 50'DL-Service breaks 08 00 09:00 4.00 9.00 DRILL E 3 P Drill out plugs,float equipment,shoe and cement 1/2672'8/2770'(650 gpm @ 880 psi,60 rpm @ 5+7k ft'lbs,WOB=2+10k lbs.MW=9.2+ppg) 09'00 09.30 0.50 9.50 DRILL E 3 P Drill rotary 0 12''/."new hole(/2770'5/2790'(650 gpm @ 880 psi 160 rpm @ 5+7k ftlbs 1 WOB 2+4k lb\Up wt 125k lb-Dw wt 70k lb-Rot wt 90k lb\Mud wt=9.2+ppg 0930 12:00 2.50 12.00 DRILL E 9 P Displace well to LSND 9.2 ppg reciprocating and rotating string(660 gpm @ 700 psi,60 pm @ 4k fldbs)-Clean shakers and trough pits-Circulate BU 9.2 ppg in/out(650 gpm @ 700 psi-60 rpm(§3k ft-lbs) 12 00 1300 1.00 13.00 DRILL E 11 P Rig up lines and perform LOT with 9.2 ppg LSND-Surface pressure of 377 psi-EMW=12.5 ppg-R/D testing equipment 13 00 18.00 5.00 18.00 DRILL E 3 P Drill rotary 0 12 7."new hole f/2790'8/3230'\720?820 gpm @ 850?1150 psi 1807110 rpm @ 4+5k ft-lbs\WOO 5+10k lb 1 Up wt=100k lb-Dwwt=80k lb-Rot wt=90k lb\Mud wt=9.2+ppg-Take survey as needed-Ream and wash 15'every connection 18 00 00 00 6.00 24.00 DRILL E 3 P Drill rotary 0 12'/."new hole 53230'8/3839'1820?900 gpm @ 115071400 psi\110?140 rpm @ 5+7k ftlbs\WOB 2+15k lb\Up w1=1101b-Dw wt=65k lb-Rot wt=85k lb\Mud wt=9.2+ppg-Take survey as needed-Ream and wash 15'every connection (ADT=6.62-JAR=6.62 Ors] Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative James Thompson Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907.685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') f. _* Eni E&P Division I Well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • APIIUWI:50-029-23459-00-00 2�II II,ii Date:6/20/2012 - Report#: 9 page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 7.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,617.27 778.03 447.14 18.47 24.2 87.0 14.4 Clear WC 58' SSW @ 9 MPH Daily summary operation 24h Summary Dell 12 1/4"section from 3.839'to 5,306'(2,552'TVD). Operation at 07.00 Drill 12°/."section @ 5415' 24h Forecast Drill 12 7."section to planned TD(12,063'). Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06 00 6.00 6_00 DRILL E 3 P Drill rotary 0 12 7."new hole 1/3839'1/4298'1900 gpm @ 1450 psi\120-140 rpm @ 6+7k flibs\WOB 8+12k lb\Up wt= 110k lb-Dw wt=65k Ib-Rot wt=85k lb\Mud wt=9.2 ppg\ECD=9.7 ppg-Take survey as needed-Ream and wash 15' every connection.Use Canrig Soft Torque. 06 00 12 00 6.00 12.00 DRILL E 3 P Drill rotary 0 12 7."new hole 1/4298'5/4322'1650-900 gpm©1270 psi 1160 rpm @ 7+8k fldbs\WOB 10+15k lb\Up wt= 115k Ib-Dw wt=65k lb-Rot wt=89k lb\Mud wt=9.2 ppg\ECD=9.72 ppg-Take survey as needed-Ream and wash 15'every connection.Use Canrig Soft Torque. 12 00 18:00 6.00 18.00 DRILL E V 3 -P Drill rotary 0 12 W new hole 1/4322'1/4797'1900 gpm @ 1650 psi 1160 rpm @ 7+11k Ribs\WOB 2+15k lb\Up wt=120k • lb-Dw wt=68k lb-Rot wt=88k Ib\Mud wt=9.2 ppg\ECD=10.12 ppg-Take survey as needed-Ream and wash 15' every connection.Use Canrig Soft Torque. Dulled Hard Spots from 4276'to 4280'8 from 4292'to 4345'. 18.00 00:00 6.00 24.00 DRILL E 3 P Drill rotary 0 12'/.°new hole 1/4797't/5306'(2552'ND)\900 gpm @ 1730 psi 1160 rpm @ 7+11k Ribs\WOB 5+15k lb\ Up wt=125k lb-Ow wt=65k b-Rot wt=90k lb\Mud wt=9.2 ppg\ECD=10.04 ppg-Take survey as needed-Ream and wash 15'every connection.Use Canrig Soft Torque. (ADT=18.47-JAR=133.2 hrs] Daily Contacts Position Contact Name Company Tide E-mail Office Mobile Eni representative James Thompson En:Petroleum Sr.Drlg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamadna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Bnan Tiedemann Nabors Alaska Dulling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') rifil* Eni E&P DivisionWell Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq 2^� Date:6/21/2012 - Report#: 10 APIIUWI:50-029-23459-00-00 If II page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N' Operator ENI Share)%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 8.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(`C) Weather Wind 1,734.92 793.40 117.65 20.81 5.7 81.0 5.6 Partly Cloudy WC NE @ 12 MPH 36' Daily summary operation 24h Summary DnII 12 1/4"section from 5.306'to 5,692'(2,603'TVD). Operation at 07.00 Drill 12 W section @ 5,905'. 24h Forecast Drill 12 114'section to planned TD @ 12,063'MD. Lithology 'Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 12.00 12.00 12.00 DRILL E 3 P Drill rotary 0 12''/."new hole(/5,306'115,557'1900 gpm @ 1780 psi\160 rpm @ 11.13k Ribs\WOB 10,15k lb\Up wt= 125k lb-Dw wt=65k lb-Rot wt=90k lb\Mud wt=9.2 ppg\ECD=9.87 ppg-Take survey as needed-Ream and wash 15'every connection.Use Canrig Soft Torque. Drilled Hard Spots from 5,392'to 5,422',from 5,451'to 5,467'&5,530'to 5,557'. 12 00 00 00 12.00 24.00 DRILL E 3 P Drill rotary 0 12 W. new hole Hard Spot f/5.557'85,692'(2.603'TVD)\700-900 gpm @ 1300-1820 psi\100-160 rpm @ 9=12k tlbs\WOB 5-20k lb\Up wt=130k b-Dw wt=58k lb-Rot wt=90k lb\Mud wt=9.2 ppg\ECD=9.9 ppg-Take survey as needed-Ream and wash 15'every connection.Use Caring Soft Torque. Varied flow rate from 700 to 900 gpm,RPM from 100 rpm to 160 rpm&WOB from 10k to 20k to maximize ROP. Note:more stick slip and level 3 shocks while dolling hard spot with 160 rpm and 20k WOB. IADT=20.81-JAR=154.01 hrsl. Daily Contacts Position Contact Name _ Company i Title E-mail Office Mobile Eni representative James Thompson Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamanna Eni Petroleum Ddg Spur. angelc.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Dnlling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgficm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 11* Eni E&P Division 'Well Name:0120-07 EN!Petroleum Co.Inc. Daily Report Well Code: 26484 Field Name: Nikatchuq • API/UWI:50-029-23459-00-00 2^nI1 Date:6/22/2012 - Report#: 11 no page 1 of 1 Wellbore name: 0120-07 Well Header PermiVConcession N° Operator EM Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72_ 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5.924.40 970.78 5.504.08 245.06 22.5 9.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,863.85 809.66 128.93 8.37 15.4 81.0 10.0 Clear WC 50` E @ 8 MPH Daily summary operation 24h Summary Drill 12 1/4"section from 5,692'to 6,115'-BROOH to 2,750'-CBU till shakers dean. Operation at 07.00 Cull out 5"DP with bad hard band. 24h Forecast POOH on elevators-cull out bad hard band 5"DP-L/D BHA#3-M/U BHA#4 with Smith insert bit-RIH to 6,115'-Drill 12 W section to planned TD @ 12,063'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 10:00 10.00 10.00 DRILL E 3 P Drill rotary 0 12 W new hole t/5,692'1/6,113'\750-900 gpm @ 1480-2080 psi\160 rpm @ 11+12.5k ftdbs\WO8 2+15k lb \Up wt=125k lb-Dw wt=62k lb-Rot wt=90k lb\Mud wt=9.2 ppg\ECD=9.98 ppg-Take survey as needed-Ream and wash 15'every connection.Use Canrig Soft Torque. Drilled Hard Spots(/5.705'1/5,710',85,922'1/5,926',(/6,039'1/6,046'8 f/6,105'86,113'. Note:At 6,113'ROP-1-2 ft/hr.Decided to POOH. 10:00 11:00 1.00 11.00 DRILL E 6 P BROOH 116,113'5/5,659'at 5 min/stand or as hole dictates.900 qpm/2020 psi/120 rpm/7-8k flips.No drag/tightspot. Monitor well for 10 min:Ok. 11:00 11:30 0.50 11.50 DRILL E 4 P Trip back in hole 1/5,659'86.113'.DwWt 65k.No problem. 11:30 12:30 1.00 12.50 DRILL E 4 P Doll rotary 0 12 W new hole 1/6,113'1/6,115'\750 gpm @ 1500 psi\160 rpm @ 12=13k ft'bs\WOB 10k lb\Up wt=125k lb.Increased RPM to 180 for 10 min:No change in ROP,slight increase in torque-14k ft'lbs. [AN=8.37-JAR=162.38 hrs). 12:30 23:00 10.50 23.00 DRILL E 6 P BROOH(/6,115'1/2,750'at 5 min/stand or as hole dictates.900 gpm/2100 psi/140 rpm/7-8k gibs.No dragltghtspot. 23:00 00:00 1.00 24.00 DRILL E 7 P CBU 2x bottoms up(shakers dean)@ 900 gpm 1 1500 psi/40-60 rpm/2-3k Sibs.Monitor well for 10 min:Ok. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative James Thompson Eni Petroleum Sr.Ddg.Spur. 907-685-1493 r Eni representative Angelo Lamarina Eni Petroleum Drlg Spur. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Dolling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgticm') 1 Ent E&P DivisionWell Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • 2^ofit* Date:612312012 - Report#: 12 API/UWI:50-029-23459-00-00 II page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 10.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 1,898.90 814.13 35.05 1.51 23.2 82.0 6.7 Clear WC 38° NE @ 13 MPH Daily summary operation 24h Summary CBU-POOH and UD 66 joints 5"DP-UD BHA#3-M/U BHA#4-RIH BHA#4 to 6,115'-Drill 12 1/4"section from 6,115'to 6,230'. Operation at 07.00 Drill 12'A"section @ 6,617'. 24h Forecast Drill 12'/."section to planned TD @ 12,063'MD. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E 7 P CBU(shakers clean)@ 900 gpm/1560 psi/40 rpm/2-3k fibs.Monitor well for 10 min:Ok. 00:30 01:00 0.50 1.00 DRILL E 4 P POOH on elevators wet from 1/2,750'8/2,500'.Pump dry job and install rubbers. 01:00 05:30 4.50 5.50 DRILL E 4 P POOH I/2,500'8/291'culling drill pipes with bad hard band.UD a total of 66 joints 5"DP+1 joint 5"HWDP. 05:30 09:00 3.50 9.00 DRILL E 5 P UD BHA#3.Bit dull 8-8-LT-A-X-2-WT-PR. -)Ghost Reamer-'A or more under gauge and large groove/step in the bottom. -)NMFC-Both NMFC had wear bad missing or damaged.Several spots with grooves cut in collar. -)Roller Reamer-Bottom 3-4 inches of stab body milled off. -)Xceed Stabilizer-upper stab missing 2/3 of tiles.Some milling on leading edge of blade as well. Lower Stab was gauged at 12 inches. 0900 10.30 1.50 10.50 DRILL E 1 P Change out MWD pressure sensor lines on ng floor.Bring bit,stabilizers and roller reamer to rig floor. 10:30 14.00 3.50 14.00 DRILL E 5 P Held PJSM.P/U BHA#4:Smith Insert bit 0 12 114"GF15B(s/n PX3949)with 3x 18/32"+lx 16/32"nozzles(TFA=0.942)+ Xceed 900(s/n CRSC-176)+Telescope(s/n GO385)+ILS NM stab+ARC 825(s/n E5102)+Smith Roller Reamer(s/n T81572)+NMDC+NM Flex DC+AST Tomax(s/n A90023)+NM Flex DC+Float sub+Weatherford 7 3/4"Hydraulic Jar (s/n 1417-1141)+XO+2x 5"HWDP.Total length=293.57'. 14:00 17:00 3.00 17.00 DRILL E 4 P RIH BHA#4 picking up 5"DP 1x1 from shed 1/293'8/2,397'. 17:00 18:00 1.00 18.00 DRILL E 25 P Service Top Drive,Drawworks and Blocks. 18:00 20:30 2.50 20.50 DRILL E 4 P Continue RIH BHA#4 with stands 5"DP 1/2,397'1/6,037'.Fill pipe every 20 stands. 20:30 21:00 0.50 21.00 DRILL E 4 P Break circulation and wash down 1/6,037 8/6,115'.Take survey 15'from bottom.Send downlink to Xceed. 21:00 00:00 3.00 24.00 DRILL E 3 P Drill rotary 0 12'A'new hole 1/6,115'816,230'\900 gpm @ 2300 psi\140 rpm @ 11.12k tt'lbs\WOB 20-30k lb\Up Wt= 130k lb-Dw wt=58k lb-Rot wt=88k lb\Mud wt=9.2 ppg\ECD=9.8 ppg-Take survey as needed-Ream and wash 15' every connection.Use Canrig Soft Torque. (ADT=1.51-JAR=163.9 hrs). Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative James Thompson Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drlg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Matenals Coordinato Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Dolling Tour Pusher '907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 4 Eni E&P Division ..} I Well Name:0120-07 EN!Petroleum Co.Inc. Daily Report` Well Code:26484 Field Name:Nikatchuq • Date:6/24/2012 - Report#: 13 APIIl1Wl:50-029-23459-00-00 e i ii - page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5.924.40 970.78 5.504.08 245.06 22.5 11.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(CC) Weather Wind 2,676.14 913.64 777.24 16.47 47.2 82.0 2.2 Fog WC 28" NNE @13 MPH Daily summary operation • 24h Summary Drill 12 1/4"section from 6,230'to 8,780'. Operation at 07.00 Drill 12''/."section @ 9,175' • 24h Forecast Drill 12'G"section to planned TD @ 12,063'MD. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 ' 12.00 12.00 DRILL E 3 P Drill rotary 0 12 7."new hole f/6,230'V7,469'1800-900 gpm @ 2180-2600 psi\140 rpm @ 12.13k gibs\WOB 5-25k lb I Up w1=130k lb-Ow wt=60k lb-Rot wt=90k lb I Mud wt=9.2 ppg I ECD=10.4 ppg-Take survey as needed-Ream and wash 30'every connection.Use Canng Soft Torque. 12:00 00:00 12,00 24.00 DRILL E 3 P 'Drill rotary 0 12'X'new hole(/7.469'V8,780'(2,995'TVD)\800 gpm @ 2300 psi 1 140 rpm©15.16k fibs\WOB 5-30k lb \Up wt=150k lb-Dwwt=55k lb-Rot wt=90k lb I Mud wt=9.2 ppg I ECD=10.4 ppg-Take survey as needed-Ream and wash 30'every connection.Use Canng Soft Torque. (ADT=16.47-JAR=180.36 hrs]. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Eni representative James Thompson Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamanna Eni Petroleum Drlg Spvr. angelo.lamanna@enipetroleum.corn 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Dulling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) TVD(mKB( Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 4 l $1.0 1 Eni E&P Division I Well Name:0120-07 I ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq •11 Date:6/25/2012 - Report#: 14 APIIUWI:50-029-23459-00-00 2" " page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession IT Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 12.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature('C) Weather Wind 2,802.64 933.54 126.49 4.78 26.5 84.0 2.2 Fog WC 32° NW @ 5 MPH Daily summary operation 24h Summary Drill 12 1/4"section from 8,780'to 9,195'-Schlumberger Xceed900 failure-BROOH to 2„683'-CBU. Operation at 07.00 L/D BHA#4. 24h Forecast CBU-POOH on elevators-cull out bad hard band 5"DP-L/D BHA#4-M/U BHA#5 with Smith insert bit-RIH to 9,195'-Drill 12 W section to planned TD @ 12,063'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:00 4.00 4.00-DRILL -E 3 -P -Drill rotary 0 12'/."new hole 1/8,780'U9,175'\800 gpm @ 2400 psi\140 rpm @ 16.18k ft'lbs\WOB 5-30k lb\Up wt= 155k lb-Dw wt=50k lb-Rot wt=98k lb I Mud wt=9.3 ppg\ECD=10.52 ppg-Take survey as needed-Ream and wash 30'every connection.Use Canrig Soft Torque. 04:00 09:00 5.00 9.00-DRILL -E 19 'TD01 'Schlumberger Tool failure:Xceed900(s/n CRSC-176)unable to keep tool face while drilling with normal parameters. Attempt to re-establish communication with the tool while drilling rotary 0 12 W new hole(/9,175'59,195'trying different parameters:tool works with max WOB 7k and RPM 60,giving max ROP of 2.5 to 7 FPH.Decided to POOH. [ADT=4.78-JAR=185.14 hrs]. 09:00 23:30 14.50 23.50'DRILL -E 6 'TD01 'BROOH 119,195'52,683'at 5 min/stand oras hole dictates.750 gpm/2200->1300 psi/140 rpm/12k->5k fl'Ibs.No drag/tightspot. 23:30 00:00 0.50 24.00 DRILL 'E '7 TD01 CBU lx bottom up @ 900 gpm/1760 psi/60 rpm/2-3k frlbs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative James Thompson Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division I Well Name:0120-07 fri* ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name: Nikatchuq • API/I/WI:50-029-23459-00-00 2�,r, Date:6/26/2012 - Report#: 15 '( II II page 1 of 1 Wellbore name: 0120-07 • Well Header Permit/Concession N° Operator ENI Share('A) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 13.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,810.87 935.01 8.23 2.00 4.1 86.0 5.0 Overcast WC 39' NNE @ 3 MPH Daily summary operation 24h Summary CBU-POOH and L/D BHA#4-Servire rig and TDS-Change saver sub-L/D 20 stands 5"DP with bad hard band-M/U BHA#5-RIH BHA#5 to 912'-Shallow test Schlumberger tools-RIH to 2,192'- Slip and cut 45'drilling line-RIH BHA#5 to 4.200'. Operation at 07.00 RIH,BHA#5 @ 7.453 24h Forecast RIH BHA#to 9,195'-Drill 12'''A"section to planned TD @ 12,063'MD. Lithology Shows MAASP(kgflcm') •Mud Weight(gIL) 1114.4 Time Log Start End Cum Time _ Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 DRILL E '7 'TD01 CBU(shakers clean)@ 900 gpm/1850 psi/60 rpm/2-3k ft'Ibs.Monitor well for 10 min:Ok. 00:30 01:00 0.50 1.00 DRILL E .4 'TD01 POOH on elevators wet from 1/2,683'V2,397'.Pump dry job. 01:00 '02:30 1.50 2.50 DRILL E 4 TD01 POOH 1/2,397 51292'. 02:30 '05:30 3.00 5.50 DRILL E 5 TD01 L/D BHA#4.Bit dull 1-1-CT-C-E-I-ER-DTF. 05:30 '08:00 2.50 8.00 DRILL 'E '1 "TD01 Clean Rig Floor and prepare to M/U BHA#5.Service TDS.Change out saver sub 8 tong dies on Top Drive.Grease gripper foot. 08:00 12:00 4.00 12.00 DRILL E '5 TD01 M/U mule shoe and RIH with 20 stands 5"DP with bad hard band.POOH and L/D same. 12:00 14:30 2.50 14.50 DRILL E 1 TD01 Clean rig floor.Load pipe shed with 60 joints of 5"DP and strap pipes.Prepare to P/U BHA. 14:30 17:00 ' 2.50 17.00 DRILL E 5 "TD01 Held PJSM.P/U BHA#5.Smith Insert bit 0 12 1/4"GF15B-ODVCPS(s/n PX2253)with 3x 20/32"+10 16/32"nozzles (TFA=1.116)+Xceed 900(s/n CRSC-148)+Telescope(s/n 00385)+ILS NM stab+ARC 825(s/n E5102)+8"NM Stabilizer+NMDC+2x NM Flex DC+Float sub+Weatherford 7 3/4"Hydraulic Jar(s/n 1417-1141)+XO+2x 5"H W DP. Total length=280.69'. 17:00 18:00 1.00 18.00 DRILL E 4 TD01 RIH BHA#5 picking up 5"DP 1x1 from shed 8280'1/912'. 18:00 18:30 0.50 18.50 DRILL E 12 TD01 Perform shallow test Schlumberger tools @ 700 gpm-850 psi'.Ok. 18:30 20:00 1.50 20.00 DRILL E 4 TD01 RIH BHA#5 picking up 5"DP 1x1 from shed 1/912'1/2,192'. 20:00 21:30 1.50 21.50 DRILL E 25 TD01 Slip and cut 45'drilling line. 21:30 00:00 2.50 24.00 DRILL E '4 .TD01 RIH BHA#5 1/2,192'1/4,200',culling out 5"DP with bad hard band and picking up news"DP 1x1 from shed.Fill pipe every 20 stands. Daily Contacts Position Contact Name Company Title E-mail Office Mobile v: Eni representative James Thompson 'Eni Petroleum Sr.Dog.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drlg Spvr. angelo.lamanna@enipetroleum.com 907.685-1493 907.903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Steve Abbott Eni Petroleum Materials Coordinate Tool Push Mike Witiams Nabors Alaska Dnlling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Dulling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') • fill* Eni E&P Divisionwell Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • API/UWI:50-029-23459-00-00 en0 Date:6/27/2012 - Report#: 16 II i page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD..,Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 14.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,810.87 935.01 0.00 81.0 5.6 Overcast WC 38' NE @ 7 MPH Daily summary operation 24h Summary RIH BHA#to 9,195'-Drill 12'/"section to 9.222'-Schlumberger Xceed900 failure-BROOH to 5,339'. Operation at 07.00 BROOH @ 3,420' 24h Forecast BROOH-CBU @ csg shoe-POOH on elevators-cull out bad hard band 5"DP-L/D BHA#5-M/U BHA#6 with Smith insert bit and Power Drive X5-RIH to 9,222'-Drill 12%"section to planned TD @ 12,063'MD. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 02'00 2.00 2.00 DRILL E 4 TD01 'RIH BHA#5 on elevator(/4,200'8/6,535'.Could not slack off.Attempt to wash down with 750 gpm and 2000 psi negative. Fill pipe every 20 stands. 02.00 09:00 7.00 9.00 DRILL E 4 TD01 'RIH BHA#5 washing and reaming 1/6,535'8/9,195'at 750 gpm/2230 psi/60 rpm/7-10k gibs. 09.00 13:30 4.50 13.50 DRILL E 3 TD01 Drill rotary 0 12 7."new hole 1/9,195'59,222'\800 gpm @ 2180 psi\60.100 rpm @ 14.18k Nibs\WOB 5-25k lb\Up wt= 175k Ib-Dw wt=55k lb-Rot wt=100k lb\Mud wt=9.4 ppg\ECD=10.2 ppg. Schlumberger Tool failure Xceed900(s/n CRSC-148)unable to hold tool face while drilling.Trouble shoot trying several times to send commands and attempting with various RPM(60 to 100),WOB(5k to 25k)and GPM(600 to 900)as per DD indications:No success.Decided to POOH. 13:30 15:30 2.00 15.50 DRILL E 19 TD01 -BROOH(/9,222'58,970'@ 800 gpm/2200 psi/120 rpm/12-16k frlbs.Send downlinks and ream down to 9,222'.Attempt to drill:tool still not working. 15:30 0000 8.50 24.00 DRILL E 6 TD01 -BROOH 1/9,222'55,339'at 5 min/stand or as hole dictates.800 gpm/2200->1660 psi/100 rpm 116k->8k fibs.No drag/tightspot. Daily Contacts Position Contact Name Company Title Email _ Office - Mobile Eni representative James Thompson Eni Petroleum Sr.[trig.Spur. 907-685-1493 - Eni representative Angelo Lamarina Eni Petroleum Drlg Spur. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 133/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 01* Eni E&P Division I Well Name:0120 07 EN/Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • APIIUWI:50-029-23459-00-00 2 II If �'r,r, Date:6/28/2012 - Report#: 17 page 1 of 1 Wellbore name: 0120-07 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(kr) Avg ROP(mlhr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 15.00 Daily Information End Depth(mKB) •End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2.810.87 93501 0.00 81.0 9.4 Overcast WC 49` East @ 6 MPH Daily summary operation 24h Summary BROOH 115,339'1/2,750'-CBU-POOH and L/D BHA#5-Troubleshoot iron roughneck-L/D 12 joints 5"DP with bad hard band-M/U BHA 86-RIH BHA#6 on elevators(/266 V 6,486'-RIH washing and reaming 116,486'87,700'. Operation at 07.00 Drill 12'''A"section @ 9,230' 24h Forecast Drill 12''A"section to planned TD @ 12,063'MD. Lithology Shows •MAASP(kgf/cm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 '05'.00 5.00 5.00 DRILL E 6 TD01 BROOH f/5,339'82,750'at 5 min/stand or as hole dictates.800 gym/1660-v1260 psi/100 rpm/8k->3k(t'Ibs.No drag/tightspot. 05.00 06.30 1.50 6.50 DRILL E 7 TD01 CBU 3x(shakers clean)@ 900 gpm/1500 psi/70 rpm/2-3k fl lbs.Monitor well for 10 min:Ok.Pump dry job,blow down top drive and install stripping rubbers. 06.30 08:00 ' 1.50 8.00 DRILL E 4 TD01 POOH on elevators from f/2,750'8280'. 0800 11 00 3.00 11.00 DRILL E 5 TD01 L/D BHA#5.Bit dull 0-0-NO-A-E-I-NO-DTF. -)NM Stab had groove worn in leading edge.This stab was only run in this BHA. -)NM ILS Stabilizer had groove worn in leading edge of stab and missing tiles at the top of the blade.This Stab was run on BHA 4 and 5. -)NM Flex DC-Missing the majority of the wear bands,uneven wear mostly on one side of collar.This collar was run on BHA 4 and 5. 11:00 11 30 0.50 11.50 DRILL E 4 TD01 M/U mule shoe and RIH with 4 stands 5"DP with bad hard band. 11:30 13.00 1.50 13.00 DRILL E 25 TR99 Rig Downtime:repair spinners on iron roughneck.Knuckle on arm of spinners broke. 13:00 1500 2.00 15.00 DRILL E 1 TD01 Continue RIH with stands 5"DP to 950'.POOH and L/D 12 joints with bad hard band.P/U newjoints tat from shed and M/U.Clean rig floor.Prepare to P/U BHA#6. 1500 1800 - 3.00 18.00 DRILL E 5 TD01 Held PJSM.P/U BHA#6:Smith Insert bit 0 12 1/4"GF15B-ODVCPS(sln PX2253)with 2x 18/32"+2x 16/32"nozzles (TFA=0.89)+PD900_X5(s/n 50356)+ARC 825(s/n E5619)+8"Telescope MWD(s/n E1166)+NM XO Sub+8"NM ' Stabilizer+NMDC+ x NM Flex DC+Float sub+Weatherford 7 3/4"Hydraulic Jar(s/n 1417-1044)+XO+2x 5"HWDP. Total length=266.04'. 18:00 19.30 1.50 19.50 DRILL E 4 TD01 RIH BHA#6 with stands 5"DP(/266'82,800'. 19:30 25 30 1.00 20.50 DRILL E 11 TD01 RIH BHA#6 with stands 5"DP(/2,800'83,515'taking survey every stands as per MWD. 20.30 22.00 1.50 22.00 DRILL E 4 TD01 Continue RIH BHA#6 on elevator f/3,515'86,486'.Could not slack off.Fill pipe every 20 stands. 22 00 05 00 2.00 24.00 DRILL E 6 TD01 RIH BHA#6 washing and reaming(/6,486'1/7,700'at 700 gpm/1560 psi 150 rpm/6-8k?ribs. Daily Contacts Position Contact Name Company Title E-mail _ Office Mobile • Eni representative James Thompson En:Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamanna Eni Petroleum Drlg Spvr. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Robert Yundt Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm2) Eq.Mud Weight(g/L) P LeakOff(kgf/cm') I* Eni E&P Division 'Well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name: Nikatchuq • API/UWI:50-029-23459-00-00 2^o Date:6/29/2012 - Report#: 18 II �Ipage 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 372 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 16.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 2,720.04 919.39 89.92 10.18 8.8 80.0 5.6 Scattered Clouds WC NNE @ 7 MPH 38' Daily summary operation 24h Summary RIH BHA#6 to 9,222'-Drill 12'/."section to 9,500'-Still not being able to drop angle as needed-Decided to sidetrack @ 8,920'-BROOH to 8,890'-Work pipe 30'up and down f/8,890'08,920'-Start sidetrack at 8,920'-Time Dri 1 g11Ti -orf sidetrack 118,920'V8,924'. Operation at 07.00 Time drilling for sidetrack at 2 fph @ 8,929'. 24h Forecast Time drilling for sidetrack-Drill 12%"section to planned TD @ 12,063'MD. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Due(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 02.00 2.00 2.00 DRILL '8 6 TD01 RIH BHA#6 washing and reaming(T7,700'1./9,069'at 700 gpm/1820 psi/75 rpm/12k bibs. 0200 03 30 1.50 3.50 DRILL -E 6 TD01 RIH BHA#6 washing and reaming f/9,096'V9,222'@ 200 fph to tie in logs/800 gpm/2280 psi/75 rpm/12k fflbs.Send Downlink to PowerDrive. 03.30 12 00 8.50 12.00 DRILL E 3 TD01 Drill rotary 0 12 W new hole V9,222'1/9,500'(3,054'TVD)1750 gpm @ 2020 psi/120 rpm @ 13.15k ft'lbs\WOB 5-12k lb \Up wt=165k lb-Dwwt=55k lb-Rot wt=95k lb\Mud wt=9.3 ppg\ECD=10.1 ppg-Take survey as needed-Ream and wash 30'every connection.Use Canrig Soft Torque. Note bit inclination 90 degree,still not being able to drop angle as needed. 12.00 15.30 3.50 15.50 DRILL 'E 3 TD01 Attempt time drilling from 9,500'to 9,513',gaining 1/2 degree inclination instead of dropping.Decided to POOH to 8,920' and sidetrack. 15.30 16.30 1.00 16.50 DRILL E 6 XDO1 BROOH(/9,513'118.890'at 2 min/stand.800 gpm/2150 psi/120 rpm/14k ft'Ibs. 16.30 19.30 3.00 19.50 DRILL 'F 6 'XDO1 Start sidetrack working pipe f/8,890'1/8,920'at 750 gpm/1900 psi/120 rpm/13k ftlbs as per DD indications. 19.30 20.30 1.00 20.50 DRILL F 3 XDO1 Continue rotating for 1 hour @ 8,920'at 120 rpm/850 gpm/2300 psi/12.7k frlbs. 20.30 0000 3.50 24.00 DRILL -F '3 XDO1 Time Drilling for sidetrack from 8,920'10 8,924'at 1 fph for 2 hours,then 2 fph at 750 gpm/1840 psi/120 rpm/12.5k ft'Ibs I WOB 2-5k lb. )ADT=10.18-JAR=10.18 hrs]. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum 'Sr.Ddg.Spvr. '907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drlg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 En:representative Robert Yundt Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 En:representative Ken Bogner Eni Petroleum Matenals Coordinato Tool Push Bruce Simonson Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Dulling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L60 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') Eni E&P Division I Well Name:0120-07 OW* ENI Petroleum Co.Inc. Daily Re M o rt Well Code:26484 Field Name: Nikatchuq • APIIl1W1:50-029-23459-00-00 en0 Date:6/30/2012 - Report#: 19 II II page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator EM Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 17.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 2,727.96 920.51 7.92 9.99 0.8 84.0 7.2 Clear Calm Daily summary operation 24h Summary Timedrilling from 8,920'to 8,950':still not being able to drop angle as needed-Decided to POOH-BROOH 1/8,950'96,008'at 2-3 min/stand. Operation at 07.00 BROOH @ 3,505'. 24h Forecast BROOH-L/D BHA#7-Test BOPS as per AOGCC requirements-M/U BHA 87 with PDC bit and RIH to 8,920'. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. _ Plan Oper.Descr. 00:00 20:00 20.00 20.00 DRILL F 3 XDO1 Time Drilling for sidetrack from 8,920'to 8,950'.Attempting to sidetrack wellbore.Timedrill at 1 fph for 2 hours,then 2 fph for 2 hrs then 3 fph for 5 hrs to 8.940.DD increased ROP to 6 fph and fell off ledge into old wellbore.P/U to 8,940'and sit for 1.5 hrs to re-establish ledge.Continue timedrilling from 8,940'to 8,950'at 2 fph with 750 gpm/1900 psi/120 rpm/ 12.4k frlbs/WOB 4-6k lb:still not being able to drop angle as needed.Decided to POOH. Note:BOP test due date on 06:00 hrs 7/2/2012. 20.00 00:00 4.00 24.00 DRILL F 6 XDO1 BROOH(18,950'1/6,008'at 2-3 min/stand @ 700 gpm/1648 psi/100 rpm/12k f"lbs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drtg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Robert Yundt Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 • Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') I 1. Eni E&P Division I Well Name:0120-07 rif* EN!Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • API/UWI:50-029-23459-00-00 2 n o Date:7/1/2012 - Report#: 20 I' II page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 18.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(`C) Weather Wind 2,727.96 920.51 0.00 84.0 2.2 Fog Calm Daily summary operation 24h Summary BROOH-L/D BHA#6-UD 5"DP with bad hard band-P/U&M/U new stands of 5"DP. Operation at 07.00 Pressure test BOP stack as per AOGCC requirements. 24h Forecast P/U,M/U&R/B stands of new 5"DP-Test BOPs as per AOGCC requirements-Bob Noble waived to witness the test-M/U BHA#7 with Reed Hycalog PDC 12 1/4"bit and RIH to 8,920'. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 11144 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05:00 5.00 5.00 DRILL F 6 XDO1 BROOH 1/6,00&1/2,754'at 2-3 min/stand©720 gpm/1300-.1000 psi/100 rpm/7-.5k fl'Ibs. 05:00 06:00 1.00 6.00 DRILL F 7 XDO1 CBU 3x(shakers clean)@ 760 gpm/1150 psi/80 rpm/2.5k tlibs.Monitor well for 10 min:Ok.Pump dry job,blow down top drive and install stripping rubbers. 06:00 09:30 3.50 9.50 DRILL I F 4 XDO1 POOH on elevators from 1/2,754'1/266'.UD 39 joints of 5"DP with bad hard band. 09:30 13:30 4.00 13.50 DRILL F 5 XDO1 L/D BHA#6.Bit dull 1-1-WT-A-E-I-NO-BHA. 13:30 14:30 1.00 14.50 DRILL F 1 XDO1 Clean and clear ng floor.Prepare to UD 5"DP with bad hard band.UD XOs and stab. 14:30 21:00 6.50 21.00 DRILL F 5 XDO1 TIH with stand 5"DP to 2,540'culling out on the way in hole 57 joints with bad hard band. 21:00 23:00 2.00 23.00 DRILL F 4 XDO1 POOH 1/2,540 to surface.SLM in derrick. 23:00 00:00 1.00 24.00 DRILL F 5 XDO1 P/U 5"DP 101 from shed and RIH to 840'.Draft pipe on skate. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.DrIg.Spvr. 907-685-1493 Eni representative Angelo Lamanna Eni Petroleum DrIg Spvr. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Robert Vundt Eni Petroleum HSE 907-685-1496 Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Em representative Ken Bogner Eni Petroleum Matenals Coordinate Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6:17/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') I Eni E&P Division I Well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name: Nikatchuq • API/U1AA:50-029-23459-00-00 2^U tt Date:7/2/2012 - Report#: 21 II II page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 19.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(Br) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2.727.96 920.51 0.00 86.0 7.8 Fog WC 42- NE @ 9 MPH Daily summary operation 24h Summary P/U,M/U&R/B stands of new 5"DP-Test BOPS as per AOGCC requirements-Bob Noble waived to witness the test-M/U BHA#7 with Reed Hycalog PDC 12 1/4"bit and RIH to 6,006'. Operation 5107.00 RIH BHA#7©8,830'. 24h Forecast RIH BHA#7 to 8,920'-Timedrilling for sidetrack @ 8,925'-Dnll 12 G"section to planned TD @ 12,063'MD. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr( Dur(Br) Phase Opr. Act. Plan Oper.Descr. 00.00 02.30 2.50 2.50 DRILL F 4 XDO1 Continue POOH with new 5"DP replacement for bad DP hard band.Rack in demck.Pipe skate broke down.Starts repairs on pipe skate. 02:30 03:00 0.50 3.00 DRILL C 5 XD01 Pull wear bushing and install test plug as per Vetco. 03:00 04:00 1.00 4.00 DRILL C 1 XD01 M/U 5"testing joint with TIW&Dart valves.Fluid pack lines/BOP stack. 04:00 08:30 4.50 8.50 DRILL C 12 XD01 Test BOP as per AOGCC requirements-Annular @ 250-2500 psi-Rams,choke manifold,floor and top drive valves @ 250-3500 psi-Chart record-BOP test waived by AOGCC rep.Bob Noble. 08:30 10:30 2.00 10.50 DRILL C 5 XD01 Pull test plug and install wear bushing.B/D and L/D testing equipment. 10:30 14:00 3.50 14.00 DRILL F 5 XD01 M/U mule shoe and P/U 66 new joints of 5"DP 101 from shed. 14:00 15:30 1.50 15.50 DRILL F 4 XD01 POOH and R/B 22 stands of new 5"DP. 15:30 18:30 3.00 18.50 DRILL F 5 XD01 Held PJSM.P/U BHA#7:Reed Hycalog PDC bit 0 12 1/4"MSX6195-A2C(s/n E141128)with 60 14/32"nozzles (TFA=0.902)+PD900 X5(s/n 54438)+ARC 825(s/n E5901)+8"Telescope MWD(s/n YD56)+NM XO Sub+8"NM Stabilizer+NMDC+2x NM Flex DC+Float sub+Weatherford 7 3/4"Hydraulic Jar(s/n 1417-1044)+XO+2x 5"H WDP. Total length=263.66'. 18:30 20:00 1.50 20.00 DRILL F 4 XD01 RIH BHA#7 with stands 5"DP 8263'82,759'.Shallow test @ 1,000'.Ok.Fill pipe every 20 stands. 20:00 21:00 1.00 21.00 DRILL F 25 XD01 Slip and cut 45'of drilling line. + 21:00 23:00 2.00 23.00 DRILL F 4 XDO1 RIH BHA#7 on elevators f/2,759'115,527',filling pipe every 20 stands. 23:00 00:00 1.00 24.00 DRILL F 6 XDO1 'RIH BHA#7 washing and reaming f/5,527'06,006'at 700 gpm/1650 psi 145 rpm/6-7k fibs. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Dug.Spvr. 907-685-1493 Eni representative Angelo Lamanna Eni Petroleum Dug Spvr. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Robert Yundt Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 1 11191* Eni E&P DivisionWell Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • Date:7/3/2012 - Report#: 22 APIIU'M:50-029-23459-00-00 2" " page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator •ENI Share(14) Well Configuration type 402100 _ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 20.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature(°C) Weather Wind 2,727.96 920.51 0.00 85.0 7.8 Mostly Cloudy WC ENE©15 MPH 40' Daily summary operation 24h Summary RIH BHA#7 to 8,920'-Timedrilling for sidetrack f/8,920'1/8,950'. Operation at 07.00 Timedrilling for sidetrack©8,953' 24h Forecast Timedrilling for sidetrack-Drill 12 Y.."section to planned TD @ 12.063'MD. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1108.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 04:00 4.00 4.00 DRILL F 6 XD01 RIH BHA#7 washing and reaming 1/6,006'1/8,920'at 700 gpm/1700 psi/50 rpm/6-7k ft'Ibs. 04:00 06:00 2.00 6.00 DRILL F 6 XD01 Odentate downhole tools.Work trench from 8,900'to 8,920'at 800 gpm/2300 psi/120 rpm/14.8k Ribs. 06:00 07:00 1.00 7.00 DRILL F 3 XD01 Rotate with tool face down©8,920'at 800 gpm/2200 psi/120 rpm/11.5k ft'Ibs. 07:00 12:00 5.00 12.00 DRILL F 3 XD01 Time Drilling for sidetrack from 8,920'to 8,925.5'.Timedrill at 1 fph for 2 hours,then 2 fph with 800 gpm/2300 psi/120 rpm/12.5k Bibs/WOB 2-4k lb.At 8,925.5'fell out the ledge.P/U to 8,920'and restart timedrilling. 12:00 0000 12.00 24.00 DRILL F 3 XDO1 Time Dulling for sidetrack from 8,920'to 8,939'at 2 fph,from 8,939'to 8,950'at 3 fph with 800 gpm/2300 psi/140 rpm/ 14.5-15k fflbs/WOB 2-10k lb. Note.inclination at 8,920'=83.15/inclination at 8,950'=82.65. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.DrIg.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Ng Spvr. angelo.lamanna©enipetroleum.com 907-685-1493 907-903-7269 Eni representative Robert Yundt Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Dolling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') VI* Eni E&P Division . I Well Name: 0120-07 EN/Petroleum Co.Inc. DailyReportWell Code:26484 Field Name: Nikatchuq eDate:714/2012 - Report#: 23 APIIUVVI:50-029-23459-00-00 ei ii page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 21.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(CC) Weather Wind 2.779.17 929.27 51.21 19.98 2.6 85.0 7.8 Clear WC 40" NE @15 MPH Daily summary operation 24h Summary Operation for sidetrack-Drill 12'/."section to 9,118'MD. ��Ivy /Z�1,(-. Operation a107.00 Drill 12%"section @ 9,256'. 24h Forecast / Drill 12'/."section to planned TD @ 12,063'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1108.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 - 12.00. 12.00 DRILL F 3 XDO1 Time Drilling for sidetrack from 8,950'to 8,956'at 2 fph with 800 gpm/2280 psi/140 rpm/14.5-15k(ribs/WOB 4-6k lb. Attempt to increase WOB,drilling off slow.Stage WOB up in slow increments f/6 to 16klbs,fell off the ledge.P/U and regain 6-15 WOB and let it drill off.Maintained 10 klbs WOB and dolled to 8,959'. 12:00 1730 5.50' 17.50'DRILL F 3 XD01 Time Drilling for sidetrack from 8,959'to 8,966'at 2 fph with 800 gpm/2280 psi/140 rpm/14.5k itis/WOB 10-22k lb. Drilled through hard spot.Inclination still dropping, 1730 0000 6.50' 24.00'DRILL F 3 XD01 Control drilling @ 30 ft/hr from 8,966'to 9,060'and©60 ft/hr from 9,060'to 9,118'with 800 gpm/2280 psi/140 rpm/ 15.5k ft'Ibs/WOB 4-7k lb.Take surveys as needed to confirm sidetrack. Old hole surveys: 8951.16'->inc.82.61/9046.23'->inc.62.21/9143.57'->inc.84.74. New hole surveys:8946,53'->inc.81.27/9010.02'->inc.79.91/9105.54'->inc.79.62. IADT=19.98-JAR=57.4 hrs]. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum -Sr.Ddg.Spur. 907.685-1493 Eni representative Angelo Lamarina Eni Petroleum Dug Spur. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Robert Yundt Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Gary Gibson Eni Petroleum Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) •TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') fiff#11 Eni E&P Division 'Well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • API/UW:50-029-23459-00-00 2 n n� Date:7/5/2012 - Report#: 24 'I �'Ipage 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 22.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,852.32 941.98 73.15 13.09 5.6 85.0 5.6 Clear WC 36° NE @ 10 MPH Daily summary operation 24h Summary Drill 12'''A"section(/9.118'1/9.358'-Decided to POOH due to low ROP and check bit conditions-BROOH 1/6,004'-POOH BHA#7 on elevators 1/940'. Operation at 07.00 LID BHA#7 in progress. 24h Forecast POOH BHA#7-cull out bad hard band 5"DP-LJD BHA#7-M/U BHA#8 with 12 1/4"VM-3 Hughes MT bit and Power Drive X5-RIH to 9,358'-Drill 12'''A"section to planned TD @ 12,063'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 02.30 2.50 2.50 DRILL -E 3 XDO1 Drill rotary 0 12 7."09,118'1/9,175'\800 gpm t 2250 psi 380-120 rpm @ 15+17k Nibs\WOB 4-25k lb\Up wt=165k lb- Dw wt=65k Ib-Rot wt=100k lb\Mud wt=9.3 ppg\ECD=9.8 ppg. 02 30 14.30 12.00 14.50 DRILL E 3 P Drill rotary 0 12'A'new hole(/9,175'1/9,358'\800 gpm @ 2250 psi\60-120 rpm a 15+18k ft.lbs\WOB 5-20k Ib\Up wt= 165k lb-Dw wt=60k lb-Rot wt=100k lb\Mud wt=9.3 ppg\ECD=9.83 ppg-Take survey as needed-Ream and wash 30'every connection.Use Canrig Soft Torque.ROP drops significantly.Decided to POOH and check bit conditions.Faults @ 9,225'8 9,262'. Note:encountered several hard spot areas.Slow down rpm to 60-80 and pick weight up to 25 klbs. 14:30 20.00 5.50 20.00 DRILL 'E 6 P BROOH 09,358'1/6.004'at 3-5 min/stand @ 800 gpm/2200 psi/100 rpm 115->12k ft'Ibs. 20:00 00:00 4.00 24.00 DRILL 'E 4 P POOH BHA#7 on elevators 1/6,004'1/940'.Up Wt 125 klbs.No swab,proper fill.Monitor well 15 min at shoe:Ok.L/D down 7 joint of 5"DP with bad hard band. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry -Eni Petroleum Sr.Ddg.Spur. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drlg Spur. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Robert Yundt Eni Petroleum HSE 907-685-1496 Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Bruce Simonson Nabors Alaska Dulling Tool Pusher 907-670-1492 Tool Push Gary Gibson Eni Petroleum Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 1111* Eni E&P Division [Well Name: 0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • API/UWI:50-029-23459-00-00 2�II 'f,ii r, Date:7/6/2012 - Report#: 25 page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m( Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 23.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 2,894.38 949.19 42.06 3.78 11.1 88.0 5.0 Overcast WC 39' NNW @ 4 MPH Daily summary operation 24h Summary POOH BHA#7-cull out bad hard band 5"DP-UD BHA#7-M/U BHA#8 with 12 1/4"VM-3 Hughes MT bit and Power Drive X5-RIH to 9,358'-Drill 12%"section 1/9,358'1/9,496'. Operation at 07.00 Drill 12 Y.."section({))9,738'. 24h Forecast Drill 12 14"section to planned TD @ 12,063'MD. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 Cl 00 1.00 1.00 DRILL E 4 P POOH BHA#7 on elevators laying down 15 joints of 5"DP with bad hard band.R/B good stand DP.Hole taking proper fill. 01'.00 04.00 3.00 4.00 DRILL E 5 P Held PJSM.UD BHA#7.Bit dull:2.8-RO-A-X-I-BT-PR. 04.00 0530 1.50 5.50 DRILL E 1 P Service ng and clear floor of BHA tools.Load pipe shed with new BHA tools.Adjust drawworks brake.Grease drawworks. 05.30 10 00 4.50 10.00 DRILL E 5 P Held PJSM.P/U BHA#8:Hughes MT bit 0 12 1/4"VM-3(s/n 5193891)with 2x 16/32"+2x 18/32"nozzles(TFA=0.902)+ PD900 X5(s/n 50357)+ARC 825(s/n E5102)+8"Telescope MWD(s/n 00385)+NM X0 Sub+8"NM Stabilizer+ NMDC+2x NM Flex DC+Float sub+Weatherford 7 3/4"Hydraulic Jar(s/n 1417-1044)+X0+2x 5"HWDP.Total length =258.41'.Surface test PowerOnve:Ok. 10.00 11 00 1.00 11.00 DRILL E 4 P RIH BHA#8 with stands 5"DP(/258'811,000'.Shallow test with 700 gpm/900 psi:Ok. 11:00 14 30 3.50 14.50 DRILL E 4 P RIH BHA#8 on elevators 1/1,000'116,480',filling pipe every 20 stands.Proper displacement. 14.30 19 00 4.50 19.00 DRILL E 6 P RIH BHA#8 washing and reaming f/6,480'69,358'at 700 gpm/1700 psi/50 rpm/6-7k ft-lbs.No tightspots.Ream through KOP @ 8,920'with same parameters:Ok.Took survey at 8,950'-8,964'-8,996':Ok,inclination dropped(/83.15 5/80.75. 19 00 00 00 5.00 24.00 DRILL E 3 P Drill rotary 0 12 Y."f/9,358'1/9,496'(3,114'TVD)\800 gpm @ 2265 psi 180 rpm @ 14+18k fobs\WOB 10-30k lb\Up wt= 170k lb-Dw wt=48k lb-Rot wt=102k lb\Mud wt=9.4 ppg\ECD=10.14 ppg-Take survey as needed-Ream and wash 30'every connection. Note:encountered several hard spot areas. (ADT=3.78-JAR=72.21 hrsj. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Drlg.Spvr. 907-685-1493 Eni representative Angelo Lamanna Eni Petroleum Ddg Spvr. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Robert Yundt Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Em Petroleum Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Bruce Simonson Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Gary Gibson Eni Petroleum Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P Lea kOff(kgflcm.) r It* Eni E&P Division I Well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • Date:7/7/2012 - Report#: 26 APIIUWI:50-029-23459-00-00 2" page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 24.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,370.48 1,005.91 476.10 18.22 26.1 88.0 7.8 Overcast WC 38' ENE @ 23 MPH Daily summary operation 24h Summary Drill 12 Y."section 59,496'1/11,058'(3,302'TVD). Operation at 07.00 Drill 12'''A"section @ 11,300'. 24h Forecast Drill 12 W section to planned TD @ 12,063'MD-Clean up cycle-BROOH. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 -06:00 6.00 6.00 DRILL E 3 P Drill rotary 0 12''"f/9,496'09,980'\800 gpm @ 2250 psi\80-120 rpm @ 14+17k Ribs I WOB 6-25k lb\Up wt=170k Ib- Dw wt=50k lb-Rot wt=100k lb\Mud wt=9.4 ppg\ECD=10.2 ppg-Take survey as needed-Ream and wash full stand every connection.Drill through hardspot 1/9,496'1/9.500'. 06:00 12:00 6.00 12.00 DRILL E 3 P Drill rotary 0 12''A"f/9,980'810,266'\800 gpm @ 2575 psi\80-120 rpm @ 16+18k nibs\WOB 15-27k lb\Up wt=175k lb -Dw wt=50k Ib-Rot wt=100k lb\Mud wt=9.4 ppg\ECD=10.23 ppg-Take survey as needed-Ream and wash full stand every connection. 12:00 .18:00 6.00 18.00 DRILL E 3 P Drill rotary 0 12''/."1/10,266'1/10,669'\800 gpm @ 2530 psi\80-120 rpm @ 16+17k f8lbs\WOB 20-25k lb\Up wt=167k Ib-Dw wt=50k lb-Rot wt=102k lb\Mud wt=9.4 ppg\ECD=10.48 ppg-Take survey as needed-Ream and wash full stand every connection.Drill through hardspot 1/10,264'1/10,270'. 18:00 00:00 6.00 24.00 DRILL E 3 P Drill rotary 0 12''A'f/10,669'811,058'(3,302')\800 gpm @ 2640 psi\80-120 rpm @ 16+18k Nibs\WOB 25k lb\Up wt= 170k lb-Dw wt=50k lb-Rot wt=102k lb\Mud wt=9.4 ppg\ECD=10.38 ppg-Take survey as needed-Ream and wash full stand every connection.Drill through hardspot(/11,048'811,058'. [ADT=18.22 hrs-JAR=90.72 hrs]. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry 'Eni Petroleum Sr.Ddg.Spvr. -907.685-1493 Eni representative Angelo Lamarina Eni Petroleum Drlg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Robert Yundt Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Gary Gibson Eni Petroleum Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') • 111* Eni E&P Division [Well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • API/UWI:50-029-23459-00-00 2�, Date:7/8/2012 - Report#: 27 II 'I II page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924 40 970.78 5,504.08 245.06 22.5 25.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3,608.83 1,028.28 238.35 8.77 27.2 88.0 7.8 Overcast WC 44" ENE @ 6 MPH Daily summary operation 24h Summary Drill 12 W section to TD @ 11,840'MD(3,375'TVD)-CBU x6-BROOH to 10,306'. Operation at 07.00 BROOH @ 8,777'. 24h Forecast BROOH to 1,100'-Circulate shakers clean-POOH and L/D BHA#8-0/0 top rams to 9 5/8"and test as per AOGCC requirements-Prepare to run 9 5/8"csg. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 12.00 12.00 12.00 DRILL E 3 P 'Drill rotary 0 12 W f/11,059'V11,840'(3,375')/800 gpm @ 2850 psi\120 rpm @ 15i-18k ft'lbs\WOB 25k Ib\Up wt=175k lb-Dw wt=50k lb-Rot wt=100k lb\Mud wt=9.4 ppg\ECD=10.2 ppg-Take survey as needed-Ream and wash full stand every connection. [ADT=8.77 hrs-JAR=99.5 hrs]. 12:00 20:00 8.00 20.00 DRILL E 7 P CBU x6 while backreaming one stand per bottoms up to 11,263'/840 gpm @ 3000 psi\140 rpm @ 18+21k nibs. 20.00 00:00 4.00 24.00 DRILL E 6 'P 'BROOH(/11,263'810,985'@ 30 min/stand and 810,985'V10,306'@ 15 min/stand with 825 gpm @ 2725 psi\140 rpm @ 18.19k albs.No tightspots. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum 'Sr.Drig.Spur. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drtg Spurr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Robert Yundt Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum :Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Gary Gibson Eni Petroleum Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOf/(kgflcm') Eni E&P Division Well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • Date:7/912012 - Report#: 28 API/UWI:50-029-23459-00-00 2" " page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 26.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 3,608.83, 1,028.28 0.00 88.0 12.8 Overcast NE @ 6 MPH Daily summary operation 24h Summary BROOH to 1,030'-Circulate 3x BU till shakers clean-POOH and UD BHA#8-C/O top rams to 9 5/8"and test as per AOGCC requirements-R/U Tesco Tool. Operation at 07.00 RIH 9 5/8"Casing(40#/L-80/Hydril 563/Special drift 8.75")0483'. 24h Forecast R/U Tesco casing tool-9 5/8"Casing Job-R/D Tesco-Install cement head-Fill up casing. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 16:00 16.00 16.00 DRILL E 6 P BROOH 010,306'1/10,000'@ 10 min/stand,010,000'07,500'@ 5 min/stand,ff7,500'1/3,991'@ 3 min/stand and 1/3,991' 01,0301@ 2 min/stand with 850 gpm @ 2900->1140 psi/140 rpm @ 20-02k ft'lbs.Consistant torque-No tightspots- Shakers running clean. 16 00 16:30 0.50 16.50 DRILL E 7 P Circulate 3x bottoms up till shakers clean with 850 gpm @ 1200 psi. 16:30 17:00 0.50 17.00 DRILL E 4 P POOH BHA#8 on elevator 1/1,030't/258'. 17:00 19:30 2.50 19.50 DRILL E 5 P Held PJSM.UD BHA#8.Bit dull:1-2-WT-A-E-1-NO-TD. 19:30 21:00 1.50 21.00 DRILL C 5 P Pull wera bushing.Shut blind rams.C/0 top rams f/4%'o 7"variable 1/9 5/8"fix. 21:00 21:30 0.50 21.50 DRILL C 12 P Set test plug-Fill BOP-Test 9 5/8'top rams 250/3500 psi 10 min on chart'.Ok. 21:30 22:00 0.50 22.00 DRILL C 5 P Pull test plug-Install short wear bushing-L/D running and testing tool. 22:00 00:00 2.00 24.00 DRILL G 5 P Held PJSM.R/U Tesco casing running tools.In progress. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative 'Ben Perry Eni Petroleum "Sr.DrIg.Spur. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum DrIg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Robert Yundt Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Materials Coordinate Tool Push Bruce Simonson Nabors Alaska Dulling Tool Pusher 907-670-1492 Tool Push Gary Gibson Eni Petroleum Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 13 3/8 12.415 L80 0.00 841.22 6/17/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') Eni E&P Division I Well Name:0120-07 fa* ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • Date:7/10/2012 - Report#: 29 APIIl1Wl:50-029-23459-00-00 2 i "ii page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 27.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 3,608.83 1,028.28 0.00 84.0 6.1 Clear WC 39° East @ 6.9 MPH Daily summary operation 24h Summary R/U Tesco-RIH 9 5/8"Csg to 11,830'-R/D Tesco tools-R/U cement head-Fill up Csg. Operation at 07.00 Circulate and condition mud for cement job. 24h Forecast Fill up casing-R/U cementing equipments-9 5/8'Cement job-R/D cement equipments-Infectivity test-R/D cement head-WOC-Lift BOP Stack-Set 9 5/8'Csg slip and cut 9 5/8.Csg-N/U BOP. Lithology Shows MAASP(kgflcm2) Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 02.00 2.00 2.00 DRILL G 5 P Finish to R/U Teseo easing running tools-Function test equipment:Ok. 02:00 07:30 5.50 7.50 DRILL G 4 P 'Held PJSM-P/U 9 5/8'eaa(40#/L-80/Hydril 563/Special drift 8.757LFJoating-Fill shoe track and check float equipment:Ok-RIH L/3267(1/1.5 min/Jt-Av.MUT 13k ft'lbs).Proper displacement. 07:30 20:30 13.00 20.50 DRILL G 4 P P/U 9 5/8"csg and RIH rotating(13.267'8/11,830'.Proper displacement. Parameters:65 rpm @ 2k->8k ft'lbs-HKLD 54k->40k lbs-1/1.5 min/Jt-Av.MUT 13k ft'lbs. 20:30 21:30 1.00 21.50 DRILL G 5 P R/D Tesco tool and running equipment-M/U cement head and lines to fill 9 5/8"csg with LSND mud. 21 30 00:00 2.50 24.00 DRILL G 9 P Fill 9 5/8"csg with 9.4 ppg LSND mud bleeding air through choke.Stop and bleed off air at 1/2 way full.In progress. Daily Contacts Position Contact Name Company Title E-mail Office Mobile EM representative Ben Perry Eni Petroleum Sr.Drlg.Spvr. 907-685-1493 Eni representative Angelo Lamanna Eni Petroleum Drlg Spvr. angelo.lamarina@enipetroleum.com 907.685-1493 907-903-7269 Eni representative Robert Yundt Eni Petroleum HSE 907.685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Materials Coordinate Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Gary Gibson Eni Petroleum Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 0.01 3,605.78 7/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm2) Eq.Mud Weight(gIL) P LeakOff(kgflcm2) $* Eni E&P Division I Well Name:0120-07 EN!Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • API/t1WI:50-029-23459-00-00 2 II n r, Date:7/11/2012 - Report#: 30 If I' page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 28.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 3,608.83 1,028.28 0.00 87.0 9.4 Clear WC 49' East @ 5 MPH Daily summary operation 24h Summary Fill up casing-R/U cementing equipments-9 5/8"Cement job-R/D cement equipments-Injectivity test-R/D cement head-WOC-Lift BOP Stack-Set 9 5/8"Csg slip and cut 9 5/8"Csg-Test packof and wellhead connection-N/U BOP. Operation at 07.00 Change upper rams to 4 1/2"-7"VBR 24h Forecast Finish to N/U BOP stack-C/O upper rams-RIH and cull out 5"joints with bad hard band-POOH installing 80x Wei-CD valves-Pressure test BOP as per AOGCC requirements w/5"&4 1/2"test joint. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Deacr. 00:00 0330 3.50 3.50 DRILL G 9 P Fill 9 5/8"csg with 9.4 ppg LSND mud bleeding air through choke.Stop and bleed off air at 1/2 way full.3/4 full and 50 bbls shy of full.Filled at 890 bbls.Once full and all air bled out,install cement plugs with Co.Man witnessing. 03:30 09:00 5.50 9.00 DRILL H 7 P Break circulation(iii 1/2 bpm and stage rate up(1 bbl/min every 10 minutes)to 8 bpm(g 485 psi w/no losses.Condition mud for cement job(8 bpm @ 550 psi).Final YP=17-MW=9.4 ppg.Check efficiency of mud pumps 1&2.Stage cement trucks and R/U cement lines. 09.00 13:00 4.00 13.00 DRILL H 9 P Held PJSM•SLB pump 5 bbls Mud Push and test Tines to 1000/3500 psi+SLB pump 75 bbls Mud Push @ 11 ppg(5 bpm @ 350 psi)-Drop Bottom Plug-SLB mix and pump 204 bbls Slurry @ 12.5 ppg(LiteCrete 730 sacks,1.57 Yield,mix fluid 5.494 gallsk](5 bpm @ 800 psi)-Drop Top Plug-SLB pump 10 bbls water-Switch to Rig Pump and Displace with 880 .^� I ' bbls mud @ 9.4 ppg(8 bpm @ 350->750 psi)-Bump plug @ 12:40-Pressure up casing to 1000 psi(500 psi over FCP)- C '" Release pressure and check float equipment:Ok-No losses during cement job. hoe @ 11,830'MD(3,375'ND)-Collar @ 11,743'MD] 13 00 13.30 0.50 13.50 DRILL H 9 P Perform 20 bbls injectivity test down 13 3/8"x 9 5/8"annulus.1 bpm=200 psi/2 bpm=320 psi/3 bpm=410 psi. 13.30 14.30 1.00 14.50 DRILL H 5 P W.O.C.-R/D cement head.L/D casing slips and elevator.Blow down lines. 14 30 19.00 4.50 19.00 DRILL H 1 P W.O.C.-Drain stack-RIH 01 Std 5"DP and displace 9 5/8"casing-R/D Katch Kan-L/D mouse hole-Hookup lifting cylinders and secondary slings-Prepare to lift BOP Stack. 19 00 21 30 2.50 21.50 DRILL C 5 P Raise BOP stack and Multi Bowl-Pull 9 5/8"csg to 150k lbs-Set emergency slips(100k lbs on slip)-R/U casing tagger- Cut csg and LID-Dress stump-Pull wear ring-Install pack off. 21 30 00.00 2.50 24.00 DRILL C '12 P Set BOP Stack and Multi Bowl back down-Pressure test wellhead connection to 5000 psi for 10 mire.Ok.Pressure test pack off to 2400 psi for 15 min Ok. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Em Petroleum Sr.Ddg.Spvr. 907.685-1493 Eni representative Angelo Lamarina Eni Petroleum Ddg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Robert Yundt Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Gary Gibson Eni Petroleum Tour Pusher Tool Push Brian Tiedemann Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 0.01 3,605.78 7/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kV/cm') Eq.Mud Weight(g/L) P Leakoff(kgflcm') ilio* Eni E&P Division well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • APIIUWI:50-029-23459-00-00 2^ Date:7/12/2012 - Report#: 31 I' II page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator EM Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 29.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 3,608.83 1,028.28 0.00 88.0 10.0 Clear/Fog WC 50 East @ 8 MPH Daily summary operation 24h Summary Finish to N/U BOP stack-C/O upper rams-Replace clamps,shackles and safety pins on derrick(as per audit checklist)-RIH and cull out 5"joints with bad hard band(75 joint culled)-POOH installing Wei-CD valves on stands. Operation at 07.00 POOH 5"DP installing Wei-CD valves on stands.R/B and SLM in derrick. 24h Forecast POOH 5"DP installing Wei-CD valves on stands-P/U,M/U and R/B 19 stands 5"DP-Pressure test BOP as per AOGCC requirements w/5'&4 1/2"test joint-Install Wear Bushing-M/U BHA#9-TIH picking up 4 1/2"DP 1x1 from shed(243 joints to P/U). Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 DRILL C 5 P Finish to N/U BOP Stack and Multi Bow-Install Now line-Hook up Kill and Choke lines-Install Katch Kan&pollution pan. 02:00 04:00 2.00 4.00 DRILL C 5 P Change out top rams from 9 5/8"to 4 1/2"o7"VBR. 04:00 04:30 0.50 4.50 DRILL E 1 P L/D casing elevators,Schlumberger 6 5/8"lift sub&casing bushings to the pipeshed. 04:30 09:00 4.50 9.00 DRILL E 4 P RIH with stands 5"DP,culling bad hard band joints.Total 24 UD. 09:00 16:30 7.50 16.50 DRILL E 1 P Replace cable clamps,shackles,safety pins,etc.from derrick audit checklist.Clean mud pits in preparation to take FazePro OBM.Change swabs/liners on mud pumps to 5.5".Freeze Protect 9 5/8"x 13 3/8"annulus with 165 bbls of dirty Diesel with LRS. 16:30 22:30 6.00 22.50 DRILL E 4 P Continue RIH with stands 5"DP culling out bad hard band joints.75 joints total cuNed. 22:30 00:00 1.50 24.00 DRILL E 5 P POOH 5"DP installing Wei-CD subs on stands.R/B&SLM in derrick. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Dug.Spvr. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum DrIg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Robert Yundt Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Dulling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 0.01 3.605.78 7/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') IP* Eni E&P Division well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • APIIUWI:50-029-23459-00-00Date:7/13/2012 - Repo #: 32 page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 30.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 3.608.83 1,028.28 0.00 87.0 13.9 Mostly Cloudy WC WSW @ 5 MPH 57" Daily summary operation 24h Summary POOH 5"DP installing Wei-CD valves on stands(80 total)-P/U,M/U and R/B 19 stands 5"DP-Pressure test BOP as per AOGCC requirements w/5"&4 1/2"test joint-Install Wear Bushing-M/U BHA#9-TIN picking up 4 1/2"DP 1x1 from shed to 2,876'. Operation at 07.00 RIH BHA#9 picking up 4 1/2"DP 1x1 from shed.Currenlly @ 4.995' 24h Forecast TIN picking up 4 1/2"DP 101 from shed(243 joints to P/U)-Continue RIH with stands 5"DP-Record CBL f/9,000'UFloat Collar-Casing Integrity test to 3000 psi x 30 min-Displace with 9.4 FazePro OBM-Slip and cut drilling line-Doll out cement,float collar,shoe and 20'new hole to 11,860'-Perform FIT/LOT-Drill 8 3/4"section to planned TD @ 19.437'. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 07:30 7.50 7.50 DRILL E '5 P Continue POOH 5"DP installing 80x Wei-CD subs on stands.R/B&SLM in derrick. 07:30 11:00 3.50 11.00 DRILL E 5 P P/U 57 joints of 5"DP 101 from shed and M/U.POOH and R/B in derrick. 11:00 11:30 0.50 11.50 DRILL C •5 P Pull wear bushing.Install test plug. 11:30 12:00 0.50 12.00 DRILL C 5 P M/U 5"and 4 1/2"testing equipment,TIW&dart valve. 12:00 16.00 4.00 16.00 DRILL C '12 P Test BOP as per AOGCC requirements wl 5"and 4 W test Jt-Annular @ 250-2500 psi-Rams,choke manifold,floor and top drive valves @ 250-3500 psi-Chart record-BOP test witnessed by AOGCC rep.Chuck Scheve. 16:00 17:00 1.00 17.00 DRILL C 5 P Pull test plug.L/D testing tools.Blow down lines.Line up stack and choke manifold.Install Wear bushing. 17:00 20.00 3.00 20.00 DRILL E '5 P Held PJSM.P/U and M/U BHA#9:Bit 8%"Hycalog SKH616M-E1D TFA:0.902(s/n E155414)+Xceed675 RSS(s/n 48591)+EcoScope LWD(s/n 1855)+Telescope675 MWD(E7436)+In-Line stabilizer+SonicVISION LWD(s/n A0371). NM X-Over+NM stab+x3 NM Flex DC+Float Sub+6%"Jar WTF(s/n 1416-1505)+x2 HWDP 5"+X-Over.Total length=310.02'. 20:00 00.00 4.00 24.00 DRILL E '4 P RIH BHA#9 1/310'8/2,876'picking up 4 1/2"DP 1x1 from shed(drift pipe with 2.5").Perform shallow test Schlumberger tools @ 1,500':Ok.Fit pipe every 20 stands. Daily Contacts Position Contact Name Company Title: _ E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spur. '907-685-1493 Eni representative Angelo Lamarina Eni Petroleum Drig Spur. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Robert Yundt Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mach Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Dolling Tour Pusher i Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bonom(mKB) Run Date CASING 95/8 8.835 L80 0.01 3.605.78 7/10/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 1"11141 Eni E&P Division I Well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name: Nikatchuq • API/UW1:50-029-23459-00-00 2�"i^n Date:7/14/2012 - Report#: 33 II page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N' Operator ENI Share(/4) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 31.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 3.608.83 1,028.28 0.00 85.0 7.8 Mostly Cloudy WC SE @ 4 MPH 45,. Daily summary operation 24h Summary TIH picking up 4 1/2"DP 1x1 from shed(243 joints to P/U)-Downtime due to pipe skate-Continue RIH with stands 5"DP to 9,000'-Record CBL 1/9,000'1/Float Collar(11,735')-Casing Integrity test to 3000 psi x 30 min-Displace with 9.4 FazePro OBM-Shp and cut drilling line-Pressure test Wei Manifold to 5000 psi-Drill out cement and float caftan to 11,738'. Operation at 07.00 Circulate and condition mud,Perform LOT. 24h Forecast Drill out cement,float collar,shoe and 20'new hole to 11,860'-Perform FIT/LOT-Drill 8 3/4"section to planned TD @ 19,437'. Lithology Shows MAASP(kgficm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 0430 4.50 4.50 DRILL E 4 P Continue RIH BHA#9 1/2,876'V5,300'picking up 4 1/2"DP 1x1 from shed(dnfl ad 2.5").Fill pipe every 20 stands. 04:30 0630 2.00 6.50 DRILL E 25 TR99 Downtime:Elevator arm howling cylinder broke on pipe skate.Made repairs. 06:30 10:00 3.50 10.00 DRILL E 4 P Continue RIH BHA#9 1/5,300'/8,013'picking up 4 1/2"DP 101 from shed(dnfl vd 2.5").Fill pipe every 20 stands. 10:00 11:00 1.00 11.00 DRILL E 5 P RIH BHA#91/8,013'V9,000'with stands 5"DP.Up W1=134k lbs-Dn Wt=45k lbs. 11:00 16:00 5.00 16.00 DRILL 1E 11 P RIH w/5"DPs 1/9,000'1/11.735'(Tag cement)logging CBL with Sonic Tool(speed controlled @ 900 fph). 16:00 17:00 1.00 17.00 DRILL E 7 P Circulate and condition mud for Casing Integrity Test @ 535 gpm-2500 psi. 1700 18:00 1.00 18.00 DRILL E 12 P R/U lines and test 9 5/8"casing to 3,000 psi and chart for 30 minutes as per AOGCC requirements:Ok. 18:00 20:00 2.00 20.00 DRILL E 9 P Displace well to new FazePro 9.4 ppg OBM pumping 50 bbls HiVisc spacer followed by 9.4 ppg OBM,reciprocating and rotating string(6-8 bpm @ 1200-1350 psi,60 rpm,Start Torque=12-13k nibs-Finish Torque=7.5k flibs.) 20:00 21:30 1.50 21.50 DRILL E 1 P Slip and cut 96'of drilling line.Service Top Dove.drawworks and blocks.Set and test crown saver.Clean shakers and through pits. 21:30 22:30 1.00 22.50 DRILL E 12 P R/U test pump and lines to perform Wei Manifold test.Pressure test all manifold's valves to 5,000 psi x 15 min:Ok. • 22:30 00:00 1.50 24.00 DRILL E 6 P Drill out float collar and cement 1/11,735'8/11,738'(500 gpm @ 3100 psi,60 rpm @ 8-10k#'lbs,1-25k WOB). Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum -Sr.Ddg.Spvr. 907-685-1493 Eni representative Angelo Lamanna Eni Petroleum Drlg Spvr. angelo.lamanna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Robert Yundt Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Dolling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 0.01 3.605.78 7/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 3.605.78 1,028.02 Faze Pro OBM 1126.4 44.8 1562.0 160.5 Eni E&P Division ..} Well Name:0120-07 11 ENI Petroleum Co.Inc. Daily Repo l Well Code:26484 Field Name: Nikatchuq • API/UWI:50-029-23459-00-00 2^ Date:7/15/2012 - Report#: 34 (f) page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP On/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 32.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,178.20 1,037.66 569.37 12.23 46.6 85.0 11.1 Overcast WC 52' SE @ 6 MPH Daily summary operation 24h Summary Drill out cement,shoe and 20'new hole to 11,860'-Perform FIT/LOT(EMW=13.0 ppg)-Drill 8 3/4"section to 13,708'. Operation at 07.00 Drill 8 3/4"section @ 14,002' 24h Forecast Doll 8 3/4"section to planned TD @ 19,437'. Lithology Shows MAASP(kgflcm°) Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 03.00 3.00 3.00 DRILL E 3 P Drill out cement,shoe and rat hole 1/11,738'1/11,840'(500 gpm @ 2700 psi,60 rpm @ 8+10k Albs,WOB=1+20k lbs,MW= 9.4 ppg)-Drill rotary 0 8%"new hole 811,840'811,860'(500 gpm @ 2800 psi, 60 rpm @ 9=10k fibs,WOB=5+10k lbs, MW=9.4 ppg). 03:00 04:30 1.50 4.50'DRILL E 7 -P Circulate B/U and condition FazePro mud for LOT(500 gpm @ 2700 psi-Mud Wt 9.4 ppg)-POOH into shoe. 04,30 05:30 1.00 5.50'DRILL E 11 P Rig up lines and perform LOT with 9.4 ppg FazePro OBM-Surface pressure of 637 psi-EMW=13.0 ppg. V/ 0530 12:00 6.50 12.00'DRILL E 3 P Drilling Rotary Steerable 0 8%"section(/11,860'1/12,330'\500-550 gpm @ 2700-2870 psi\120 rpm @ 11+12k ft-lbs\ WOB=0+10k lb\Up wt 150k lb-Rot wt 100k lb I Mud wt 9.4 ppg\ECD=11.8-Take survey as needed-Ream and wash one joint every connection-Use E-CD for connections. 12:00 00:00 I 12.00 24.00-DRILL E 3 P Drilling Rotary Steerable 0 8./."section 512,330'813,708'(3,404'TVD)\550 gpm @ 3500 psi\140 rpm @ 15.17k Ribs\ WOB=2=15k lb\Up wt 160k lb-Rot WA 98k lb\Mud wt 9.4 ppg\ECD=11.93-Take survey as needed-Ream and wash one joint every connection-Use E-CD for connections.Occasional hard drilling. [ADT=12.23 Hrs-JARS=98,1 Hrs]. Daily Contacts Position Contact Name Company Title E-mail Office Mobile - Eni representative Ben Perry Eni Petroleum Sr.Drig.Spin-. 907-685-1493 Eni representative Angelo Lamarina Eni Petroleum DrIg Spvr. angelo.lamarina@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Robert Yundt Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinate Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Dulling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 0.01 3,605.78 7/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm°) Eq.Mud Weight(gIL) P LeakOff(kgflcm°) 3.605.78 1,028.02 Faze Pro OBM 1126.4 44.8 1562.0 160.5 I* Enl E&P Division I Well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name: Nikatchuq Date:7/16/2012 - Report#: 35 APIIUWI:50-029-23459-00-00 2" "u page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5.504.08 245.06 22.5 33.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,448.25 1,035.52 270.05 6.91 39.1 83.0 10.6 Clear WC 51' WSW @ 11 MPH Daily summary operation 24h Summary Drill 8 3/4"section 1/13,708'1/15,880'(3,399'TVD). Operation at 07.00 Drill 8 3/4"section @ 16,260'. 24h Forecast Drill 8 3/4"section to planned TD @ 19,437'. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 12:00 12.00 12.00 DRILL E -3 -P Drilling Rotary Steerable 0 8%"section 613,708'1114,594'(3,397'TVD)\550 gpm @ 3540 psi\140 rpm @ 17,18k 9'lbs`, WOB=2.15k lb\Up v.4 160k lb-Rot v4 95k lb\Mud v1 9.4 ppg\ECD=12.1-Take survey as needed-Ream and wash one stand every connection-Use E-CD for connections.Occasional hard drilling. 12.00 00:00 12.00' 24.00"DRILL 'E 3 •P Drilling Rotary Steerable 0 8 G'section 1/14,594'1/15,880'(3,399'TVD)1 550 gpm©3565 psi 1 140 rpm @ 16.20k bibs 1 WOB=2.15k lb 1 Up vA 175k lb-Rot wt 100k lb 1 Mud wt 9.4 ppg I ECD=12.25-Take survey as needed-Ream and wash one stand every connection-Use E-CD for connections.Occasional hard drilling. [AN=14.65 Hrs-JARS=112.8 Hrs]. Daily Contacts Position _ Contact Name _ Company Title E-mail _ Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Drlg.Spvr. 907-685-1493 Eni representative Angelo Lamanna Eni Petroleum Drtg Spvr. angelo.lamanna@enipetroleum.corn 907-685-1493 907-903-7269 Eni representative Robert Yundt Eni Petroleum HOE 907-6685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Dolling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date • CASING 9 5/8 8.835 L80 0.01 3,605.78 7/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3.605.78 1,028.02 Faze Pro OBM 1126.4 44.8 1562.0 160,5 1"411411 Eni E&P Division I Well Name:0120-07 EN!Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • API/UWI:50-029-23459-00-00 2 n o Date:7/17/2012 - Report#: 36 II II II page 1 of 1 Wellbore name: 0120-07 Well Header PermitIConcession N' Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 34.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 4,718.00 1,038.11 149.05 6.24 23.9 86.0 5,0 Clear WC 37" SE @ 6 MPH Daily summary operation _ 24h Summary Drill 8 3/4"section(/15,880'016,461'-Sidetracked for geological reasons @ 14.990'-Drill 8 3/4"section 1/14,990'015,479'(3,407'TVD). Operation at 07.00 Drill 8 3/4"section @ 15,890' 24h Forecast Drill 8 3/4"section to planned TD @ 19,437'. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06.30 6.50 6.50 DRILL E 3 P Drilling Rotary Steerable 0 8'A"section 1/15,880'016,461'1 500 gpm @ 3340 psi 1140 rpm @ 17*18k Ribs\WOB=1*10k lb\Up wt 170k k1-Rot wt 100k lb\Mud wt 9.4 ppg\ECD=12.2-Take survey as needed-Ream and wash one stand every connection-Use E-CD for connections. Drilled through possible fault at 16,106'. At 16,264'started loosing mud at-50 bph.Lost 138 bbls.Pump 40 bbl LCM pill, losses slowed to-46 bph. An evaluation of well position showed that we had drilled through the 0A4 sand and into the canning shale from 16,106'to 16,461'.Decision was made to back up to-15,000'and sidetrack. 06.30 0900 2.50 9.00 DRILL F 9 U BROOH 016,461'1/16,200'.Mix and spot 50 bbls LCM pill @ 9.9 ppg in open hole section from 16,200'to 15,600'. 09:00 1300 4.00 13.00 DRILL F 6 U BROOH dry(No pumps)016,200'1/14,980'v.th 35-40 rpm.Pulled at 7 min per stand:no issues,hole slick. 13:00 18.00 5.00 18.00 DRILL F 3 U Timedrilling for sidetrack 1/14,990'015,046'@ 2->20 fph 1 500 gpm©3000 psi 1160 rpm @ 16k ftlbs\WOB=10k lb\Up wt 155k lb-Rot wt 100k lb\Mud wt 9.3+ppg.Take survey as needed to confirm sidetrack. 18:00 00.00 ' 6.00 24.00 DRILL E 3 P Drilling Rotary Steerable 0 8 G"section 1/15,046'1/15,479'(3,407'TVD)\550 gpm @ 3585 psi 1140 rpm @ 17+20k Bibs\ WOB=2+15k lb\Up wt 170k lb-Rot wt 100k lb\Mud wt 9.3 ppg\ECD=11.81-Take survey as needed-Ream and wash one stand every connection-Use E-CD for connections.Occasional hard drilling. (ADT=10.44 Hrs-JARS=125.0 Hrs].Total Loss's to formation 278 Bbl's Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. -907-685-1493 Eni representative Angelo Lamanna Eni Petroleum Drlg Spvr. angelo.lamadna@enipetroleum.com 907-685-1493 907-903-7269 Eni representative Robert Yundt Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Dulling Tool Pusher 907-670-1492 Tool Push Brian Tiedemann Nabors Alaska Dulling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 0.01 3.605.78 7/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3.605.78 1,028.02 Faze Pro OBM 1126.4 44.8 1562.0 160.5 Eni E&P Division I Well Name: 0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq e API/UWI:50-029-23459-00-00 2�, Date:7/18/2012 - Report#: 37 If 'I page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72` 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 35.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,347.11 1,023.09 336.19 8.05 41.8 84.0 3.9 Clear WC 39' Calm Daily summary operation 24h Summary Drill 8 3/4"section(/15479'017543'(3354'TVD) Operation at 07.00 Drill 8 3/4"section @ 17,653' 24h Forecast Dn118 3/4"section to planned TD @ 19437' Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Deser. 00:00 12:00 12.00 12.00 DRILL E 3 P Drilling Rotary Steerable 0 85"section 8/15479'1116440'(3374'TVD)\550 gpm @ 3690 psi\80+140 rpm @ 16+17k ft•Ibs \WOB=2,15k lb\Up wt 155k lb-Rot vie 100k Ib\Mud Wt 9.3 ppg-Take survey as needed-Ream and wash one stand every connection•Use E-CD-Occasionally hard drilling 12:00 00:00 12.00 24.00 DRILL E 3 P Drilling Rotary Steerable 0 8%"section(/16440'1/17543'(3354'TVD)\550 gpm @ 3950 psi\140 rpm @ 20-17k ft•lbs\ WOB=5+14k lb\Up Wt 185k lb-Rot wt 92k lb\Mud wt 9.3+ppg I ECD=12.2-Take survey as needed-Ream and wash one stand every connection-Use E-CD-Occasionally hard drilling (ADT=14.17 Hrs-JARS=139.14 Hrs]-Mud lost to formation 306 bbl Daily Contacts Position Contact Name Company Title E-mail Office _ Mobile Eni representative Ben Perry 'Eni Petroleum Sr.Dig.Spvr. '907-685-1493 Eni representative Mirko Musumeci Eni Petroleum DrIg Spvr. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 0.01 3.605.78 7/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) •Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm°) 3,605.78 1,028.02 Faze Pro OBM 1126.4 44.8 1562.0 160.5 1191* Eni E&P Division IWell Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • APIIUIM:50-029-23459-00-00 2 �I^n Date:7/19/2012 - Report#: 38 I) II page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5.504.08 245.06 22.5 36.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,776.57 958.53 429.46 13.85 31.0 83.0 7.8 Clear WC 42' S @ 8 MPH Daily summary operation 24h Summary Drill 8 3/4"section(/17543'to TD(18952'MD-3154'TVD)-Circulate BU-BROOH Operation at 07.00 BROOH©17,359' 24h Forecast BROOH to 17050'(10?5 min/Std)-Short clean up cycle-BROOH Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 12.00 12.00 12.00 DRILL E 3 •P Drilling Rotary Steerable 0 8%"section(/17543'1118232'(3308'TVD)\535 gpm @ 3800 psi\80*120 rpm @ 16+18k ft•Ibs \WOB=10k lb\Up wt 172k lb-Rot wt 100k lb I Mud wt 9.3+ppg-Take survey as needed-Ream and wash one stand every connection-Use E-CD-Occasionally hard drilling 12'00 21 00 9.00 21.00 DRILL E 3 'P 'Drilling Rotary Steerable 0 8%"section f/18232'11TD(18952'MD-3154'TVD)\530 gpm @ 3930 psi\120 rpm @ 17*19k ft•lbs\WOB=2+10k lb I Up wt 185k lb-Rot wt 89k lb I Mud wt 9.3+ppg-Take survey as needed-Ream and wash one stand every connection-Use E-CD-Occasionally hard drilling [ADT=13.85 Hrs-JARS=143.39 Hrs) 21'.00 22'.30 1.50 22.50 DRILL E '3 •P Circulate BU while BROOH xl Std(/18952'5/18823'(550 gpm @ 4k psi-140 rpm©19k ft•Ibs) 22.30 0000 1.50 24.00 DRILL E 3 •P BROOH 1/18823'1118429'(550 gpm @ 4k psi-140 rpm @ 19k ft•Ibs-20?10 min/Std) Mud lost to formation 733 bbl Daily Contacts Position Contact Name Company Title E-mail Office Mobile- Eni representative Ben Perry Eni Petroleum 'Sr.Ddg.Sp, 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Drlg Spvr. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling 'Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 95/8 8.835 L80 0.01 3,605.78 7/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm°) Eq.Mud Weight(g/L) P LeakOff(kgflcm.) 3.605.78 1,028.02 Faze Pro OBM 1126.4 44.8 1562.0 160.5 If* Eni E&P Division I Well Name:0120-07 EN!Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq 2^� Date:7/20/2012 - Report#: 39 APIIUWI:50-029-23459-00-00 II II page 1 of 1 Wellbore name: 0120-07 • Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL • Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) • 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 37.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP Warr) POE Temperature(CC) Weather Wind 5.776.57 958.53 0.00 85.0 5.0 Overcast WC 38' ENE @ 5 MPH Daily summary operation 24h Summary BROOH to 17050'(1075 min/Std)-Short clean up cycle-BROOH to 12700' Operation at 07.00 BROOH @ 11,840' 24h Forecast BROOH 1/12700'1/8100'-C/O elevators and Saver sub-Flow check 30 min-BROOH(/8100'53000'-Circulate hole clean-POOH on elevators-POOH and L/D BHA Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 05:00 5.00 5.00 DRILL E '6 P BROOH 1/18429'517050'(550 gpm @ 4000?3800 psi-140 rpm @ 18.5?17k ft'lbs-10?5 min/Std) 05.00 '11:00 ' 6,00 11.00 DRILL E 6 P Short clean up cycle:Circulate x5 BU(450 gpm @ 3800?3650 psi-140 rpm @ 17k ft'lbs)Rack back x1 Std each BU f/17050'V16850'and 2 Sid each BU f/16850'516270' 11:00 00:00 ' 13.00 24.00 DRILL 'E -6 P BROOH f/16850'1/12700'(550 gpm @ 3800?3200 psi-140 rpm @ 17?13.5k ft'lbs-5.7 min/Std) Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ng Spvr. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinate Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 0.01 3,605.78 7/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 3,605.78 1,028.02 Faze Pro OBM 1126.4 44,8 1562.0 160.5 Ifif* Eni E&P Division .. I Well Name:0120-07 EN!Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • APIIUWI:50-029-23459-00-00 2^ Date:7/21/2012 - Report#: 40 I( II page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator EM Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 38.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 5,776.57 958.53 0.00 85.0 6.1 Clear WC 38° SSE @ 9 MPH Daily summary operation 24h Summary BROOH(/12700'88010'-C/O elevators and Saver sub-Flow check 30 min-BROOH 1/8010'52900'-Circulate hole clean Operation at 07.00 Troubleshoot on Iron roughneck 24h Forecast Troubleshoot on Iron roughneck-POOH on elevators-POOH and L/D BHA#9-P/U,M/U and RIH BHA#10(Dumb iron BHA) Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1078.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. . Act. Plan Oper.Descr. 00:00 13:00 - 13.00 13.00-DRILL E 6 P BROOH(/12700'88010'(550 gpm @ 320072500 psi-140?120 rpm @ 15?6k(fibs-5?2.5 min/Std) 13:00 14:00 1.00 14.00 DRILL E '5 'P Flow check 30 min(23 bbl gain)-C/O Saver Sub-C/O Elevators 14.00 23:00 9.00 23.00 DRILL 'E '6 P BROOH 88010'82900'(550 gpm @ 2500?1600 psi-120 rpm @ 672.5k Ribs-2.5 min/Std) 23:00 00:00 ' 1.00' 24.00'DRILL E 7 P Circulate hole clean(550 gpm(§1600 psi-115 rpm 2k Ribs)-Continue to circulate(550 gpm @ 1600 psi-no rotation) prepare to troubleshoot on iron roughneck Daily Contacts Position Contact Name _ Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum DrIg Spar. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 0.01 3.605.78 7/10/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 3,605.78 1,028.02 Faze Pro OBM 1126.4 44.8 1562.0 160.5 11"1* Eni E&P Division I Well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • API/UWI:50-029-23459-00-00 2�, Date:7/22/2012 - Report#: 41 If II II page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5.924.40 970.76 5,504.08 245.06 22.5 39.00 • Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,776.57 958.53 0.00 88.0 10.0 Clear WC 50" E @ 7 MPH • Daily summary operation 24h Summary Troubleshoot on Iron roughneck-POOH on elevators-POOH and L/D BHA#9-P/U,M/U and RIH BHA#10(Dumb iron BHA)to 4767'-POOH on elevators due to DPs connections under torque Operation at 07.00 Working on iron ruff neck torque gauge. 24h Forecast POOH on elevators checking M/U torque-RIH BHA#10 to 17100'-Circulate BU-Displace Breaker fluid-POOH on elevators as per KW trip schedule Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1078.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase_ Opr. Aet. Plan Oper.Deser. 00:00 02:00 2.00 2.00 DRILL E 25 P Service TDS,draw works,Handling equipment-Troubleshoot on Iron roughneck.Lower jaws sheared bolts 0200 13.00 11.00 13.00 DRILL E 25 TR99 Downtime-Troubleshoot on Iron roughneck:Lower jaws sheared bolts 13:00 16:00 3.00 16.00 DRILL E 4 P POOH on elevator(/2900'6310'(Proper displacement) 16:00 19.00 3.00 19.00 DRILL E 5 P POOH and L/D BHA#9(Bit Dull:1-1-WT-A-X-1-NO-TD)-Download MWD tools 19:00 22:30 3.50 22.50 DRILL E 4 P M/U BHA#10 I8'/."Hole Opener+Bit Sub ed float+x9 Jt 5"DPs+Jar+x2 HWDP 5"+XO)and RIH on elevators 1/4767' NOTE: Torque gauge on Iron Roughneck not rightly set,Pull x2 Std and check M/U torque:under torque 22:30 00:00 1.50 24.00 DRILL E 4 TR99 POOH on elevator checking M/U torque 1/4577'63815' Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry -Eni Petroleum Sr.Dog.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Drtg Spvr. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher )907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 0.01 3.605.78 7/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm.) Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3,605.78 1,028.02 Faze Pro OBM 1126.4 44.8 1562.0 160.5 IEni E&P Division I Well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • API/LINA:50-029-23459-00-00 ,;, Date:7/23/2012 - Report#: 42 �fi page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 40.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) FOB Temperature(°C) Weather Wind 5,776.57 958.53 0.00 88.0 15.0 Overcast WC 59° WSW @ 5 MPH Daily summary operation 24h Summary POOH on elevators checking M/U torque-Troubleshoot on iron roughneck-RIH BHA#10 to 15900' Operation at 07.00 Circulate to condition mud-Load and ship breaker fluid from MI mud plant 24h Forecast RIH BHA#10 1/15900'517100'-Circulate to condition mud-Displace Breaker fluid-POOH on elevators as per K&M trip schedule Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1078.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 DRILL E 4 TR99 POOH on elevator checking M/U torque f/3815 to surface 03:30 06:00 2.50 6.00 DRILL E 25 TP99 Downtime-Troubleshoot on Iron roughneck:Replace valve bank 06:00 10:30 4.50 10.50 DRILL E 4 TP99 RIH BHA#10 on elevator 54717' 10:30 13:00 2.50 13.00 DRILL E 4 P Continue to RIH on elevator f/4717'58010'-Fill pipe every 2000'-Proper displacement 13:00 15:00 2.00 15.00 DRILL E 5 P C/O elevators and Saver sub-C/O gripper heads in TDS 15:00 17:00 2.00 17.00 DRILL E 4 P Continue to RIH on elevator f/8010'511633'-Fill pipe every 2000'-Proper displacement 17:00 20:00 3.00 20.00 DRILL E 2 P Slip and cut 93'DL-R/D MWD equipment and sensor off rig floor 20:00 00:00 4.00 24.00 DRILL E 4 P Continue to RIH on elevator 1/11633'515900'-Fill pipe every 2000'-Proper displacement,Wash and ream down 513394' • 513500'(200 gpm @ 450 psi-40 rpm©8k(fibs) Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.DrIg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 0.01 3.605.78 7/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3,605.78 1,028.02 Faze Pro OBM 1126.4 44.8 1562.0 160.5 fill*• Eni E&P Division I Well Name: 0120-07 1 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • 2 II�,,t Date:7/24/2012 - Report#: 43 APIIl1W1:50-029-23459 -00 11 page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mK8) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 41.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,776.57 958.53 0.00 86.0 12.2 Overcast WC 54' S @ 8 MPH Daily summary operation 24h Summary RIH BHA#10 1/15900'1/17100'-Circulate to condition mud-Displace Breaker fluid-POOH on elevators as per KW trip schedule to 11600'-Clean pits and prepare to displace brine Operation at 07.00 waiting for Vac truck to displace brine. 24h Forecast Complete to clean pits and prepare to displace 9.1 ppg Brine(Breaker shipping delayed due to a ng move on the way)-Displace Brine 611600'to surface-POOH on elevators-R/U GBR-4'A"liner job Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1078.4 Time Log Start End Cum , Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01:30 1.50 1.50 DRILL E 4 P Continue to RIH on elevator f/15900'617110'-Fill pipe every 2000'-Proper displacement-No tight spot encountered 01'.30 10:30 9.00 10.50 DRILL E 7 P Circulate to condition mud(200 gpm @ 720 psi-60 rpm @ 11+12k Bibs-MW 9.8?9.5 ppg)at BU on surface 1850 units gas-Connected Vac Trucks with mud pump-PJSM 10:30 14.30 4.00 14.50 DRILL E 9 P Displace 8%"Open Hole from 9.4 ppg FazePro to 9.5 ppg FazeAway breaker fluid-Pumped 410 bbl FazeAway(110 gpm @ 450?390 psi-60 rpm @ 11.5k ft-lbs)-Displaced with 137 bbl FazePro+30 bbl 11.4 ppg Pill+12 bbl FazePro 14:30 22:30 8.00 22.50 DRILL E 4 P POOH on elevators 617110'611600'(20?5 min/Std)-5 bbl/Hr average losses Tight spot @ 13503'+13484'5/10k lbs overpull-@ 12518'30k lbs overpull and set down take string weight,worked trough with 50 rpm than check hole condition:free up/down without rotation 22 30 00.00 1.50 24.00 DRILL E 1 P Continue to clean pits and prepare to displace 9.1 ppg Brine 3%KCI-Breaker shipping delayed due to a rig move on the way Daily Contacts Position Contact Name Company • Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum 'Sr.Ddg.Spvr. 907-685-1493 - Eni representative Moire Musumeci Eni Petroleum Drig Spvr. 907-685.1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Steve Abbott Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 0.01 3.605.78 7/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgllcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3.605.78 1,028.02 Faze Pro OBM 1126.4 44.8 1562.0 160.5 Eni E&P Division I Well Name:0120-07 EN!Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq Tri°1*1 • APIIUWI:50-029-23459-00-00 2 II^r, Date:7/25/2012 - Report#: 44 'I II page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 42.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,776.57 958.53 0.00 87.0 12.2 Scattered Clouds East @ 7 MPH Daily summary operation 24h Summary Complete to clean pits and prepare to displace 9.1 ppg Brine(Breaker shipping delayed due to a rig move on the way)-Displace Brine 1/11600'to surface-POOH on elevators-R/U GBR-RIH 4'4" liner to 620' Operation at 07.00 RIH 4 V'Liner @ 2,306' 24h Forecast P/U,M/U and RIH 4'A"liner as per tally-Install SLZXP Baker liner hanger-RIH liner vd 4 W45"DPs as per tally to 17164' Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1078.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06.00 6.00 6.00 DRILL 'K 8 P Continue to clean pits and prepare to displace 9.1 ppg Brine 3%KCI-Breaker shipping delayed due to a rig move on the way-Connected Vac Trucks-Transfer 3%KCI Brine 9.1 ppg to rig pits-PJSM 06:00 09:30 3.50 9.50 DRILL 'K 9 P Displace hole(from 11600'to surface)to 9 ppg Bone(3%KCI)820 bbl(260 gpm©500 psi-40 rpm©6714k fllbs) 09:30 13:00 3.50 13.00 DRILL K 20 P Clean pits,shakers,possum belly and lines 13.00 1830 5.50 18.50 DRILL 'K 4 P POOH BHA#10 f/11600'V393' 18.30 21:00 2.50 21.00 DRILL K 5 P Complete to POOH and UD BHA#10 21.00 22:30 1.50 22.50 DRILL '0 2 P R/U GBR 4''A"liner running equipment 2230 00:00 1.50 24.00 DRILL G 5 P PJSM-P/U,M/U and RIH Liner 4 1/2'11.69 L80 HYD521(M/U torque 6.3k fobs)V620'installing ICD valve and water swell packer as per tally-Top fill every 10 Jt Daily losses<10 bbl Daily Contacts Position Contact Name Company Title E-mail Office • Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. -907-685-1493 Eni representative Mirko Musumeci Eni Petroleum DrIg Spvr. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Mitch Billington Eni Petroleum Rig Clerk 907-670-8601 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670.1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date CASING 9 5/8 8.835 L80 0.01 3605.78 7/10/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3.605.78 1,028.02 Faze Pro OBM 1126.4 44.8 1562.0 160.5 Eni E&P Division I Well Name:0120-07 If* EN/Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • Date:7/26/2012 - Report#: 45 API/UWI:50-029-23459-00-00 e i ii page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name .Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924,40 970.78 5,504.08 245.06 22.5 43.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5.776.57 958.53 0.00 80.0 11.7 Partly Cloudy WC East C 6 MPH 53" Daily summary operation 24h Summary P/U,M/U and RIH 4 G"liner as per tally-Install SLZXP Baker liner hanger-RIH liner w/4 G"+5"DPs as per tally to 13280' Operation at 07.00 POOH and rack back 4'''A"DPs 24h Forecast Continue to RIH 4'A"liner w/4%"+5"DPs as per tally to 17164'-Set Liner hanger-Test Hanger 1500 psi 10 min-POOH and rack back 5"DPs-POOH and L/D 4 V DPs-BOP test as per AOGCC Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1078.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 10:00 10.00 10.00 DRILL G 5 P Continue to P/U,M/U and RIH Liner 4 1/2"11.6#L80 HYD521(M/U torque 6.3k fl4bs)(/620'1/5532'installing ICD valve and water swell packer as per tally-Top 011 every 10 Jt 10:00 11:00 1.00 11.00 DRILL G 5 P P/U&M/U SLZXP liner hanger-Fill Tieback sleeve with"pal mix"(wait 30'to set up)-Partially R/D GBR equipment 11:00 12:30 1.50 12.50 DRILL G 5 P C/O Elevator-C/O Saver sub-Adjust gripper 12:30 13:30 1.00 13.50 DRILL G 4 P RIH 5%"Liner on 4'G"DPs 8/5532'1/6005' 13:30 16:30 3.00 16.50 DRILL G 25 P C/O swivel packing leaking,grease and test 3500 psi 16:30 20:30 4.00 20.50 DRILL G 4 P Continue to RIH''/:'Liner on 4'A"DPs V6005'1/13280'-Fill pipe every 2000'(@11753'.Up wt 125k lbs-Dwwt 65k lbs-Rt wt 95k lbs) 20:30 21:00 0.50 21.00 DRILL G 5 P C/O saver sub and elevators 21:00 00:00 3.00 24.00 DRILL G 4 P Continue to RIH'A'Liner on"DPs f/13280'1/15960'-Fill pipe every 2000' Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Ben Perry Eni Petroleum 'Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Ddg Spvr. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 3,535.99 5.231.59 7/26/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 3605.78 1,028.02 Faze Pro OBM 1126.4 44.8 1562.0 160.5 I En/E&P DivisionWell Name:0120-07 OW* ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • API/UW1:50-029-23459-00-00 enI - Date:7/27/2012 - Report#: 46 II �Ipage 1 of 1 Wellbore name: 0120-07 Well Header PermiVConcession N° Operator ENI Share(14) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 44.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,776.57 958.53 0.00 79.0 10.6 Scattered Clouds WNW @ 4 MPH WC 51" Daily summary operation 24h Summary Continue to RIH 4'"liner w/4%"+5"DPs as per tally to 17164'-Set Liner hanger-Test Hanger 1500 psi 10 min-POOH and rack back 5"DPs-POOH and L/D 4%"DPs-BOP test as per AOGCC Operation at 07.00 RIH 5"DPs and LID ECD subs 24h Forecast Complete BOP test-Pull test plug-LID testing equipment-Set wear ring-RIH and L/D ECD subs-POOH and LID 5"DPs-R/U 4'/:"completion running tools-4%"Completion job Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1078.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 II 1.00 DRILL G 4 P Continue to RIH 4 14'Liner on 5"DPs(/15960'5/17018'-Fill pipe every 2000' 01:00 01:30 0.50.. 1.50 DRILL G 4 P Ream down 4 14"Liner on 5"DPs 1/17018'V17203'(25-30 rpm @ 15k 6-lbs surf.Torque-Up w1 170k lbs) 01:30 04:00 2.50' 4.00 DRILL G 19 P Pull liner in tension(160k lbs)-Drop setting ball-Start pump(3 bpm @ 680 psi)-Pressure up to 3000 psi to set hanger- Pressure up to 3500 psi to shear bypass-Pressure up to 4000 psi and held 10'-Set 80k lbs on hanger-Running tool released(Up wt=157k lbs) 4%"Shoe @ 17164' TOL @ 11601' Water swell packer @ 17155.8'/17102.1'/16277'115288.2'/14339.2'/13340.1' Hall ICD valves(All in open position)@ 16836.7'/16532.9'/15971.5'/15626.3'/14985.9'/14638.8'/14033.5'/13679.9'/ 12961.1'/12580.5'/12197' 04.00 07.00 3.00. 7.00 DRILL G 4 P POOH and rack back 5"DPs(/11601'1/7751' 07.00 19'00 12.00 19.00 DRILL G 5 P POOH,BIO and L/D 4 Yr'DPs(/7751'to surface-L/D and inspected HRD running tool 19.00 20.00 1.00 20.00 DRILL C 1 -P Pull wear nng-Set test plug-R/U BOP test equipment-Fill stack and choke with water 20.00 00:00 4.00. 24.00 DRILL C 12 P Test BOP as per AOGCC requirements w/4 W and 5'test Jt-Annular @ 250?2500 psi-Rams,choke manifold.floor and top dove valves @ 250?3500 psi-Chart record-BOP test waived by AOGCC rep.John Crisp-In progress Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Drlg Spvr. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 3,535.99 5.231.59 7/26/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 3,605.78 1,028.02 Faze Pro OBM 1126.4 44.8 1562.0 160.5 Eni E&P Division ..} I Well Name:0120-07 WirtENI Petroleum Co.Inc. Daily Repo l Well Code:26484 Field Name:Nikatchuq • APIIUWI:50-029-23459-00-00 2^H,t Date:7/28/2012 - Report#: 47 - II Ii page 1 of 1 wellbore name: 0120-07 Well Header Permit/Concession N° Operator EM Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 45.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(Br) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5,776.57 958.53 0.00 79.0 12.8 Clear WC 55' East @ 9 MPH Daily summary operation 24h Summary Complete BOP test-Pull test plug-L/D testing equipment-Set wear ring-RIH 5"DPs Std and L/D ECD subs-Clean contaminated brine-RIH to packer depth to circulate and clean brine(in progress) Operation at 07.00 Build up HI Vis pill and prepare to circulate hole dean. 24h Forecast P/U,M/U and RIH t/11470'(Planned Packer depth)-Build up Hi Vis pill-Circulate hole clean-POOH and LID 5"DPs-R/U 4%"completion running tools-4''A"Completion job Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1078.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:30 2.50 2.50 DRILL C 12 P Complete test BOP as per AOGCC requirements w/4 W and 5"test Jt-Annular @ 250?2500 psi-Rams,choke manifold. Floor and top drive valves @ 25073500 psi-Chart record-BOP test waived by AOGCC rep.John Crisp 02:30 03:30 1.00 3.50 DRILL C 5 P Pull test plug-UD testing equipment-Set wear ring 03:30 10:00 6.50 10.00 DRILL E 5 P RIH 5"DPs Std to 8360'-B/O and L/D ECD subs 10:00 10:30 0.50 10.50 DRILL E 7 TP99 Noticed presence of contaminated brine in hole,circulate out to cuttings box(10 bpm @ 700 psi) 10:30 11:00 0.50 11.00 DRILL E 4 P RIH 5"DPs Std 58360'09500' 11:00 14:30 3.50 14.50 DRILL E 5 P POOH and UD 5"DPs Jts(/9500't/7315' 14:30 16:30 2.00 16.50 DRILL E 4 P RIH 5"DPs Std f/7315'1/9400'(contaminated bone coming out from displacement) 16:30 17:30 1.00 17.50 DRILL E 25 P Service ng:TDS,draw works,pipe skate,blocks 17:30 22:00 4.50 22.00 DRILL E 7 TP99 Clean out mud system from contaminated brine-Load 290 bbl new brine in rig pits-Circulate to dean brine(450 gpm @ 600 psi)-Large amount of contaminated bone plug the flow line-Reduce flow rate and continue to circulate to dean brine (350 gpm @ 260 psi)-Clean mud system and skim off contaminated bone surface Contaminated brine: Pressurized weight 9 ppg-pH 10.5-Color Light brown-Viscosity as"peanut butter" 22:00 00:00 2.00 24.00 DRILL E 4 TP99 Load shed wl 5"DPs-P/U,M/U and RIH 5"DPs 59400'1/9689' Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Em Petroleum Sr.Dug.Spvr. '907-685-1493 Eni representative Mirko Musumeci Eni Petroleum DrIg Spvr. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Dolling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 3,535.99 5.231.59 7/26/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 3,605.78 1,028.02 Faze Pro OBM 1126.4 44.8 1562.0 160.5 I It* Eni E&P Division Melt Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq •Il Date:7/29/2012 - Report#: 48 API/UWI:50-029-23459-00-00 2" " page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970.78 5,504.08 245.06 22.5 46.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) FOB Temperature(°C) Weather Wind 5,776.57 958.53 0.00 79.0 13.9 Clear WC 57' South @ 9 MPH Daily summary operation 24h Summary P/U,M/U and RIH 5/11470'(Planned Packer depth)-Build up Hi Vis pill-Circulate hole clean-POOH and LID 5"DPs Operation at 07.00 POOH and UD 5"DPs Jts @ 1,730" 24h Forecast Complete to POOH and L/D 5"DPs-R/U 4'''A"completion running tools-4 G"Completion job Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1078.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 DRILL E 4 TP99 P/U,M/U and RIH 5"DPs f/9689'1/11475'(contaminated brine coming out from displacement) 03:00 09:30 6.50 9.50 DRILL E 7 TP99 Circulate to clean brine(200?400 gpm©100?560 psi)-Clean mud system and skim off contaminated brine surface-Load 870 bbl new brine in ng pits-Hook up lines to take dirty return to vac truck 09:30 11:00 1.50 11.00 DRILL E 7 TP99 Circulate 40 bbl Hi Vis sweep followed by new 9 ppg Brine(440 gpm©550 psi-50 rpm©15k Ribs)until flow back clean 11:00 20:30 9.50 20.50 DRILL E 5 P POOH and UD 5"DPs Jts f/11475'54173' 20:30 00:00 3.50 24.00 DRILL E 25 •TR99 Troubleshoot-Lifting pipe skate tray failed,repair links Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum .'Sr.Dug.Spvr. - 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Drig Spur. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Bruce Simonson Nabors Alaska Dolling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Can.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 4 1/2 'L80 3.535.99 5.231.59 7/26/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 3.605.78 1,028.02 Faze Pro OBM 1126.4 44.8 1562.0 160.5 Eni E&P Division [Well Name:0120-07 OW* ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • en 0 Date:7/30/2012 - Report#: 49 API/WN:50-029-23459-00-00 II 'I page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 DRILLING 6/14/2012 5,924.40 970,78 5,504.08 245.06 22.5 47.00 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 5.776.57 958.53 0.00 Daily summary operation 24h Summary Operation at 07.00 24h Forecast xxx Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1078.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 LBO 3,535.99 5,231.59 7/26/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 3.605.75 1.028.02 Faze Pro OBM 1126.4 44.8 1562.0 160,5 Illi* Eni E&P DivisionWell Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name: Nikatchuq • Date:6/30/2012 - Report#: 1 APIIUWI:50-029-23459-00-00 ' i i fi page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND.. Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 COMPLETION 7/30/2012 5,924.40 970.78 0.01 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 79.0 11.1 Overcast WC 52" Calm Daily summary operation 24h Summary POOH and L/D 5"DPs-R/U 4'A"completion running tools-RIH 4'''A"Completion string to 10239' Operation at 07.00 Performing space out 24h forecast Complete to RIH 4 W Completion string-Space out-Set and test tubing hanger-Set PHL packer-Tubing integrity test-Shear mirage plug-Shear GLM valve-Set BPV-N/D BOP Stack N/U Production Tree Lithology Shows MAASP(kgflcm') Mud Weight(gIL) Time Log Start End Cum Time _ Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 DRILL E 5 P POOH and UD 5"DPs Jts(/4173'to surface 06:00 06:30 0.50 6.50 COMP C 5 P Pull and L/D wear bushing 06:30 08.00 1.50 8.00 COMP K 2 P R/U completion running tools 08:00 00.00 ' 16.00 24.00 COMP K 5 P PJSM-P/U and M/U Tieback entry guide+Mirage plug assembly+Halliburton PHL Packer assemblies and RIH completion string inn 4 W 12.68 L80 HYD563 tbg 1/10239'(Up wt 95k lbs-Dw wt 52k lbs-M/U Tq 3.8k Ribs)as per tally Daily Contacts Position Contact Name Company Tide E-mail Office Mobile Eni representative Ben Perry Eni Petroleum 'Sr.Dig.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Drig Spvr. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Matenals Coordinato Tool Push Bruce Simonson Nabors Alaska Dnlling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 3,535.99 5231.59 7/26/2012 Last Leakoff Test Depth(mKB) ND(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 3.605.78 1,028.02 Faze Pro OBM 1126.4 44.8 1562.0 160.5 111* Eni E&P Division `Well Name:0120-07 ENI Petroleum Co.Inc. Daily Report Well Code:26484 Field Name: Nikatchuq � API/UWI:50-029-23459-00-00 2^ Date:7/31/2012 - Report#: 2 II II page 1 of 1 Wellbore name' 0120-07 Well Header Permit/Concession N° Operator EM Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(ND...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) 0120-07 COMPLETION 7/30/2012 5,924.40 970.78 1.01 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 78.0 7.8 Overcast WC 46° ENE @ 8 MPH Daily summary operation 24h Summary Complete to RIH 4%"Completion string-Space out-Set and test tubing hanger-Set PHL packer-Tubing integrity test-Shear mirage plug-Shear GLM valve-Set BPV-N/D BOP Stack N/U Production Tree and test-Prepare for rig move Operation at 07.00 • Prepare for rig move 24h Forecast Rig move-Freeze protect annulus-C/O GLM valve Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1078.4 • Time Log Start End Cum Time Time _Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 04.30 4.50 4.50 COMP K 5 P P/U,M/U and RIH completion string w/4%"12.64 L80 HYD563 tbg 510239'1/11604'(M/U Tq 4.4k fllbs)-Tag no go @ 11604'-Space out-M/U VITs and tubing hanger 04 30 06.00 1.50 6.00 COMP K 5 P Land tbg hanger-Run in all lock down screws-Test upper and lower seals 5000 psi 10'each (Shoe @ 11630'-NO GO @ 11604'-LN'XN'3.813'@ 11491'-PHL Packer @ 11471'-LN'X'3.813"@ 11420'-GLM 2000 psi A?T @ 2059'-LN'X'3.813"@ 1967'] 06.00 10:00 4.00 10.00 COMP K 19 P M/U surface lines to set Packer-Pressure test lines @ 5000 psi-Pressure down Tbg to 3500 psi,hold 30 min on chart- PIT Bleed Tbg pressure to 2000 psi-TestPacker pumping down IA to 2500 psi,hold 30 min on chart-Bleed off IA pressure- �/� Increase Tbg pressure until shear Mirage plug @ 4400 psi-Bleed off Tbg pressure-Pressure down IA until shear GLM @ 2500 psi 10:00 12:00 2.00 12.00 COMP C 5 P R/D equipment-Blow down all lines and TDS-Drain BOP Stack-Install BPV 12:00 20:00 8.00 20.00 COMP C 5 P LID completion running equipment-Remove choke&kill lines-R/D Ketch Kan-L/D mouse hole-L/D flow line-N/D BOP stack and set back-N/D and L/D riser 20:00 00:00 4.00 24.00 COMP C 5 P N/U Tree adapter and valves-Pressure test upper void area 5000 psi 10 min-Pull BPV-Install TWC-Pressure test Tree 500/5000 psi 5/15 min-R/D testing equipment-Pull TWC-Prepare for rig move Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry Eni Petroleum Sr.DrIg.Spvr. 907-685-1493 Eni representative Mirko Musumeci Eni Petroleum Dig Spvr. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-1492 Tool Push Toby Bordelon Nabors Alaska Drilling Tour Pusher 907-670-1492 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date I LINER 4112 L80 3535.99 5.231.59 7/26/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 3.605.78 1,028.02 Faze Pro OBM 1126.4 44.8 1562.0 160.5 I 1 1* Eni E&P Division .. f Well Name:0120-07 EN!Petroleum Co.Inc. Daily Report Well Code:26484 Field Name:Nikatchuq • APIIUWI:50-029-23459-00-00 2^II Date:8/1/2012 - Report#: 3 I' II page 1 of 1 Wellbore name: 0120-07 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 402100 ENI PETROLEUM 100.00 HORIZONTAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.18 3.72 0.00 11.35 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0120-07 COMPLETION 7/30/2012 5,924.40 970.78 2.01 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 78.0 9.4 Overcast WC 49" ENE @ 12 MPH Daily summary operation 24h Summary Rig move-R/D WEI ECD system-Freeze protect well-CIO GLM valve Operation at 07.00 OP18-08:C/O GLM valve-Install Vetco hang-off flange and isolation valve-R/U CTU-Clean up run 24h Forecast 0120-07 complete-Start OP18-08 rigless job Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1078.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 0600 6.00 6.00 MOB A 2 'P Prepare for rig move:Pump pill through surface equipment-Continue to Clean pits-Secure BOP stack-Blow down lines- R/D lines f/ECD manifold U stand pipe-Secure well-Move cuttings box and continue preparing for rig move-Set rig mats -Swap power-R/D inner connection 06 00 12 00 6.00 12.00 MOB A 2 P Roll up Lampson curtains-Set rig mats-Jack up both modules on rig mats and move to let room for rigless job 12.00 18.00 6.00 18.00 COMP K 9 P R/D ECD manifold and fill up pump-R/U Little Red and retums lines on Tree to freeze protect annulus-PJSM-Pressure test line 1500 psi 5 min-Little Red pump diesel down IA with returns from Tbg:ICP 2 bpm @ 700 psi-6200 gal pumped- Shut pump 18:00 00:00 6.00 24.00 COMP R 5 P R/D Little red-R/U Slick line unit-Pressure test lubricator-Run#1:Set Tbg stop-Run#2:P/O sheared valve-Run#3. Set new valve 2000 psi A?T-Run#4:P/O Tubing Stop-RID Slick ine Daily Contacts Position Contact Name Company Title E-mail Office Mobile Dnlling Supt. Ben Perry Eni Petroleum Sr.Ddg.Spvr. 907-685-1493 Drilling Supt. Mirko Musumeci Eni Petroleum Drlg Spvr. 907-685-1493 907-903-7269 Eni representative Mike Nelson Eni Petroleum HSE 907-685-1496 Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Eni representative Ken Bogner Eni Petroleum Materials Coordinato Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670.1492 Tool Push Brian Tiedemann Nabors Alaska Drilling Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 41/2 L80 3,535.99 5,231.59 7/26/2012 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gig P LeakOff(kgf/cm') 3,605.78 1,028.02 Faze Pro OBM 1126.4 44.8 1562.0 160.5 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg v' ' Z-- P.I.Supervisor r t ' DATE:Monday,August 27,2012 SUBJECT:Mechanical Integrity Tests ENI US OPERATING CO INC 0120-07 FROM: Lou Grimaldi NIKAITCHUQ 0120-07 Petroleum Inspector Src: Inspector Reviewed By:- P.I.Suprv.lW` NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ 0120-07 API Well Number 50-029-23459-00-00 Inspector Name: Lou Grimaldi Permit Number: 211-140-0 Inspection Date: 8/24/2012 Insp Num: mitLG120824184716 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - --Tp r Well 0120-07 Type InI i W.TVD 3345 800 1700 - 1685 1680 - i — IA PTDz Type Test SPT Test psi OA 200 210 Interval IINITAI. �P/F P Tubing 320 320 322 1 320 1 Notes: Initial post inj MIT.2.5 bbl's pumped,2.4 returned.Good solid test. 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W +044 m 20--8 4—T 84 W JAateT+ Utp aOCt +pDA+e 8.2NA 88484 8440 W W JN80 N OU8+8 O2 Ol V O NO'W to$ 88.248 820888 4pi4N8o 88 W W W 084.200 82k182 22C v CO .J J J JO JO JO. oJ JO Jo J0 OJ VO V VO OV V V VO VV .o J J,-.4t -6, 0 Vo J V V V V N t t 4t N1It U t 84tHN8 NN NNN 4t 24222 2 N N N N NNN N N N 4 4 C8N1 N NNN N o A d A y N N>AAA Wp W N W W W N NNN y N t..,--1,p �aN+o 00//00211 a W+ Mil 0124 0_t tUpp tD 801 Ae W+Ot >p 4A W N Om28U OWt N Iii in W.POJ CNJt tCT W 088 OA W OP1 W 22.8088 00108 W .8824 +Ntw008 A..°O N W 4 A N. + .2 0 0 2 o e N o N ..... +O N 2 2 8 2 2 N 8 A K AAA AAAAA A A A A A A a A a a a a a A A A A A A A A A A A A a A a a A m �+ tO(O 0 tO tO CO tO CO tO CO tO tO U CO CO tO tO fO CO N!O m m U..CC U tO w tO tO t0 tO tO tO w CO tG 13 W W N COO CUD WWW WWW W W WWW W W *REM W(W W OCD W W W J J J J-Jp11 J J V J v V 0 N P W W NN OO CD tp0 VIM GAA A W NN p+00 COD ppO W 01 CCICaCOCO A m 882 +(C(N A N Ot C 4 W 01 A two$ V N C N 8 2 01 O N V 8 A V W 6 N W J A O N U t O t O 2 0 as NJ 02882 LA 108 102 t0 N+ 2 W O E4 N� w A Wil +O W AO 282 2242+ NN +JJ W 2A 8228 W 830 O_ A Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, June 27, 2012 5:11 PM To: 'Longo Joseph' Cc: Davies, Stephen F (DOA) Subject: RE: 0120-07 Alternate Path (PTD 211-140) ._ ...._ Joe, Thanks for the cross section plot. The deviation in well plan is acceptable as you are staying within 500' of your permitted well path (as stated earlier). Since the N sand is in the same pool you can penetrate this section without a revision to the PTD. The swell packer and blank liner will isolate this N sand from any injection which could cause drilling issues in the future. Please send us a digital form of the new wellpath to verify the position and put in our database. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Longo Joseph [mailto:joe.longo@enipetroleum.com] Sent: Wednesday,June 27, 2012 1:51 PM To: Schwartz, Guy L(DOA) Subject: 0I20-07 Alternate Path Guy, How are you doing today? I want to thank you and Cathy again for taking the time to meet Davide and I last week, I know you are extremely busy and I appreciate you taking the time to accommodate us last minute. As we were talking the other day I have attached the section view of the alternate well path that we are planning for the reservoir section of 0I20-07. Basically we want to evaluate the extent of the N-Sand on the west side of the field. We are also planning the same type of well plan for a few other wells on the island. The planned well path will not breach the Schrader Bluff top (i.e. we will keep with in the Schrader Bluff Oil Pool). The plan is to drill the lateral section until our expected water contact and then steer up to evaluate the N- Sand. The section after the water contact will not be lined and a swell packer will be run to seal off any potential inadvertent injection to the N-Sand. If you require any more information of have any concerns please do not hesitate to contact me. Regards, Joseph Longo Drilling Engineer Anchorage, AK Office (Anchorage): (907) 865-3323 Office (North Slope): (907) 685-1226 Cell: (907) 947-4323 Email: Joseph.Longo©enipetroleum.com This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing,copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake,we ask you to kindly inform the Sender and to delete the message. 6/27/2012 j Ak -2500 -2600 -2700 -2800 -2900 -3000 -3100 -3200 -3300 -3400 -3500 1 �. . . --I . N- s+ O o �. 0 L.' •\ Q • O w, O 0 o- m '1 0 a\o \ cm 0 o O t co '' . tki o li q C4Q�7 ii O I O O- O O- O CO- f7 O I O O- O O- O N- N 8 \ O- , 0 a- t\ O O O O- iiii OO O 0= 0 • Q 0] oa Z ;�y c - rCD � N row co N CC Nr- i 41plac Y o \ _ 00 co \\ (V LLop C CO LL o cow US W I... 4 o O o Cp o N g p0 S p rr ; � < 009Z- 009Z- OOLZ- 0082- 006Z- 000£- 004E- OOZE- OOEE- 0017E- OOSE- i, A c, /11\ SEAN PARNELL,GOVERNOR O [1(L-=‘\ ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Maurizio Grandi Well Operation Project Manager ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, 0120-07 ENI US Operating Co. Inc. Permit No: 211-140 Surface Location: 3141.3' FSL, 1682.3' FEL, SEC. 05, T13N, R9E, UM Bottomhole Location: 4451' FSL, 2425' FEL, SEC. 35, T14N, R8E, UM Dear Mr. Grandi: 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, Daniel T. Seamount, Jr. Chair h DATED this day of November, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RE 'PR,Prw - PERMIT TO DRILL )( , L L'' 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Development-Oil U Service- Winj LI • Single ,' g1 Spiepecify if well is proposed for: Drill 0 . Redrill ❑ - Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone 8 E1 eGeli3.E titydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Anchor Shale Gt ' ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well Name and Number: ENI US Operating Co.Inc. Bond No. RLB0008627 • 0120-07 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 19438' • TVD: 3351' • Nikaitchuq Schrader Bluff Oil Pool• 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3141.3 FSL 1682.3 FEL S5 T13N R9E UM • ADL 355024,373301,391283,388577 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 560 FSL 1516 FEL 36 T14N R8EUM ADL 417493 1/9/2012 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 4451 FSL 2425 FEL 35 T14N R8EUM 1280 556'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 53.2 feet 15.Distance to Nearest Well Open Surface:x- 516598 , y- 6036494 Zone- 4 GL Elevation above MSL: 12 feet to Same Pool: 0P16-03 , /2(. 7 / � y) /0•i9•if 16.Deviated wells: Kickoff depth: 250 feet . 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90° degrees Downhole: 1508 psig - Surface: 1140 psig • 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) Driven 20" 178.89 X-65 Welded 124 36 36 160 160 pre-installed 16" 13-3/8" 68 L-80 BTC 2728 35 35 2763 2172 1260 sx 10.7#ASL,230 sx 12.5#Deeperete 12.25" 9-5/8" 40 L-80 Hydril 563 12026 33 33 12059 3405 687 sx 12.5#Deeperete 8.75" 4.5" 11.6 L-80 Hydril 521 7579 11859 3405 19438 3351 uncemented liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat 0 BOP Sketch 0 Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Luca Boni @ 907-865-3328 Printed Name Maurizio Grandi Title Well Operation Project Manager Signature A jaCKAL�O 14...04,....t( Phone 907-865-3320 Date 10/11/2011 Commission Use Only Permit to Drill i// � API Number: O�� 2 jermit Ap�pv@I \` See cover letter for other Number: / 50- (f �*! Date: \`+` requirements. Conditions of approval: If box is c ecked,well may not be used to explore for,test,or produce coalbed m thane gas hydrates,or gas contained in shales: Er Other: 4 35c gi. �P (e. Samples req'd: Yes❑ No 1 Mud log req'd: Yes ❑ o Q/ S5-Vvl psi: Ahnw�r --r-c.5-i- ( ., H25 measures: Yes Nod Directional svy req'd: Yes []✓No ❑ - 01'06r-6r l.l�c�c.v,,P ..` Lb ,4 Ac. Zs..,03S(ti)�z?� �/{/ 1-i vn E�►....✓+h a ti , G2 Lr:,...) 4Aro 3 to /21/ APPROVED BY THE COMMISSION l / DATE: 410, ,COMMISSIONER 7‘, fir- I - I( ORIGINAL , 10,,/„ ,1 (k Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate Viti* • Enli 'Jc-tro eum 3800 Centerpoint Drive Suite 300 � Anchorage,Alaska 99503 tl�� Jc T Maurizio Grandi ilk7 /j Phone(907)865-3320 Q��&6 Email: Maurizio.Grandi@enipetroleum.com Ctlns October 11 2011 4 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Injector 0120-07 Dear Commissioners, • Eni US Operating Co. Inc.hereby applies for a Permit to Drill for the onshore injector well 0120-07.This well will be drilled and completed using Nabors rig 245E. The planned spud date could be as early as 09- Jan-2012. - Please fmd attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information,please contact Joseph Longo at 907-865-3323 or Boni Luca at 907-865-3328. Sincerely, Maurizio Grandi Well Operations Project Manager vitit • Enfl Petrolleuirn 2no Application for Permit to Drill 0I20-07 Saved: 11-Oct-11 Application for Permit to Drill Document Injector Well 0120-07 Table of Contents 1. Well Name 3 Requirements of 20 MC 25.005(f) 3 2. Location Summary 3 Requirements of 20 MC 25,005(c)(2) 3 Please see Attachment 7:Surface Platt 3 Requirements of 20 MC 25.050(b) 3 3. Blowout Prevention Equipment Information 4 Requirements of 20 MC 25.005(c)(3) 4 4. Drilling Hazards Information 4 Requirements of 20 MC 25,005(c)(4) 4 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 MC 25.005(c)(5) 4 6. Casing and Cementing Program 5 Requirements of 20 MC 25.005(c)(6) 5 7. Diverter System Information 5 Requirements of 20 MC 25.005(c)(7) 5 8. Drilling Fluid Program 6 Requirements of 20 MC 25.005(c)(8) 6 Surface Hole Mud Program (extended bentonite) 6 Intermediate Hole Mud Program(LSND) 6 Lateral Mud Program(MI FazePro Mineral Oil Base) 6 9. Abnormally Pressured Formation Information 6 Requirements of 20 MC 25.005(c)(9) 6 10. Seismic Analysis 7 Requirements of 20 MC 25.005(c)(10) 7 AOGCC PERMIT Document.doc Page 1 of 9 Printed: 11-Oct-11 enn• Eni Petirolleuirn Application for Permit to Drill 0I20-07 Saved: 11-Oct-11 11. Seabed Condition Analysis 7 Requirements of 20 MC 25.005(c)(11) 7 12. Evidence of Bonding 7 Requirements of 20 MC 25.005(c)(12) 7 13. Proposed Drilling Program 7 Requirements of 20 MC 25.005(c)(13) 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 8 Requirements of 20 MC 25.005(c)(14) 8 15. Attachments 9 Attachment 1 Directional Plan 9 Attachment 2 Drilling Hazards Summary 9 Attachment 3 BOP and Diverter Configuration 9 Attachment 4 Cement Loads and CemCADE Summary 9 Attachment 5 Well Schematic 9 Attachment 6 Formation Integrity And Leak Off Test Procedure 9 Attachment 7 Surface Platt 9 AOGCC PERMIT Document.doc Page 2 of 9 Printed: 11-Oct-11 • • • EnHAem„ tr®Ie Application for Permit to Drill 0I20-07 Saved: 11-Oct-11 1. Well Name Requirements of 20 MC 25005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Well Name: 0I20-07 • 2. Location Summary Requirements of 20 MC 25005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application.: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation, and at total depth, referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 3141.3 FSL, 1682.3 FEL, S5 T13N R9E UM • ASP Zone 4 NAD 27 Coordinates RKB Elevation 52.2'AMSL • Northing 6036494.32', Easting:51659799' • Pad Elevation 12.2'AMSL Location at Top of Productive Interval 560 FSL, 1516 FEL, S36 T14N R8E UM ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 12059' Northing: 6039176.8' Easting:506327.6' Total Vertical Depth, RKB: 3405' • Total Vertical Depth, SS:: 3353' Location at Total Depth 4451 FSL, 2425 FEL, S35 T14N R8E UM • ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 19438' - Northing:6043065' Easting: 5001353' Total Vertical Depth, RKB: 3351' • Total Vertical Depth, SS: 3299' . Please see Attachment 7:Surface Platt and (D)other information required by 20 MC 25.050(b); Requirements of 20 MC 25050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat, drawn to a suitable scale,showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and AOGCC PERMIT Document.doc Page 3 of 9 Printed:11-Oct-11 lot • EMI -' (-. .tro eu eiria Application for Permit to Drill 0120-07 Saved: 11-Oct-11 (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. ' 3. Blowout Prevention Equipment Information Requirements of 20 MC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035, 20 MC 25.036, or 20 MC 25.037, as applicable; Please see Attachment 3: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 MC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered, criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The expected reservoir pressure in the Schrader Bluff sand is 0.45 psi/ft, or 8.6 ppg EMW (equivalent / mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the planned vertical depth of the OA sand formation is: MPSP — Dss)(0.45 - 0.11 psi/ft) = 1140 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 MC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests, as required under 20 MC 25.0300; Please see Attachment 6: Formation Integrity And Leak Off Test Procedure AOGCC PERMIT Document.doc Page 4 of 9 Printed:11-Oct-11 tot dna - troHe _ern Application for Permit to Drill 0I20-07 Saved: 11-Oct-11 6. Casing and Cementing Program Requirements of 20 MC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 124 36 36 160 160 pre-installed 16" 13-3/8" 68 L-80 BTC 2728 35 35 2763 2172 1260 sx 10.7#ASL,230 sx 12.5# Deeperete 12.25" 9-5/8" 40 L-80 H563'l 12026 33 33 12059 3405 687 sx 12.5#Deeperete (.Sy rf; Hydril sK 8.75" 4.5" 11.6 L-80 521 7579 11859 3405 19438 3351 uncemented liner in open hole 7. Diverter System Information Requirements of 20 MC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please see Attachment 3: BOP Configuration. ENI requests that AOGCC waive diverter requirements per 20 AAC 25.035. (h). (2). — D is AOGCC PERMIT Document.doc Page 5 of 9 Printed:11-Oct-11 *oil • • Iia 'troOe r 1 Application for Permit to Drill 0I20-07 Saved: 11-Oct-11 8. Drilling Fluid Program Requirements of 20 MC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8)a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Casing Point Initial Value Final Value Initial Value Final Value Density(ppg) 8.8 9.2 9.2 9.5 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50 70 30 50 (lb/100 st) Plastic Viscostiy 30 55 15 20 (CP) pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 8.0 8.0 (cc/30 min)) Intermediate Hole Mud Program Lateral Mud Program (LSND) (MI FazePro Mineral Oil Base) (:)12/1/l 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value Density(ppg) :.7-9.4 Density(ppg) 8.8 - 9.5 Plastic Viscostiy 15 - 25 Funnel Viscosity (CP) (seconds) 45 - 60 Yield Point Plastic Viscostiy (lb/100 sf) 15 - 20 12 - 18 (CP) HTHP Fluid loss Yield Point 18-24 (ml/30 min @ <5.0 (lb/100 st) 200psi& 100°F API Filtrate Oil/Water (cc/30 min)) 4 - 6 Ratio 60/ 40 Chlorides(mg/I) <500 Electrical >600 pH 9.0- 10.0 Stability MBT <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 MC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application; AOGCC PERMIT Document.doc Page 6 of 9 Printed: 11-Oct-11 tot, ....... . E 1 .--) (... t , 1 , n role - -i Application for Permit to Drill 0120-07 Saved: 11-Oct-11 (9)for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(1); Not applicable: Application is not for an exploratory or stratigraphic test well. ' 10. Seismic Analysis Requirements of 20 AAC 25005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. • 11. Seabed Condition Analysis Requirements of 20 AAC 25005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform, mobile bottom-founded structure,jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 MC 25.061(6); Not applicable: Application is not for an offshore well. • 12. Evidence of Bonding Requirements of 20 AAC 25005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 MC 25.025{Bonding}have been met; Evidence of bonding for ENI is on file with the Commission. • 13. Proposed Drilling Program Requirements of 20 AAC 25005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. 1. Move in / rig up Nabors 245E. • 06✓w4e,^ !./moi„ J 7d. II'f•n 2. Spud and directionally drill 16” hole to casing point as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 3. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 4. Install and test wellhead to 5000 PSI. 5. Nipple up 13-5/8"5K BOP and test to 3500 PSI. Notify AOGCC 24 hrs before test. 6. Pressure test casing to 2500 psi per AOGCC regulations. Record results. ,-- 7. 7. PU 12-1/4"bit and directional drilling assembly with MWD, LWD and PWD. ` 8. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording SOT TO t3,.ta— results. 9. Directionally drill to 9-5/8"casing point per directional plan. Pull out of hole backreaming to the surface casing shoe. 10. Install 9-5/8"casing rams in the BOP and test to 3500 PSI. AOGCC PERMIT Document.doc Page 7 of 9 Printed: 11-Oct-11 • Eni troOeum Application for Permit to Drill 0I20-07 Saved: 11-Oct-11 11. RU casing drive system. 12. Run 9-5/8", 40# L80, Hydril 563 casing to setting depth. Pump cement and displace with mud. Bump plug with casing on depth. 13. Install 9-5/8"Emergency Slips. 14. Install 9-5/8" packoff and test to 5000 psi. 15. Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 16. Pressure test casing to 3000 psi per AOGCC regulations. Record results. �-� ce 17. PU 8-3/4" bit and directional drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. 18. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. 19. Directionally drill 8-3/4" hole to TD as per directional plan. Pull out of hole backreaming to casing shoe. 20. PU and run 5-1/2"slotted liner to TD. 21. Land liner, set liner hanger with 200'Liner lap inside the 9-5/8"intermediate casing. POOH laying down DP as required. 22. PU ESP completion as required and RIH to depth. Land tubing. Set BPV 23. Nipple down BOP, nipple up tree and test. Pull BPV. • ENI requests that the AOGCC waive surface safety valve requirements per 20 MC 25.265. (c). ---. (1). lotout-S • The Vetco horizontal wellhead utilized physically prevents locating the SSV in the vertical run of the tree as there is no vertical tree on this wellhead. • Wellhead schematics should be on file with the AOGCC. 24. Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 25. Move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25,005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point , Class I disposal well or by hauling the fluids to the Prudhoe Bay Grind and Inject Facility. All cuttings generated will be disposed of either down an Oliktok Point Class I grind and inject disposal well or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. AOGCC PERMIT Document.doc Page 8 of 9 Printed:11-Oct-11 lot Enil iHtrolleum Rim Application for Permit to Drill 0120-07 Saved: 11-Oct-11 15. Attachments Attachment 1 Directional P/an Attachment 2 Drilling Hazards Summary Attachment 3 BOP and Diverter Configuration Attachment 4 Cement Loads and CemCADE Summary Attachment 5 Well Schematic Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt br(ILI ft.c...e.g.....c_ plows : AOGCC PERMIT Document.doc Page 9 of 9 Printed: 11-Oct-11 • em ass operating WELL 0120-07 Drilling Procedure 0120-07 Oliktok Point Conductor slot #20 Reservoir location #07 Producer (Schrader Bluff) Nikaitchuq Project Drilling Wellplan Page 1 of 30 11/01/11 til* 2nll us operrahns WELL 0120-07 Oliktok Point Nikaitchuq Field --mea North Slope - Alaska pOrofieu 11 0I20-07 DIR/LWD FORM DEPTH HOLE CASING MUD INFO MWD MD I TVD SIZE SPECS INFO Cement to Surface 20" Hole Angle o X-65 0° 20"Conductor Shoe it II' 16' Driven Welded N/A GR/Res ti Surface Csq Dir/PWD 'i u 13-3/8" y 68 lbs/ft MW(ppg) Wellbore Stability Mud Motor B/Permafrost ,,(,',/ 1780 L-80,BTC 8.8-9.5 Lost Circulation — Hole Cleaning Casing Sections KOP:250' Casing Wear ,. DIS: Surface T/Tail Cement 2259 1917 M, N 0-3.75°/100' in 0 i n C n Hole Angle 68.88 Deo 13-3/8" 2,764' 2,172' PI 16" 50°F WBM GR/RES Neutron/Density/PWD ' Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Xceed 900 40 lb/ft NW/(ppg) Hole Cleaning L-80,Hyde)563 8.8-9.5 Torque&Drag Casing Sections Tangent Angle: Casing Wear 82.45 Deg 1 _,i BHA Expense lnhvnnedi,rte TOC 9,794' 3,138' Pick-up Top of Sand i N 9 N Top 10,794' 3,270' c a e TOI 11,859' 3,391' ;; Hole Angle �� 86.00 Deg 9-5/8' 12,059' 3,405' 12_ 85"F OBM GR/RES Neutron/Density/PWD Wellbore Stability Lost Circulation Slotted Unnr Hole Cleaning 4-1/2" Torque&Drag 11.61b/H MW(ppg) Casing Sections Xceed 675 II L-80,Hyde)571 8.7-9.4 Casing Wear BHA Expense I Hole Angle 90.54 Deg 4-1/2"Liner 19,438' 3,351' I r r 8-3/4" 85'F MOBM Drilling Wellplan Page 2 of 30 11 01 1 1 eni us operating WELL 0120-07 Table of Contents WELL PLAN SUMMARY 4 MIRU SECTION 5 SURFACE SECTION 6 Surface Drilling 7 Surface Casing 9 Surface Cementing 12 Pick Up Intermediate Drilling Assembly 14 INTERMEDIATE SECTION 15 Intermediate Drilling 16 Intermediate Casing 17 Intermediate Cementing 20 Pick Up Production Drilling Assembly 22 PRODUCTION SECTION 23 Production Drilling 25 Production Liner 26 ATTACHMENTS 28 Health, Safety & Environment 29 Safety Meeting Topics 30 Drilling Wellplan Page 3 of 30 11/01/11 em us operating WELL 0120-07 WELL PLAN SUMMARY Rig: Nabors 245E Type of Well: Producer Well Design: 13-3/8"Surface x 9-5/8"Intermediate x 5-1/2"Slotted Liner Close Approach and Offset Well Interception Risks It is important to stay as close as practical to the planned directional program. The directional program and a summary of close approaches can be found in the attachments. These close approaches will be in conformance with the minimum well separation criteria detailed by the Drilling Anti-Collision Analysis and Close Approach Guidelines. It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. It is important that the well bore remains close to the planned well path as any major deviations from the profile may adversely affect the ability to drill future wells and still adhere to the current close crossing guidelines. Survey Program&Procedures Take MWD surveys as frequently as needed,but no less than every 100 ft. Carefully review the anticipated close crossings with existing wellbores and future well paths. Make sure that directional drillers are aware of all drilling close crossing issues,hard lines and no-go lines. If a no-go or hard line has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. Mud Logging Program Mudlogging will be utilized from spud to production hole TD. Refer to the Geological Mud Logging Procedure document. Drilling Wellplan Page 4 of 30 11/01/11 us opcii thong WELL 0120-07 MIRU SECTION OD WT Grade Conn. ID(in) Collapse Burst Tensile Yield (in) (ppl) Type (psi) (psi) (kips) 20 178.89 X-65 Welded 18.25 3240 4980 3417 1. Confirm that the identification markings on the conductor match the planned surface location with the "as-built survey." If identification markings are not present on the conductor, contact the Drilling Supt. prior to moving the rig onto the well. ➢ Each conductor is to be marked with a common pad elevation survey mark by the surveyors ➢ Surveyors to also mark each conductor with a degree of angle to set each horizontal wing valve 2. Move in and rig up. Record move distance and rig floor distance to pad and sea level in WellView and on IADC reports. Initiate a Rig Elevation Record and place it on the N drive. • Ensure all concerned parties(Directional Drillers,MWD Operators,and Geologists)are using the same rig floor elevation. 3. Post drilling permit in the rig office and company office. 4. Nipple up the Vetco Gray landing ring,Vetco starter head,the diverter spool,and the annular preventer. Function test the system. Pi✓e 4`' ➢ "Cs r _:.ua din. •nd 2 est �,;. rs • �o �erf��,i„•;. i�• .�'u c ion (✓k.ioc.,.0 ➢ Test lower seals of the starting head to 80%collapse of the pipe,but do not exceed 500 PSI. ➢ Confirm proper signage is on the pad indicating the rig has diverter equipment rigged up and to restrict access /i_f_o to diverter line area ➢ Place drip berm under the end of diverter line 5. Verify that two 3”threaded.nipples have been welded on the conductor on opposite sides. Include ball valves and Cam-Lock male fittings on each nipple. Ensure threaded ball valves can be installed without running into the OD of the diverter head. Nipples are to be used as follows: ➢ Assist in washing out surface casing hanger on cement jobs ➢ Take returns to Vac trucks while cementing ➢ Provide access to annulus for top job through small diameter tubing 6. Build spud mud. Drilling Wellplan Page 5 of 30 11/01/11 104 env us operreng WELL 0120-07 SURFACE SECTION Surface Formation Markers: (all depths Nabors 245E: Schlumberger Plan (P14) Formation Tops Measured True Vertical Comments Depth, ft Depth, ft SV-4 716 712 SV-3 979 958 SV-2 1278 1215 SV-1 1945 1702 B/Permafrost 2057 1780 Ugnu Top (UG-4) 2349 1973 Set Surface Casing ✓ I3� e UG-2 4386 2428 Lower Ugnu 8918 3023 Fault 17-02 1 8982 3032 Schrader Bluff 10389 3217 N Seq Top 10498 3231 N Top 10794 3270 N Bottom 11040 3302 N Seq Base 11362 3344 OA Sand Top 11968 3399 Drilling Wellplan Page 6 of 30 11/01/11 diroo1/4 • 2nQ us operr has WELL 0120-07 Surface Close Approach Wells NOTE: It is the responsibility of the Directional Driller and the Drilling Supervisor to ensure that the directional plan is executed as planned,that the position of the well as it is drilled is monitored on an anti-collision diagram and that no tolerance line for close approach wells is crossed. Surface Mud Program: NOTE: Maintain Weight up Schedule as listed below to casing point API Fluid Density 6 RPM Chlorides Interval Depth Reading Loss (mgn) PH (ml/30min) 110'-1800' 8.8-9.2 20-24 <8 <2000 9.0-9.5 Surface: 1800'—C.P. 9.2—9.5 20—24 <6 <2000 9.0—9.5 Surface Logging/Formation Evaluation Program: MWD Directional/PWD LWD GR/Res Surface Drill Pipe Surface Drilling Surface Hole Notes: • The area around the conductor should be continuously monitored during drilling,circulating,and cementing operations. If broaching occurs,stop drilling immediately. Contact the AOGCC field inspector and the Drilling Superintendent and inform them of the broach. The Conductor Broach Procedure will then be implemented. • Prior to spud,a safety meeting will be held with the rig crews to discuss open hole drilling procedures. Suggested topics include: • Conductor broaching operations and contingencies • Well control procedures and rig evacuation procedures • Flow rates and hole cleaning • Ported float valves are required in all hole sections Surface Hole Procedure: 1. Pick up and drift all DP,HWDP,and DC's for surface section to confirm free of debris. 2. PU BHA(Include UBHO for Single shot E-line Gyro if MWD surveys are not clean initially)for directionally drilling to Surface Casing point with one BHA 3. Directionally drill surface hole: Drilling Wellplan Page 7 of 30 11/01/11 em us operating WELL 0120-07 ➢ Avoid anti-collision boundaries ➢ Take MWD surveys as frequently as needed. Carefully review the anticipated close crossings with existing wellbores. Make sure that directional drillers are aware of all drilling close crossing issues,hardlines and no-go lines. If a no-go or hardline has been or will be crossed,stop drilling immediately and contact the Drilling Superintendent to discuss options. 4. Hole conditions will always determine final mud properties. ➢ Watch returns closely for signs of gas when near the base of the permafrost and circulate out all gas-cut mud before continuing to drill. • Due to expected gas hydrates,keep mud as cool as possible(cold lake water). • Control drill at 100 to 120 fph through any troublesome zone so the hole does not load-up with gas cut mud. • Check and report trip gas. • Have 2 ppb Lecithin on location prior to drilling below the permafrost to minimize the effects of hydrates on the mud if hydrates are encountered. 5. Surface casing point: ➢ Landed in good shale found in this area between 2000' SSTVD and 2150' SSTVD ➢ Below the sand at the base of the Sagavanirktok Formation(SV-1). ➢ Inside the upper Ugnu(UG-4). D. Drill the footage necessary to leave the appropriate amount of rathole below the casing shoe. 6. Backream out of the hole at surface casing point: ➢ Circulate until shakers are clean. ➢ Backream to the HWDP • Decrease backreaming speed as torque and pump pressure dictate. • NOTE: once backreaming in the open hole has been started,do not stop backreaming until the HWDP. Do not attempt to pull out on elevators once backreaming has started. • If shakers/mud return system become overloaded and flow rate is cut to handle the issue,then do not continue to Backream until the parameters are brought back to full backreaming rate ➢ Once the HWDP is reached,circulate until hole is clean(shakers clean) 7. Pull and lay down BHA. 8. Perform a dummy hanger run before running casing. Surface Casing Program: (all depths feet RKB) OD WT Grade Conn. Cplg OD ID(in) Drift(in) Collapse Burst Tensile Yield (in) (PPO Type (in) (psi) (psi) (kips) 13-3/8 68 L-80 BTC 14.375 12.415 12.259 1950 3450 1069 Drilling Wellplan Page 8 of 30 11/01/11 ens us operating WELL 0120-07 Surface Casing Connection Make Up Torque(ft.lbs) Opt. OD WT Grade Conn.Type Make Up (in) (PPO Torque 13-3/8 68 L-80 BTC Triangle Surface Casing Casing Running Notes a. Rig up and utilize a Fill Up tool for the casing job. b. Any packing off while running casing,and especially while above the base permafrost,should be treated as a very serious problem if major returns are lost. Contact the Drilling Superintendent if the casing packs off high for discussion of the options. c. Have Vetco representative verify the correct casing hanger is on location prior to the point at which it is needed. d. Torque values for the BTC casing are determined at the rig by making up the connection to the make-up mark (base of triangle). Record torque values for the first 10 connections made up in this manner and average. This average will be used as the make up torque for the remainder of the string. 1. Inspect and drift all surface casing to 12.259". 2. While RIB with the the Casing: ). obtain SO Weights ➢ obtain PU Weights 3. Run the surface casing as follows: Surface Casing Running Order 1 Float shoe Bakerlock 2 2 joints 13-3/8"68#L-80 BTC casing Bakerlock Drilling Wellplan Page 9 of 30 11/01/11 e m us operating - WELL 0120-07 3 Float Collar Bakerlock 4 13-3/8"68#L-80 BTC casing ** TAM BTC port collar+/-500 ft Only run if losses are expected 6 13-3/8"68#L-80 BTC casing 7 13-3/8"hanger 8 13-3/8"landing joint **If TAM port collar is run: • A landing joint,which has a connection that can be broken below the rotary table,will need to be run to allow for running the drill pipe inside the 13-3/8"without needing a false rotary table. Also,the drill pipe running tool needs to be on location and stood back in the derrick ready to run in case the TAM port collar needs to be opened to circulate cement to surface. • If decision to run is at the last minute,ensure the additional footage of the port collar plus handling pup will allow for sufficient rathole below the surface casing shoe. Surface Centralizers +/- 18 13-3/8"Tandem Rise Weatherford Drilling Wellplan Page 10 of 30 11/01/11 end us operating WELL 0120-07 Surface Centralizer Placement 11111110 10' oa 13-3/8"x 16"Tandem Rise Centralizers Collar • 2 at 5'&8' above Float shoe on stop collars,using stop buttons or stop collars. • No centralization on collar of 1s'joint. • 1 at 10'above Float Collar,using stop buttons or stop collars. • From 3rd joint through tail slurry(500'tail slurry),1 centralizer per joint run on collars. Do not allow centralizer to float between collars. • 2 on 13-3/8" casing collars,inside conductor @ TD so csg can be reciprocated. 8' A Drilling Wellplan Page 11 of 30 11/01/11 e no us operafing WELL 0120-07 Surface Cementing Program Section Casing Size Type of Fluid/Cmt Volume Properties Mudpush II 100 bbls Density10.1 ppg Lead Slurry Density 10.7 ppg Surface 13-3/8" (ArcticSet Lite) 507 bbls Yield 2.26 ft3/sk Tail Slurry (DeepCRETE) 63 bbls Density 12.5 ppg Top of Tail @ 2,259'MD Yield 1.54 ft/sk Surface Cementing Casing Cementing Notes a. Obtain and review the Test Report from the cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. b. Use split landing joint if TAM port collar is utilized and needs to be opened by running tool on drill pipe. 1. After reaching bottom,rig up and circulate with casing on bottom,if possible,without losing returns. Reduce mud viscosity prior to pumping cement if necessary. 2. Rig up to cement and pressure test cement lines. 3. Pump cement job per the attached Schlumberger cementing plan. ➢ If necessary,verify that the TAM Tech has located the proper crossovers to his combo running tool D. If necessary,rack TAM running tool in derrick and ready tp run 4. Report the number of bbls of cement returned to surface: V ➢ Task one person to be in charge of monitoring for cement returns and volume of cement returns ➢ Recommend that a dye or small amount of celloflake be added to the wash or spacer to give an indication of top of cement. 5. Drop the bottom plug between the lead cement and the mud push. 6. Drop top plug after the tail slurry. 7. Pump displacement 8. Drop circulation rate for last 20 bbls of displacement for bumping plug. 9. Pump until the plug bumps and then pressure up to 500 psi above circulating pressure to ensure the plug has landed. If floats do not hold,maintain final circulating pressure on casing and shut in cement head for a minimum of 6 hours before rechecking. ➢ Do not over displace the cement(no more than'/z the shoe joint volume). ➢ Watch for signs of packing-off during pumping operations and closely monitor the cellar area for mud or cement returns around the conductor. ➢ In the event cement is not circulated to surface,pump the calculated volumes and prepare to open the TAM Port Collar(if applicable)for a secondary cement job. ➢ AOGCC and Drilling Superintendent must be contacted prior to beginning top job. Do not proceed with top job without AOGCC approval. 10. Drain and wash cement from riser. Nipple down riser and flush all lines. Drilling Wellplan Page 12 of 30 11/01/11 if* en us operraConc WELL 0120-07 11. Nipple up Vetco Gray Well Head,orienting the well head valves as indicated on the conductor markings. ➢ Ensure that the seal between the casing hanger and well head is tested to 5,000 psi for 10 minutes. ➢ Measure the distance from the rig floor to the top flange of the well head and record on the IADC report and in WellView. Complete the Rig Elevation Record and place it in the electronic well folder. 12. Nipple up the 13-5/8"5M BOP stack and test per the AOGCC Permit to Drill(attached) ➢ Test rams and choke manifold components to 3500 psi high/250 psi low ➢ Test annular preventer to 2500 psi high/250 psi low ➢ Do not test BOPE against casing. ➢ Notify AOGCC 24 hours prior to performing BOP test. • PERMIT TO DRILL requires BOP testing frequency every 14 days unless notified otherwise by AOGCC Drilling Wellplan Page 13 of 30 11/01/11 env Ms operrahng WELL 0120-07 Pick Up Intermediate Drilling Assembly 1. Install wear bushing. 2. Pick up BHA. 3. RIR to top of float equipment and pressure test surface casing to 2500 psi for 30 min and record on chart. D. Plot Casing Pressure Test on LOT form. Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. 4. Drill out the float collar&shoe. 5. Drill 20'-50'of new hole using spud mud. 6. Displace hole to new LSND mud system. U� 7. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. ➢ PU into casing and perform LOT. ➢ If the pressure continues to rise past 13.0 ppg EMW,shut down and call it a FIT per the FIT Guidelines (attached). ➢ If LOT is unacceptable to drill ahead(i.e.less than 11.0 ppg EMW),contact Drilling Superintendent to discuss ropTIons. ➢ Plot on LOT form on N drive. Drilling Wellplan Page 14 of 30 11/01/11 erns us operraVing WELL 0120-07 INTERMEDIATE SECTION Surface Formation Markers: (all depths Nabors 245E: Schlumberger Plan (1'141 Formation Tops Measured True Vertical Comments Depth, ft Depth, ft SV-4 716 712 SV-3 979 958 SV-2 1278 1215 SV-1 1945 1702 B/Permafrost 2057 1780 Ugnu Top (UG-4) 2349 1973 Set Surface Casing UG-2 4386 2428 Lower Ugnu 8918 3023 Fault 17-02 1 8982 3032 Schrader Bluff 10389 3217 N Seq Top 10498 3231 N Top 10794 3270 N Bottom 11040 3302 N Seq Base 11362 3344 OA Sand Top 11968 3399 Drilling Wellplan Page 15 of 30 11/01/11 U en II us o?c rrati nng WELL 0120-07 Intermediate Mud Program: NOTE: Weight up to at least a 9.4 ppg MW by the top of the"N" sand Interval Density PV 6 RPM API FL pH DrillSolidsMBT (ppg) Reading (ml/30min) (/o) Intermediate: 9.2—9.4 12-18 12-18 <6.0 9-10 <6.0 <18 Inter_mediate Loggin2/Formation Evaluation Program: MWD Directional/PWD LWD GR/Res Intermediate Section Notes: a. If the well is to be an ESP producer,a pump tangent must be placed in the intermediate hole section as per the planned directional profile. The pump tangent must be within 300'TVD from the top of the uppermost OA sand and at least 200'MD in length. b. Shallow test MWD tools. Intermediate Drilling 1. Directionally Drill 12-1/4"hole 2. Casing Point D. Land Intermediate casing in 0A2 sand reservoir 3. Backream at Intermediate Casing point. D. Circulate until shakers are Clean D. Decrease backreaming speed as torque and pump pressure dictate D Circulate until shakers are clean in the surface casing shoe 4. Pull and lay down BHA. Drilling Wellplan Page 16 of 30 11/01/11 ifos e nn o us op r has -- WELL 0120-07 Intermediate Casing Program: (all depths feet RKB) OD WT Conn. Cplg OD Collapse Burst Tensile Yield (in) (ppb Grade Type (in) ID(in) Drift(in) (psi) (psi) (kips) Hydril **Special 9-5/8 40 L-80 563 10.625 8.835 Drift 3090 5750 916 8.75 Intermediate Connection Make Up Torque(ft.lbs) Min. Target Max. OD WTMake U � Grade Conn. Type Torque, ft- Make Up Make Up Yield Torque lbs Torque Torque 9-5/8 40 L-80 H56�31 10,800 13,000 N/A 75,000 **Special Drift casing to 8.75 Intermediate Casing Interval Notes: a. Ensure proper sized rams are installed and tested prior to running intermediate casing. b. Rig up and utilize a casing fill up tool for the casing job. Shoe Track: 1. Have a spare float shoe and collar made up with centralizers and on location ready to go ➢ The shoe track joints should be Bakerlocked. D. Inspect the float valves as the shoe track is picked up. ➢ Run the shoe track into the well to test and confirm the floats are holding negative differential pressure. Casing Running Order 1 Float shoe Baker-Lock 2 2 joints 9-5/8"casing Baker-Lock 3 Float Collar Baker-Lock 4 9-5/8"Casing 6 9-5/8"hanger 7 9-5/8"landing joint Centralizers +/-38 9-5/8"x 11-3/4"Rigid Hydroforms(Floating) Volant Drilling Wellplan Page 17 of 30 11/01/11 • eni us operating WELL 012O-07 Running Procedure: 1. Inspect and drift intermediate casing(drift 8.75"). 2. Centralizers(See Diagram Below) 3. Pull wear bushing. Install 9-5/8"rams and test. Pickup and run casing. 4. Monitor running speeds to minimize surge and swab pressures while running in or picking up off slips. ➢ Monitor trip tank while running in hole. Reduce speed if decrease or loss of flow is noted. 5. While running in open hole with Casing: ➢ obtain SO Weights 6. Once on bottom with the casing: ➢ obtain PU and SO Weight 7. Run the casing string on bottom. Establish circulation rate and pressure. Reciprocate casing while circulating and cementing. Drilling Wellplan Page 18 of 30 11/01/11 los 1111 • ens us Oop rrahng WELL 0120-07 Intermediate Centralizer Placement C7 b Y I 10' Float 9-5/8"x 11-3/4" Hydroform Centralizers Collar Run 1 Hydroform: • On Stop collar 5'above Float shoe. • NoOn centralizeStop on next ejoint • On Stop collar 10'above Float Collar. • From 4th joint to+1-1000' above the shoe- 1 centralizer floated between collars • 1 centralizer floated between collars from N sand oil bearing zone to+/-500' above N sand oil bearing zone EZI 1_. Drilling Wellplan Page 19 of 30 11/01/11 iff* 2no us operating WELL 0120-07 Intermediate Cementing Program Section Casing Size Type of Fluid/Cmt Volume Properties Intermediate 9-5/8" Mudpush II 70 bbls Density 10.5 ppg DeepCrete 196 bbls Density 12.5 ppg Top of Cement @ 9,794'MD (704 sacks) Yield 1.56 ft3/sk Intermediate Cementing Intermediate Cementing Notes: a. Obtain and review the Test Report from cementing lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality,quantities,pumping times,or thickening times. If need be,confer with Drilling Superintendent. b. Do not over displace the cement(no more than'/2 the shoe joint volume). c. For injectors,a cement bond log is required. Prefer to run sonic LWD in production hole BHA and log intermediate casing on trip in hole to drill out intermediate shoe. 1. Perform Rig pump efficiency check and confirm+96%efficiency before pumping and displacing cement. 2. Ensure Schlumberger re-calculates cement volume based on"N"sand actual depth! D Cement volume is based on 50%excess and at least 1000'of annular fill a e top of the N sand(highest known hydrocarbon bearing zone). 3. Batch mix cement. Test cement lines and pump cement job as per the attached Schlumberger program. 4. Displace cement with rig pumps. D Ensure that the cement unit and rig pumps are manifolded so there will be redundancy in case of any pump failure during displacement. D Pump cement and displace watching for lost returns. Slow rate to during last+/-30 bbls prior to bumping plug. 5. When the plug bumps,pressure the casing to 500 psi over the final displacement pressure and ensure that the string is holding pressure. Notify the Drilling Superintendent if the string will not hold pressure. Bleed off pressure and ensure the floats are holding. If the floats leak,pressure back up to final displacement pressure and shut in cementing head. 6. Land casing D Maintain reciprocation as long as possible 7. Install Vetco 9-5/8"packoff assembly. 8. Pressure test packoff per Vetco Gray. D Do not exceed 80%of intermediate casing collapse D Record test on IADC report and in WellView Drilling Wellplan Page 20 of 30 11/01/11 2rnl� us operr hng WELL 0120-07 9. Freeze protect 13-3/8"x 9-5/8"annulus to the surface casing shoe. ➢ Pressure limitations are as follows:80%of surface burst or 80%of intermediate collapse,whichever is less. ■ 2472 PSI is 80%Intermediate casing collapse(9-5/8"40#L-80) ➢ Freeze protect the surface by intermediate annulus with diesel. Pump enough diesel to flush and freeze protect to the surface casing shoe. 10. Install rams and test per the AOGCC Permit to Drill(attached) ➢ Test rams and choke manifold components to 3500 psi high/250 psi low ➢ Test annular preventer to 2500 psi high/250 psi low ➢ Do not test BOPE against casing. ➢ Notify AOGCC 24 hours prior to performing BOP test. • PERMIT TO DRILL requires BOP testing frequency every 14 days unless notified otherwise by AOGCC 11. Install wear bushing. 12. Clean mud pits • Pits must be clean and free of all Barite Drilling Wellplan Page 21 of 30 11/01/11 loos" 2no us op rreong WELL 0120-07 Pick Up Production Drilling Assembly 1. PU the 8-3/4"bit and the BHA assembly. 2. RIH to the float equipment. ➢ Pressure test the casing to 3000 psi for 30 min and record on chart(AOGCC required casing integrity test). ➢ Plot Casing Pres ure Test on the Pressure tO'T form. Oil Based Mud Fluid Displacement 3. Displace casing to new Oil Based Reservoir Drilling Fluid ➢ Do not contaminate new OBM in rig pits 4. Drill out the float collar&shoe. 5. Drill 20'-50'of new hole using the Oil Based Reservoir Drill-In fluid. 6. Perform Leak Off Test as per AOGCC requirements following the attached LOT Procedure. ➢ PU into casing and perform LOT. ➢ If the pressure continues to rise past 13 EMW,shut down and call it a FIT per the FIT Guidelines (attached). ➢ If LOT is unacceptable to drill ahead(i.e.less than 12.0 ppg EMW),contact Drilling Superintendent to discuss options. ➢ Do not pump more than 1/2 bbl after leak off is determined. There is no need to pump more than 1/2 bbl into the leak off and extend the fracture. ➢ Plot on LOT form. Drilling Wellplan Page 22 of 30 11/01/11 e n n us operr A ng WELL 0120-07 PRODUCTION SECTION Surface Formation Markers: (all depths Nabors 245E: Schlumberger Plan (P Measured True Vertical Formation Tops Comments Depth, ft Depth, ft SV-4 716 712 SV-3 979 958 SV-2 1278 1215 SV-1 1945 1702 B/Permafrost 2057 1780 Ugnu Top (UG-4) 2349 1973 Set Surface Casing UG-2 4386 2428 Lower Ugnu 8918 3023 Fault 17-02 1 8982 3032 Schrader Bluff 10389 3217 N Seq Top 10498 3231 N Top 10794 3270 N Bottom 11040 3302 N Seq Base 11362 3344 OA Sand Top 11968 3399 Drilling Wellplan Page 23 of 30 11/01/11 em us operating WELL 0120-07 Production Mud Program: FazePro Density HTHP FL Electrical Interval YP (ml/30min) Oil:water Stability mlVolts Production 9.4 14-20 <5.0 65:35 >600 Production Logging/Formation Evaluation Program: MWD Directional/PWD LWD GR/Res Production Section Notes: a. Monitor hole conditions carefully. Be alert for early signs of lost circulation and differential sticking. If any of these problems are observed immediately notify the Drilling Supervisor or Toolpusher(attempt to keep the pipe moving and circulation established). Ensure that all team members are communicating with each other on any observed drilling trends and that everyone understands the potential risks. b. Shallow test MWD tools. c. Keep shut down times to a minimum during connections. When surveying in this hole section reciprocate the pipe slowly while the survey is transmitted uphole. Keep the pipe rotating whenever possible. d. Ensure the Top Drive Torque Limit is set below the lowest make up torque in the string. Do not run the risk of further make up to a connection while drilling. Drilling Wellplan Page 24 of 30 11/01/11 iff* 2no us operating- WELL p rrting- WELL 0120-07 Production Drilling 1. Directionally drill the 8-3/4"hole to TD. 2. Backream at TD: D. At TD circulate hole clean and backream to intermediate casing shoe. ■ Decrease backreaming speed as torque and pump pressure dictate. ➢ Backream into the intermediate casing shoe. • Decrease backreaming speed as torque and pump pressure dictate 3. Continue backreaming until depth at which it is possible to pull out on elevators at>9.1 swab EMW at 2.5 min/stand 4. Circulate until shakers are clean. 5. Slug DP and trip out of hole on elevators. 6. Lay down BHA Drilling Wellplan Page 25 of 30 11/01/11 • /mos 2n� us operr hng WELL 0120-07 Production Liner OD WT Conn. Cplg OD Collapse Burst Tensile Yield (in) (PP.I) GI Type (in) ID(in) Drift(in) (psi) (psi) (kips) 4-1/2" 11.6 L-80 5211 4.695 4.000 3.875 6360 7780 171 Production Liner Connection Make Up Torque (ft-lbs) Min. Target Max. OD WT Grade Conn. Type Make Up Make Up Make Up Yield (in) (PPS Torque, ft Torque Torque Torque lbs 4-1/2" 11.6 L-80 Hydril 521 3600 4300 N/A 16000 Production Liner Centralization From To Quantity/Joint Fixed/Floating Type Shoe Liner 1/joint Fixed 4-1/2"x 7" top -Mid joint -Crimped on -Hydroform Production Liner Liner Running Procedure Notes: a. Ensure proper crossover from DP to slotted liner is on the rig floor in case of a well control situation. b. Liner top should be placed a minimum of 200 ft above the intermediate casing shoe. c. Perform visual inspection,measure and caliper all components prior to running any assembly in the hole. Ensure accurate dimensional data is recorded for all equipment run in the well. d. Ensure all equipment has been hydraulically and operationally tested. Also ensure all equipment to be run is dimensionally compatible with all other equipment. e. Review all setting operations and shear pressures with service hand. f. Ensure that all workstring components have been rabbited as ball will be dropped to actuate downhole tools.Rabbit DP on last trip out of prior to running liner. g. If any openhole sidetracks have been drilled,monitor sidetrack depths during run in and ensure shoe enters the correct hole. Drilling Wellplan Page 26 of 30 11/01/11 • eni us operating WELL 012O-07 Procedure: 1. Hold Pre job safety meeting to ensure all parties understand operation. 2. PU the Liner Assembly and Running/Inner String. 3. RIH with Liner Assembly. Record PU and SO weights as required. 4. Pick up liner hanger assembly and make up to proper torque. 5. Trip in hole one stand and circulate 5 bbls to ensure all flow paths are free. ➢ Record ROTATE,PU and SO of liner assembly. 6. RIH in hole to casing shoe with DP. RIH with Liner Assembly as hole conditions allow. ➢ Break circulation and fill DP as necessary. 7. Monitor mud flow while running in open hole and slow running speed if necessary. ➢ Circulate minimum of one DP volume and record ROTATE,PU and SO weights. 8. Continue RIB with Liner Assembly to proper setting depth. ➢ Liner should be spaced out to locate the liner top approximately 200 feet above 9-5/8"casing shoe. 9. Prior to setting the hanger&packer,double check all pipe tallies and record amount of drill pipe on location. 10. Rig up to pump down workstring with rig pumps. Pressure test lines. Bleed off test pressure. 11. Drop setting ball down the workstring and pump slowly. Slow pump before the ball seats. Do not allow ball to slam into ball seat. 12. Pressure up to 3000 psi and hold for 5-15 minutes to set hanger packer. Continue pressuring up in 500 psi increments holding for 5 minutes each up to 4000 psi. 13. Packer can now be pressure tested. Bleed DP pressure to zero,close annular preventer and test annulus to 1,500 psi for 10 minutes and chart. 14. Bleed off pressure and pickup to verify that the running tool has released.If packer did not test,rotating dog sub can be used to set packer. 15. Once running tool is free and packer is tested,Displace mud from liner top to surface with 9.0 ppg KC1 brine 16. POOH and LD and inspect the liner running tools. Drilling Wellplan Page 27 of 30 11/01/11 • em us operating WELL 0120-07 ATTACHMENTS 1. Health,Safety,and Environment 2. Safety Meeting Topics 3. ENI LOT procedure 4. ENI FIT Guidelines Drilling Wellplan Page 28 of 30 11/01/11 los an n us operafing WELL 0120-07 Health, Safety & Environment The following are part of the mitigation&contingency measures to be put in place in order to complete this project while helping to meet our HS&E goals. It is the Drilling Supervisor's responsibility that these measures are implemented and communicated to the relevant parties on location. Good communication when drilling is essential for increasing the safety of personnel and equipment. H2S Contingency Measures Assume all locations have the potential for H2S. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic 112S detection equipment meeting the requirements of 20 AAC 25.066. Manual detectors in accordance with 20 AAC 25.065 will also be maintained on location. 3. Self-contained Breathing Apparatus for all rig personnel will be maintained on location. 4. All personnel engaged in the drilling operation will be trained in H2S emergency procedures and the use of proper personal protective equipment. 5. A standard H2S contingency plan will be posted at the rig. All rig personnel should read and familiarize themselves with this document and copies should be posted in the rig floor doghouse and in the camp on location. 6. H2S treating material for the drilling mud system will be available on location in the event that any H2S is encountered. It is expected that the rig and personnel will have the equipment and training to identify and contain a H2S emergency situation. If it becomes necessary to notify the AOGCC of an H,S encounter,drilling will be suspended and will resume only after the development of detailed remedial and contingency procedures.full compliance with 20 AAC 25.065 and the applicable referenced sections of API RP49 and approval of the AOGCC. Lessons Learned Documentation of lessons learned has been proven to reduce downtime and increase efficiency of rig operations. It is expected that planning meetings,daily operations meetings and pre-tour meetings will be held on a regular and consistent basis and that the records of those meetings will be placed on the N drive in the appropriate folder for this well. Drilling Wellplan Page 29 of 30 11/01/11 irfirt en us op rrahing WELL 0120-07 Safety Meeting Topics Move In,Rig Up ➢ Prior to spud,a safety meeting should be held with the rig crews to discuss open hole drilling procedures. - Subsidence around wellheads-use of buddy system, - Conductor broaching operations and contingencies, - Shallow gas hydrate drilling practices, - Proper tripping practices and hole fill calculations with various sizes of pipe and tubing, - Well control procedures, - Flow rates and hole cleaning,and - Diverter operation and crew responsibilities. D. A'Diverting Shallow Gas'drill should be held with rig crews prior to spud,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ An'Accumulator'drill should be held with rig crews prior to spud. Document drill and record on morning report. ➢ Shut-in drills should be held on a regularly scheduled basis. A suggested minimum is once per day on alternating tours. Document and record on morning report. D. Check trip tank for leaks and confirm gauges are calibrated. Complete trip sheets and submit to the Drilling Supervisor after each trip. ➢ Perform and document all drills. ➢ Designate crew member to control access at the pad entrance in case of diverter operation. Surface ➢ A'Stripping'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ A'Well Kill'drill should be held with rig crews prior to drill out,unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. ➢ A well kill sheet shall be posted in the doghouse and updated each tour. Intermediate ➢ Prior to picking up the BHA a safety meeting should be held with the rig crews to discuss hole risks and open hole drilling procedures. ➢ Potential formation pressures and mud weight,Well control procedures. ➢ Hole cleaning best practices,flow rates. ➢ Stuck pipe,Lost circulation. ➢ Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. Production ➢ Potential formation pressures and mud weight,Well control procedures. ➢ Hole cleaning best practices,flow rates. ➢ Stuck pipe,Lost circulation. ➢ Proper tripping practices and hole fill calculations with various sizes of pipe and tubing. 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' 'JJ'6 6t • t. • 3 W o • . t ' J6 • ' •^ • opeT i 1'� ' < o • �• Cn000 O O O = i' 1 N -co • 1 ppp INV 1 5. � O rn 0 0 0 v '' 4 0 � O� g 0 CooO 0 o A f O (in sOo -0 N p Co Oz• 1301 Ai. w co OOD A GWIQ - ' - O p 4'•C) O T AWw CO OOA 13� ? N W1N -0 � W (nCO TW T V c) pW -' W aco N § I § R o 4 : o i.C. it tCID o ) A ! t w ) Z; E i|.g 0 e s • . S R ; $ # |lf ' 2 1|G a ) LT n f fi ■ 1 � � / E . - � 2 w« I. sc §§ , »i2 # / k z �, ! . ■ Iz- ! § ! ! �0 ��§ : As °|3 \. k !` 0 _g . . . o 1,• s; & § eu P w X33 !� k ■ ! 7 aa ( a§\ ,! 3 ■ !■ - 3 p� ; `- .. . '� ;■ a 0. !i 22 ( } � 9 -5 L .- ° IN ; ƒ ! 6(3 E - E 12 O || , 3 ¢ I © � . . . ); !£& \ ; h ' _o . m 2 0 ., m 2 2 ■ a «< N Um«;&#=inns S »> Schlumberger 0120-07 (P14) Anti-Collision Summary Report Analysis Date-24hr Time: September 28,2011-14:51 Analysis Method: Normal Plane Client: ENI Reference Trajectory: 0120-07(P14)(Def Plan) Field: Nikaitchuq Depth Interval: Every 5.00 Measured Depth(ft) Structure: Oliktok Point Rule Set: D8M AntiCollision Standard S002 v5.1 Slot: OP20 Min Pts: All local minima indicated. Well: 0120-07 Borehole: 0120-07 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Global within 60448.78 ft Selection filters: Definitive Surveys-Definitive Plans-Definitive surveys exclude definitive plans -All Non-Def Surveys when no Def-Survey is set in a borehole-All Non-Def Plans when no Def-Plan is set in a borehole Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major OP23-W7802(Def Survey) Fail Major 23.96 22.74 457 16.5E 0.00 0.00 CtCt<=15m<15.00 Enter Alert 22.13 19.73 2.7 8j 344.37 344.36 MinPt-O-SF 19.24 16.04 -0.15 5.62 439.98 439.82 SfcRul<5.91 Enter Major 57 11.22 -2.82 2.87 524.71 524.00 MinPts 16.97 10.82 2.42 2.56 549.40 548.41 MinPl-0-EOU 17.67 11.10 -1.73®' 564.15 562.97 MinPt-O-SF 19.15 12.19 -0.24 2.58 583.75 582.28 SfcRul>5.91 Exit Major 48.33• 40.41 28.93 5.95 731.96 726.61 CtCt<=15m>15.00 Exit Alert 817.52 804.20 798.1'imme 1920.10 1684.42 MinPt-O-SF 1209.52 1187.38 1176.9.mar0 2248.09 1910.09 MinPt-0SF 963141 9593.13 9574.48 258.18 3452.83 2304.93 TD OP21-W W01(P3)(Def Plan) Warning Alert 7.95 6.73 1.35 550 0.00 0.00 CtCt<=15m<15.00 Enter Alert 7.66 4.72 1.05 2.19 345.09 345.08 MinPts 777 463 1.17 2.09 370.09 370.06 MinP50-EOU 7.93 4.69 1.33 immEra 380.07 380.04 MinPt-OSF 8.85 5.25 22 eP, 404.97 404.90 MinPt-OSF • 48.75 41.82 38.96 8.33 597.60 595.89 CtCt<=15m>15.00 Exit Alert 1833.87 1814.18 1804... 2160.13 1851.37 MinPtOSF 9059.57 9027.76 9012.35 293.89 2772.02 2175.10 TD OP22-W W03(P1)(Def Plan) Warning Alert , 15.91 14.67 2.93 11.83 0.00 0.00 CICt<=15m<15.00 Enter Alert • 13.91 9.961 ..94 3.20 435.44 435.30 MinPts • 14.07 9.84 1.10 3.04 450.38 450.17 MinPt-O-EOU 14.74 10.16 1.77 gnj 470.22 469.92 MinP5-OSF 48.75 40.89 35.78 5.89 643.37 640.72 CtCt<=15m>15.00 Exit Alen 1667.04 1643.65 1832. a fillL7 2470.33 2041.06 MinPt-0SF 9218.27 9155.89 9125.19 150.14 4885.42 2493.21 TD ME=®IIIMEn IIE250.00 250.00 CtCt<=15m<15.00 Enter Alert 0124-08(P9)(Def Plan) Warning Alert 31.87 30.65 6.13 25.04 0.00 0.00 CICt<=15m<15.00 Enter Alert IIIIIIIEE 24.83 gPM 5.83 512.35 511.75 MinPts 3552 18.30 9.7:IIIMB" 743.28 737.49 MinPt-0-SF 38.21 17.92 8.38 1.94 788.18 780.40 MinPt-O-EOU • 39. 17.9 7.88 189 803.12 794.60 MinP50-EOU 46.87 19.6 6.61 1 761 897.46 883.09 MinPts 153.27 121.53 106.28 4 58 1582.93 1443.86 O5F>5.00 Exit Alert 325.27 278.92 256. MIME 2502.81 2057.99 MinPt-O-SF 383.71 327.09 299.26- 2971.09 2233.65 MinPt-0SF 598.37 523.94 487. .. KE, 5355.08 2554.94 MinPt-0SF 570.13 503.6 1 8.69 5982.93 2637.46 MinP50-ADP 567.7•'.maim 471.40 8.91 6095.75 2652.29 MinPt-0-EOU 1111111=1 505.19 475.42 9 49 6341.00 2684.52 MinPt-CtCt 914.59 752.72 672.2 Min 8705.69 2995.32 MinPt-0SF 3357.24 3063.54 2917.1''® 12515.75 3414.26 MinPt-0SF 31.87 29.24 6.13 11 63 250.00 250.00 CtCt<=15m<15.00 Exit Alert 3293.05 2994.13 2845.1.® 13321.33 3402.66 MinPt-0SF 3329.46 3027.58 2877.1 mum 13578.30 339125 MinPt-0SF WEIME 2877.31 11.08 13764.09 3391.14 MinPts 2949.49 2541.21 2337.56 7.24 16837.24 3378.73 TD 13354.741 3061.11 2914.79 11.46 12511.43 3414.28 MinPt-C1Ct OP18-08PB1(Def Survey) Warning Alert 24.04 22.82 4.57 18.64 0.00 0.00 CtCt<=15m<15.00 Enter Alert 99 15.78® 7.19 338.06 338.06 MinPts 22.89 3.42 6.80 367.88 367.86 MinPt-0-EOU 26.32r�i 6.85 4.65 512.08 511.49 MinPt-0-EOU 31.10® 11.62 3.05 636.55 634.07 MinPt-O-EOU i 34.82. 15, gn 706.32 701.89 MinPts 50.53 24.7.Nom 2.01 895.61 881.37 MinPt-O-ADP • 51.06 24.92 12.46 gIll 900.58 885.98 MinPt-0SF 142.58 109 56 93 72 4.46 1335.83 1260.47 TD OP18-08P82(Def Survey) Warning Alert 24.04 22.82 4.57 18.64 0.00 0.00 CtCt<=151n<15.00 Enter Alert 22.78 19.78 3.31 7.19 338.06 338.06 MinPts 22.89 19.70 3.42 6.80 367.88 367.86 MinPt-0-EOU 26.321 20.92 6.85 4.65 512.08 511.49 MinP5-0-EOU 31101 21.1_1 11.62 3.05 636.55 634.07 MInP50-EOU Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 1 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 34.82 21.67 15.35 2.55 706.32 701.89 MinPts 50.53 24 74 1246 2.01 895.61 881.37 MinPt-O-ADP 51.06 24.92 12.46 2.001 900.58 88598 MinPt-O-SF 163.04 129.43 113.23 5.00 1719.41 1542.07 OSF>5.00 Exit Alert 172.51 137.02 119.88 5.00 1868.78 1648.25 OSF<5.00 Enter Alert 19042 149.45 129.5 000000000{' 2195.12 1875.17 MinPt-OSF 191.33 150.16 130.1.00000000000 2206.82 1883.00 MinP1-0SF 227.50 181.01 158 38 5 00 2511.76 2062.55 OSF>5.00 Exit Alert 691.27 594.85 547.1• 131 4713.58 2470.63 MinP1-0SF 1256.18 1083.42 997.5 ® 7698.90 286299 MinPt-O-SF 1543.01 1327.12 1219.6 MIME 9328.53 3077.18 MinPt-O-SF 1610.59 138476 1272.3'000000000Aa 9702.43 312632 MinPt-O-SF 1754.51 1508.47 1385.'•.111138:2. 10458.81 3225.73 MinPt-O-SF 1949.84 1677.32 1541. •® 11449.52 3355.94 MinPt-O-SF 2196.68 1901.79 1754.:'0000000000000 12510.01 3414.29 MinPt-O-SF 2221.72 1920.49 1770.3 0000000000■• 13106.43 3410.13 MinPt-O-SF 2221.10 1920.2•..1155330 7.40 13231.19 3406.73 MinPt-O-ADP 2195.0 000009 M15;211110 13577.01 3391.26 MinPts 1808.47 1445.76 1264.89 5.00 15592.63 3394.81 OSF<5.00 Enter Alert 1806.7' 1441.70 1259.64 4.96 15653.54 3394.62 MinPt-CtCt 1807.7'00000 1257.66 4.94 15708.52 3394.54 MinPt-O-EOU 1808.95 1440.96{00 1=2j 4.93 15733.48 3394.50 MinPt-O-ADP 1843.6 �1 1257.01 4.72 16355.26 3386.42 MinPt-O-EOU 184484 1452.46,1 4.71 16380.17 3385.69 MinPt-O-ADP 1866.73 1466.98 1267.6. 4.631 16576.28 3379.97 MinPt-O-SF 1974.22 1535.5 000000 4.51 17616.97 3374.87 MinPt-O-ADP 1984.07 1540.65 1319.4' 4 48 17723.00 3374.27 MinPt-0SF OP18-08(Def Survey) Warning Alert 24.04 22.82 4.57 18.64 0.00 0.00 CtCt<=15m<15.00 Enter Alert MEIZIE 19.78 MEG 7.19 33806 338.06 MinPts 22.8'®' . 3.42 6.80 367.88 367.86 MinPt-O-EOU 26.3.®.' 6.85 4.65 512.08 511.49 MinPt-O-EOU 31.1.® 11.62 3.05 636.55 634.07 MinPt-O-EOU 34.8 ,0000000001.7 15. -000000000001 706.32 701.89 MinPts 50.53 24.7'00000000P)7 2.01 895.61 881.37 MinPt-O-ADP 51.06 24.92 12.46 000000000'1" 900.58 885.98 MinPt-0SF 163.04 129.43 113.23 5.00 1719.41 1542.07 OSF>5.00 Exit Alert 172.51 137.02 119.88 5.00 1868.78 1648.25 OSF<5.00 Enter Alert 190.42 149.45 129.5 11=1152 2195.12 1875.17 MinPt-O-SF 191.33 150.16 130.1'0000000000E 2206.82 1883.00 MinPt-0SF 227.50 181.01 158.38 5.00 2511.76 2062.55 OSF>5.00 Exit Alert 691.27 594.84 547.1.00000000000•Is1.'� 4713.58 2470.63 MinPt-O-SF 1256.18 1083.40 997. .0000000000011 7698.90 2862.99 MinPt-O-SF 1543.01 1327.10 1219.6•IMMEfi 9328.53 3077.18 MinPt-OSF 1610.59 1384.73 1272. .MEE 9702.43 3126.32 MinPt-O-SF 1754.51 1508.44 1385.'.000000000002 10458.81 3225.73 MinPt-O-SF 1949.84 1677.29 1541.51000 15 11449.52 3355.94 MinPt-O-SF 2196.68 1901.76 1754.7'0000000001'1 12510.01 3414.29 MinPt-O-SF 2221.72 1920.46 1770.3.000000000'1" 13106.43 3410.13 MinPt-O-SF 2221.10 1920.1'00000 7.40 13231.19 3406.73 MinPt-O-ADP 2195.0'00000•en MEE MEE 13577.01 3391.26 MinPts 1808.73 1446.17 1265.38 5.00 15588.45 3394.85 OSF<5.00 Enter Alert =cm,85 1441.66 1259.58 4.96 15653.54 3394.62 MinPt-CtCt 1807.7911440.67 1257.60 4.93 15708.52 3394.54 MinPt-0-EOU 1808.95 1440.92100000)'. 4.93 15733.48 3394.50 MinPt-O-ADP 1843.6 =ME 1256.95 4.72 16355.26 3386.42 MinPt-O•EOU 1844.84 1452.4 Nom 4.71 16380.17 3385.69 MinPt-O-ADP 1866.40 1463.4 9. 8•' 4.64 16678.67 3378.96 MinPt-O-ADP I 1994. 1536.91 1308.44 4.36 18215.71 3367.11 MinPt-Ctet 1996 1535.0 1304.73 4.33 18300.55 336462 MinPt-O-EOU 1998.69 1535.4 1304.30 4.32 18340.47 3363.45 MinPt-O-ADP 2008.51 1540.33 1306.73 4.301 18455.26 336008 MinPt-O-SF I 2014.660 1508.861 1256.45 3 99 19438.28 335095 MinPts OP17-02PB1(Def Survey) Warning Alert 32.05 30.82 6.18 25.18 3.95 3.95 CtCt<=15m<15.00 Enter Alert 31.04 28.21 5.18 10.53 288.61 288.60 MinPts 31.18 28.11 5.31 9.75 313.39 313.39 MinPt-O-EOU 41.72 36.24 15.86 00000000 474.40 474.08 MinPt-O-SF 49.07 42.73 23.21 7.54 527.15 52641 CtCt<=15m>15.00 Exit Alert 51.35 44.73 25.49 7.5 541.45 540.56 MinPt-0SF 85.33 75.21 59.47 8.31 712.32 707.68 MinP1-0SF 362.62 344.97 336,75 . 20 48 1478.77 1368.16 MinP1-0SF 648.42 630.83 622.56 36.79 2320.25 1955.43 MinPt-O-SF 662.32 645.26 636. 38.76 2762.09 2171.54 MinPt-O-SF 628.91 611.95 603,04 37.0 3038.13 2247.79 MinPt-OSF 627.7'oO.1:an 601.87 37.08 3085.60 2256.06 MinPt-0-EOU 000000 610..' 601.8 37.09 3089.15 2256.62 MinPts 631.24 613.70 605. 1�'1 3237.44 2276.62 MinPt-O-SF 1225.72 1095.98 1031,6•=111131211 7319.54 2813.13 MinPt-OSF 4511.66 4209.7.mrzag 14.99 14128.61 3390.56 MinPt-O-ADP 0000 3451.49 3230.59 8.81 17896.00 3373.30 MinPt-CtCt 3720.85 3245.34 3008.08 7.84 1891991 3355.48 TO 3889.65 344361 3221.0. 18049.96 3371.62 MinPt-O-SF 0113-03(P6)(Def Plan) Warning Alert 64.06 61.66 6096 44.65 25000 250.00 MinPt-CtCt 64.10 61.57 60.79 40.67 279.67 279.67 MinP1-0-EOU 64.12 61.57 60.791 40.30 284.61 284.61 MinPt-O-ADP 128.80 102.24 89.45 5.00 984.71 962.99 OSF<5.00 Enter Alert 131.65 104.44 91.33 498 998.91 975.80 OSF>5.00 Exit Alert 5837.00 5570.36 5437.54 21.971 11447.74 3355.71 MinPt-O-SF 6109.90 5830.73 5691.641 21 961 1210001 3407.80 MinPt-0-SF Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 2 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 6173.71 5891.55 5750.96 21.95 12325.01 3415.22 MinPt-O-SF 5650.0' 5267.37 5076.49 14.80 17001.29 3378.50 MinPt-CtCt 6086.24 5794.16 5648.61 20.90 13340.63 3401.61 MinPt-O-SF • I 6086.141 5794.061 5648 51 20 9 13358.19 3400.60 MinPts 5512.62 5094.77 4886.35,..m. 13.22 18111.07 3370.16 MinPt-O-SF 5445.19 5014.63 4799.84 12.67 18474.88 3359.53 MinPt-O-SF 5259.01 4793.92 4561.87 11.33 19438.28 3350.95 TD 6244.53=60.671 5819 231 22.07 12624.09 3413.73 MinPts 0115-54(P5)(Def Plan) Warning Alen 48.02 46.80 15.21 38.23 0.00 0.00 CtCt<=l5m<15.00 Enter Alert 48.0 45.38 15.21 17.74 250.00 250.00 MinPts 48.10 45.29 15.29 16.68 279.75 279.75 Min1:1-0-EOU 49.14 46.01 16.33 15.29 363.83 363.81 CtCt<=15m>15.00 Exit Alert 97.90 77.34 65.09 4.70 869.33 856.91 OSF<5.00 Enter Alert 101.86 79.66 69.06 892.83 878.79 MinPt-O-SF 191.70 142.64 118.72 3.98 1290.36 1224.45 MinPt-O-SF 246.97 196.34 171.63 4.97 1465.28 1358.31 OSF>5.00 Exit Alen . 8632.21 8361.87 8227.2.MOn 11513.83 3363.80 MinPt-OSF 48.02 45.38 1521 17.74 250.00 250.00 CtCt<=15m<15.00 Exit Alert 8725.13 8424.20 8274. 29.0 13585.05 3391.24 MinPt-O-SF 8723.73 8423.02 827316 29.10 13620.28 3391.19 MinPt-O-ADP , 8723.68 8423.011 827317 29.11 13623.79 3391.19 MinPt-O-EOU I 8723.60 8423.07 8273 30 29.12 13834.34 3391.18 MinPt-CICt ' 8723.11 8425.50 8277 19M-BEE111 13365.69 3400.15 MinPt-O-SF 8504.1 8096.63 7893 08 20.89 16923.61 3378.61 MinPt-CtCt 8502.75 8087.67 78806111 20.531 17143.14 3378.18 MinPt-O-SF 8436.18 7987.25 776328E 18.831 18023.28 3372.12 MinPt-O-SF 8348.63 7862.54 7619.98 1.21 19088.94 3354.24 TD 9030.941 8738.461 8592.711 30.98 12623.68 3413.73 MinPts OP16-03(Def Survey) Warning Alert 40.03 38.81 7.76 31.71 0.00 0.00 CtCt<=15m<15.00 Enter Alert 40.03 38.52 7.76 25.60 114.11 114.11 MinPts 40.3 37.73 8.05 15.09 278.91 278.91 MinPt-O-EOU 45.35 41.84 13.08[ 12 5711 447.67 447.48 MinPt-O-SF 48.87 45.09 16.60 12.60 494.90 494.44 CtCt<=15m>15.00 Exit Alert 76.76 68.98 44.4'gmai 758.16 751.75 MinPt-O-SF 167.53 153.36 135.26 MIK 1389.29 1301.74 MinPt-O-SF 340.37 315.87 304...�' I 2204.23 1881.28 MinPt-O-SF 395.78 368.98 356.11 mum 2581.02 2096.34 MinPt-0SF 411.63 393.79 12.53 3431.11 2302.07 MinPt-CtCt 447.6• 397.47 372.88 9.08 4094.89 2389.31 MinPt-CtCt 392.80 366.06 8.34 4294.61 2415.56 MinPt-CICt =FM, 360.39 323.36 5.87 5349.05 2554.15 MinPt-CtCt 437.90 349.50 305.79 5.00 5868.39 2622.41 OSF<5.00 Enter Alert =Mfg 341.33 294.90 4.68 6113.31 2654.60 MinPt-CtCt I 33447 284.46 4.34 6433.20 2696.64 MinPt-CtCt 442.. Ammo 276.09 4.01 6727.55 2735.33 MinPt-O-EOU MEW 284.54 213.93 3.02 8011.21 2904.04 MinPt-CtCt 269.21 188.91 2.68 8665.75 2990.07 MinPt-CtCt 321.20 167.62 91.3.®' 9719.09 3128.51 MinPt-O-SF 303.13 159.8 2.12 9798.32 3138.02 MinPt-O-ADP 283.711=0E. 93.07 2.24 9885.10 3150.33 MinP1-0-EOU i 170.39 131.70 3.20 10132.81 3182.89 MinPt-CtCt i 289.95,*1*1 74.27 2.02 10334.42 3209.38 MinPt-O-EOU 314.10 150.3.MIEE 1.92 10389.36 3216.60 MinPt-O-ADP 340.21 160.96 71.83®'. 10439.74 3223.23 MinP1-OSF 1417.63 1133.31 991.64 5.00 12182.08 3412.90 OSF>5.00 Exil Alert 1477.16 1180.76 1033.05 5.00 13752.69 3391.14 OSF<5.00 Enter Alert • I906.76 518.04 324.17 2.34 16414.95 3384.68 MinPt-CtCt 91081 516.20 319.40 2.31 16564.93 3380.28 MinPt-O-EOU 916.20 5174 318.61 2.30 16693.75 3378.94 MinPt-O-ADP 922.68 520.52 319.93 2.30 16780.62 3378.82 MinPt-O-SF 1137.14 689.30 465.87 2.54 17939.58 3373.05 MinPt-O-SF 1150.0' 689 24 459.32 2.50 18392.70 3361.91 MinPt-0-EOU , 1153.51 690 07 , ilIZI 18452.51 3360.16 MinPts 1158.6 1=1B1E3 462.11 2.50 18612.64 3357.45 MinPt-O-EOU 1161.68 694.57. 2.49 18667.35 3357.10 MinPt-O-ADP 1174.94 700.78 464.1'6n 18828.75 3356.07 MinPt-O-SF • OP14-53(Def Survey) Pass 55.86 53.58 23.05 23.91 243.97 243.97 MinPts 55.88 53.52 23.07 23.18 263.83 263.83 MinPt-O-EOU 56.02 53.61 23.21 IMMILIFE 293.54 293.54 MInPt-OSF 56.23 53.81 23.4.' 22.71 318.30 318.29 MinPt-OSF 118.30 100.36 85.49 6.53 900.71 886.09 MinPt-O-SF 10037.51 9755.80 9615. 35.7- 12916.30 3411.90 MinPt-O-SF 9940.16 9663.971 9526.36 36.11 13196.01 3407.96 MinPt-O-ADP 9940.02 9663.941 9526.39 36.13 13201.10 3407.79 MinPt-O-EOU I 9939.95 9664.02 9526.54 36.15 13207.88 3407.57 MinPt-CtCt 9981.29 9707.301 9570.801 36.561 13595.42 3391.22 MinPts 1 9795.41 9464.49 9299.53 29.69 15534.61 3395.51 MinPt-CtCt 9769.41 9396.871 9211.09 26.29 16617.72 3379.21 MinPt-O-EOU 1 9748.28 9365.25 9174.22 25.51 16886.84 3378.66 MinPt-CtCt 9617.13 9194.44 8983.58 22.80 17890.06 3373.33 MinPt-CtCt 9521.57 9058.94 8828.11 20.62 19134.39 3353.81 TD 9976.71 9702.21 956545 3647 13580.61 3391.25 MinPt-0SF I 9972.71 9692.88 9553.47 35 76 14070.27 3391.14 MinPts 9606.88 9181.8 8969.761 22.651 17944.12 3373.03 MinPts OP12.01(Def Survey) Pass 88.0' 86.828 70.92 2.62 2.62 MinPts . 84.81® 31.29 277.17 277.17 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 3 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 87.77 84.58 54.96 27.12 331.35 331.34 MinP1-0-EOU 149.40 127.23 116.64 857.41 845.77 MinPt-0SF 179.58 148.94 134.23 6.06 983.13 961.58 MinPt-0-SF 5386.14 5188.91 5090.7•misic 9060.51 3041.95 MinPt-O-SF 6253.90 6027.99 5915.5 Mama 10187.51 3190.07 MinPt-O-SF OP26-DSPO2(Def Survey) Peas I 256.261 255.14 223.45 228.88 3.99 3.99 MinPts 203.33 181.16 170.52 91870.40 857.91 MinPt-O-SF 187.67 162.18 150.00 7.66 999.71 97652 MinPt-O-SF 186.36 161.52 149.66 7.81 1021.40 995.96 MinPt-O-ADP 185.67 161.41 149.84 7.97 1038.61 1011.30 MinPt-O-EOU 1 18506 162.11 151.19 8.42 1072.68 1041.39 MinPt-CtC1 185.17 162.95 152. • -1 1089.54 1056.15 MinPt-O-SF 411.58 399.22 378. ® 1607.80 1461.85 MinPt-O-SF 667.05 644.87 634.2 1::0 1996.59 1738.01 MinPt-O-SF 788.70 762.20 749. 4 Man 2136.19 1834.88 MinPt-O-SF 5596.04 5554.09 5533.60 136.56 3792.24 2349.54 TD OP10-09(Def Survey) Pass 1 104.04 102.82] 71.231 84.00 0.00 0.00 MinPts 104.441 102.351 71.63 49.36 199.07 199.07 MinP1-0-EOU 186.09 163.90 153.2: ;IEE 822.39 812.83 MinPt-0-SF 237.63 205.78 190.47*4 958.34 938.05 MinPt-O-SF 2622.74 2547.73 2510.7.MMEIS. 3966.11 2372.39 M1nPt-0-SF 3718.86 3810.54 3556.9 5WL 5416.48 2563.01 MinPt-0SF 4151.57 4031.48 3971.9 mEg, 5924.09 2629.73 MinPt-O-SF 7380.87 7119.68 6989.5.• 11451.78 3356.24 MinPt-O-SF 7555.96 7266.'••=11ME 26.23 13609.91 339120 MinPt-0-ADP 7555.9. 7266.9 7122.96 26.23 13612.09 3391.20 MinPt-0-EOU 7266.97 7123.00 26.24 13614.26 3391.20 MinPt-CtCt =MR 7257.34 7110.98 25.79 13954.14 3391.14 MinPt-CtCt 7552.66 MEM 7109.00 25.59 14044.09 3391.14 MinPt-0-EOU 7555.7 Mon 7103.86 25.13 14288.50 3387.95 MinPt-0-EOU 7556.79 7254.36 MIME 25.06 14298.48 3387.39 MinPt-O-ADP MMIEE 6815.46 6615.56 18.05 16957.47 3378.56 MinPt-CtCt 7564.00 7277.27 7134.44 13308.83 3403.30 MinPt-0SF 7554.17 7267.9.IN= 26.48 13379.07 3399.34 MinPt-0-ADP 6787.56 6293.61 6047.13 13.77 19438.28 3350.95 TD 7867.64 7582.24 7440.041 27.661 12622.39 3413.74 MinPts 0106-05 MWD-Standard(Non-Def Survey) Par. 141.32 110.96 58.21 224.07 224.07 MinPts 143.77 141.03 110.96 51.94 253.92 253.92 MinPts 143.87 140.90 111_06 48.05 276.24 27824 MinPt-0-EOU 224.04 209.71 191.23® 721.98 717.00 MinPt-0SF 214942 2130.85 2116.61 115.72 1278.38 1214.83 TD 4705.29 4665.39 4646.05 121.62 1189.04 1141.34 MinPt-0SF 4625.28 4586.03 4567.02 121.62 1190.44 1142.51 MinPt-0SF 4527.58 4489.13 4470.52 121.58 1192.27 1144.04 M1nPt-0SF 4015.35 3980.28 3963.35` 118.58 120442 1154.19 MinP9-0SF 3830.96 3797.19 3780.92 117.67 1211.00 1159.68 MinPt-0SF 3608.99 3577.08 3561.74 1219.26 1166.53 MinPt-0SF 3419.02 3388.74 337421 117.61 1226.64 1172.62 MinPt-0SF 3224.84 3196.38 318276 118.36 1234.81 1179.36 MinPt-0SF 2713.48 269123 2680.68 121.85 1258.58 1198.80 MinPt-0SF 2608.18 2586.98 2575.37 122.99 1262.87 1202.28 MinP1-0SF 4840.30 4799.24 4779.33 12148 1188.49 1140.88 MinPt-0SF 4892.77 4851.27 4831.13.. 121.46 1189.01 1141.31 MinP9-0SF 5215.33 5170.06 5148.04 118.40 1201.78 1152.00 MinPt-0SF 5635.20 5581.89 5555.84 108.17 1245.58 1188.20 MinPt-0-SF • 5888.96 5830.80 5802.33 103.40 1276.41 1213.24 MinPt-0-SF 0106-05 current(Non-Def Survey) Pass 111111111173 141.32 110.96 58.21 224.07 224.07 MinPts 143.77 141.03 110.96 51.94 253.92 253.92 MinPts 143.87 140.90 111.06 48.05 278.24 278.24 MinPt-0-EOU 224.04 209.71 19123' 15.55 721.98 717.00 MinPt-0SF 1743.68 1726.26 1710.8 100.14 1263.59 1202.87 MinPt-0SF 2149.03 2131.11 2116.22 119.86 1278.15 1214.65 TD 3174.80 3150.86 3139.4.=ME 1238.02 1180.35 MinP1-0SF 2949.48 2927.28 2916.6:=gm 1248.85 1189.23 MinPt-0SF 5209.01 5173.61 5156.4 =1315E 1200.39 1150.83 MinPt-0SF 5626.22 5586.36 5566.9 =4 r 1244.03 1186.93 MinPt-0SF 5759.20 5718.20 5698.2 �" '1 1262.23 1201.76 MinPt-0-SF 5875.85 583418 5813.8; 144.6' 1274.85 1211.98 MinPt-0SF OP08.04(Def Survey) Par 1 120.0 118.7 87.211 97 05 0 00 0.00 MinPts 120.33' 118.141 87.52 54.60 183.90 183.90 MinPt-0-EOU 236.92 215.15 204.11®'- 845.00 834.12 MinPt-0SF 24827 22549 214.71 Milla3 873.25 860.57MinPt-0SF 6713.88 6593.24 6533.41 mina 6183.77 2663.86 MinPt-0SF OP08-04P81(Def Survey) Pass 1 120.01 118.79 87.211 97.05 0 00 0.00 MinPts 120.33 118141 87.52 54.60 183.90 183.90 MinPt-0-EOU 236.92 215.15 20411 MIZE 845.00 834.12 MinPt-0SF 248.27 22549 214.71 mar 873.25 860.57 MinPt-0SF 6038.04 5971.27 5938.3:IMMO 3924.31 2366.89 MinPt-0SF 0106-05(P9c)(Def Plan) Pass Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 4 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 144.03 142.81 11122 116.68 0.00 0.00 Surface 144.03 141.40 111.22 54.28 249.11 249.11 MinPts 144.10 141.30 11130 50.88 278.39 278.39 MinPt-O-EOU 240.18 22678 207.37 17.83 791.33 783.40 MinPt-O-SF 613.67 599.98 580.86 44.73 1086.04 1053.09 MinPt-0-SF 4454.91 4432.70 4422.10 200.54 1194.19 1145.65 MinPt-O-SF 4370.75 4349.01 4337.94\ 201.00 1195.56 1146.80 MinPt-O-SF 5880.51 5838.36 5817.81 143.10 1274.70 1211.86 MinPt-OSF 8310.71 6264.65 6242.11 139.97 1331.17 1256.82 MinPt-O-SF 6970.79 6917.56 6891.44 133.42 1418.62 1323.86 MinPt-OSF 726222 720492 7176.76 128.92 1479.36 1368.59 MinPt-OSF 7853.93 7787.39 775462 119.80 1756.10 1568.28 MinPt-OSF 7931.42 7864.68 7831.81 120.61 1789.71 1592.22 MinPt-OSF 7977.79 7910.67 7877.6 1809.52 1606.29 M1nPt-O-SF 8118.80 8049.83 8015.83 119.40 1869.11 1648.48 MinPt-OSF 8512.42 8440.75 840540 12041 1992.77 1735.34 MinPt-O-SF 9132.13 9055.93 9018.32, 121.40 2161.33 1852.20 MinPt-0-SF 11319.10 11230.36 11186.49 128.98 2335.85 1964.88 TD 0107-04(Def Survey) Paas r 128.0 126.81 95.231 103.61 3.88 3.88 MinPts 128.221 125.71 95.41 50.68 263.57 263.57 MinPt-O-EOU 128.37 125.82 95.56 mom 292.92 292.92 MinPt-0SF 128.56 128.01 95.7 M231 312.48 312.47 MinPt-0SF 245.31 232.41 212.50 828.23 818.34 MInPt-0-SF 2293.21 2271.01 2260.4*IIKEE 1974.93 1722.87 MinPt-0SF 3359.17 3325.46 3309.1• .'.'1 2271.36 1925.00 MinPt-0SF 9778.00 9726.61 9701.41 193.98 2968.40 2233.03 TD OP05-06PB2(Def Survey) Pea 151.79 149.91 118.98 79.86 153.94 153.94 MinPts 151.86 149.86 119.05 75.29 173.94 173.94 MinPt-O-EOU 252.98 242.07 220.17®"- 747.71 741.74 MinPt-0-SF 6243.27 8221.06 6210.•:ME="'-* 8 1065.86 1035.40 MinPt-O-SF 9363.81 9282.18 9241.8 mum 1424.33 1328.13 MinPt-0-SF 11204.51 11110.66 11064.2 NW= 1614.97 MinPt-0-SF 11256.95 11162.71 11116.11 120.76 1839.19 1627.32 TD OP05-O6PB1(Def Survey) Pana 151.79 149.91 118.98 79.86 153.94 153.94 MinPts 151.86 149.86 119.05 7529 173.94 173.94 MinPt-O-EOU 252.98 24207 220.17 MIME 747.71 741.74 MinPt-0SF 1758.37 1744.75 1725.56 129.00 1331.05 1256.75 TO 1 1763.351 1749.721 1730.54 129.311 1331.08 1256.75 MinPts OP05-06(Def Survey) Pass AMINIM 151.79 149.91 118.98 79.86 153.94 153.94 MinPts 151.86 149.86 119.05 7529 173.94 173.94 MinPt-O-EOU 252.98 242.07 220.17 mgall 747.71 741.74 MinPt-0SF 8243.27 6221.06 621046 m"' 1065.86 1035.40 MinPt-0SF 9363.81 9282.17 9241.871 55! 1424.33 1328.13 M1nPt-0SF 12608.32 12506.98 12456.80 12562 2144.40 1840.54 TD OP09-S1(Del Survey) ( 12206 300 11761 74 11539.930 27.52' 18904.39 3355.58 MinPts 12079.81 11610.43 11376.23 25.79 19438.28 3350.95 TD 112.57 109.65 79.76 3823 283.14 283.14 MinPt-O-EOU 290.05 26787 25724 13.02 95721 938.02 MinPt-0SF 320.07 295.28 283.5 1001.86 978.45 MinPl-0SF 371.03 342.33 328.59 13.46 1071.71 1040.54 MinPt-0SF 12343.91 12076.501 11943.29 46.33 13485.91 3394.19 MinPt-0-ADP 12346.17 12077.88 11944.22 46.181 13579.43 3391.25 MinPt-0SF MEM 12025.53 11882.30 42.98 14581.40 3382.46 MinPt-CtCt 12313.61 MEW*: 11881.03 42.79 14614.70 3382.56 MinPt-0-EOU 12314.50 12025.0• 11880.8 42.69 14832.82 3382.76 MinPt-0-ADP 1000 ' 11947.79 11787.51 38.27 15463.48 3396.39 MinPt-CtCt 12274.6* 11940.06. 11773.27 36.80 15806.72 3394.38 MinPt-0-EOU 12278.92 11940.5*MIME. 36.60 15856.65 3394.30 MinPt-0-ADP 12519.52 12243.45 12105.9*.Man 12967.15 3411.51 MinPt-0SF 12343.91 12077.4..11= 4649 13342.51 3401.50 MinPt-0-ADP 12343.;'Nfr261k11 1194469 46.50 13344.24 3401.40 MinPt-0-EOU .11EME7 12077.47 11944.79 46.52 13347.64 3401.21 MinPt-C(Cl 0111-01PB7(Def Survey) Pas 95.87 9417 63.07 55.64 138.95 138.95 MinPts 96.23 93.91 6342 41.04 253.88 253.88 MinPt-O-EOU 96.38 94.02 63.5 MZIE 283.38 283.38 MinP1-0SF 220.06 197.90 187.2 =ME 977.37 956.34 MinPt-0-SF 313.61 277.13 259.50 8.86 1195.76 1146.97 MinPt-0-SF 4326.49 425433 4218.75 60.78 4140.63 2395.33 TD 0111.01(Def Survey) Pas 95.87 94.17 63.07 55.64 138.95 138.95 MinPts 96.23 93.91 63.42 41.04 253.88 253.88 MinPt-0-E0U 96.38 94.02 63.5 101110 * * 283.38 283.38 MinPt-0-SF 220.06 197.90 187.2 �r 1 977.37 956.34 MinPt-0SF 313.61 277.13 259.5000000000 1195.76 1146.97 MinPt-0SF 5770.98 5630.96 5561.••maw 731685 2812.75 MinPt-0SF OPO4-07(Def Survey) Pae 159 26 156.80 126.46 64.14 258.60 258.60 MinPts 159.29 156.78 126.48 63.11 270.65 270.65 MinPt-0-EOU 159.38 156.86 126.5:MIR 287.78 287.77 MinPt-0SF 159.61 157.09 126.8* 62.86 307.23 307.22 MinPt-0-SF • Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 5 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor 1 Major 296.39 277.98 263.58 16.03 90280 888.03 MinP1-0-SF 8258.23 8202.20 817468 15002 3406.27 2298.81 MinPt-0SF 8746.77 8687.79 8658.8 150.81 3581.03 2321.78 MinPt-O-SF 10226.51 10161.83 10129.69 180.05 3918.44 2366.12 TD OPO4-07PB1(Def Survey) Pass 159.26 156.80 126 A6 64.14 258.60 258.60 MlnPts 159.29 156.78 126.48 63.11 270.65 270.65 MinPt-O-EOU 159.38 156.86 126.58 287.78 287.77 MinPt-O-SF 159.61 157.09 126.81 62.86 307.23 307.22 MinPt-O-SF 296.39 277.98 263.58 Mani 902.80 888.03 MinPt-0SF 8694.66 8636.50 8607.91 152.05 3531.37 2315.25 TD Oliktok Point 1-2PB1(Det Survey) Pass 176.54 17546 143.73 162.75 0.00 0.00 Surface =En 175.46 143.7 162.75 40.00 40.00 MinPts 174.88 172,13 142.07 83.30 369.01 368.99 MinPts 174,90 172,09 142.09 81.88 382.98 382.94 MinPt-O-EOU 175.11 172.14 142.29 58.75 406.27 406.20 MInP1-0-EOU 187.3 173.16 154.54 13.13 779.54 772.17 MInPt-O-EOU 188.•1 173.23 156.09 11.99 807.57 798.81 MInPt-O-EOU 196.76 174.64 163.9 Ll4 924.17 907.76 MinPt-OSF 202.58 177.80 165.• �: 6 1003.31 979.76 MinPt-0SF 219.23 192.18 179.1•IIMMICE 1310.57 1240.56 MinPt-O-SF 323.50 281.32 260.77 2219.70 1891.55 MinPt-O-SF 1966.77 1850.50 1792.85 17.05 617141 2662.23 TD Oliktok Point 1.2(Def Survey) Pew 176.54 175.46 143.73 162.75 000 0.00 Surface 176.54 175.46 143.7 162.75 40.00 40.00 MinPts 17488 172.13 14207 63.30 369.01 368.99 MinPts 174.90 17209 142.09 61.88 382.98 382.94 MinPf-0-EOU 175.10 172.14 142.29 58.75 406.27 406.20 MinPt-O-EOU 187.35' 173.16 154.54 13.13 779.54 772.17 MinPt-O-EOU 188. 173.23 156.09 1199 807.57 798.81 MinPt-0{OU 196.76 174.64 163.•.non 924.17 907.76 MinPt-OSF 202.58 177.80 165.• ®. r 1003.31 979.76 MinPt-0SF 219.23 192.18 179.1• 8.40 1310.57 1240.56 MinPt-OSF 323,50 281.32 260,7711111111111111111 2219.70 1891.55 MinPt-0SF 2160.04 2020.91 1951.8•mmegI 6810.52 2746.23 MinPt-0SF • 5127.90 4873.41 4746.66 20.22 11021.52 3299.69 TO Oliktok Point I-2PB2(Def Survey) Par 176.54 175.56 143.73 178.37 0.00 0.00 Surface 176.54 17546 143.7 162.75 40.00 40.00 MinPts 174.88 172.18 142.07 6442 369.01 368.99 MinPts 174,90 172.14 142.09 62.94 382.98 382.94 MinPt-O-EOU 175.1 142.29 59.65 406.27 406.20 MinPt-O-EOU 187.35 173.17 154.54 13.14 779.54 772.17 MinPt-O-EOU l88.90' 173.24 156.09 11.99 807.57 798.81 M1nPt-0{OU 196.76 17464 163.9 j 924.17 907.76 MinPt-O-SF 202.58 177.80 165.9 1003.31 979.76 MinPt-OSF 219.23 192.18 179.21 1310.57 1240.56 MinPt-O-SF 323.50 281.33 26078 1131 2219.70 1891.55 MInPt-O-SF 2160.04 2020.91 1951.8 M1n] 6810.52 2746.23 M1nPt-OSF 3459.47 3287.71 3172.32 18.13 8629.32 2985.28 TD OP03-P05PB1(Def Survey) Pass I 167.94 166.64 135.13 128.45 64.00 64.00 MinPts 168.05 165.827 135.24 74.89 244.00 244.00 MinPts 168.07 165.78 135.26 7289 258.74 258.74 MinPt-O-EOU 168.33 165.99 135.5.'1 292.73 292.73 MinPt-0SF 327.29 310.77 294.48 1.11110fin 899.75 885.21 MinPt-O-SF 4183.35 4157.75 4145. •MIME 1585.39 1445.64 MinPt-O-SF 4670.05 4640.78 4626.7 MIK 180169 160073 MinPt-O-SF OP03-P05(Def Survey) Pass t 167.94 166.64 135.131 128.45 64.00 64.00 MinPts /I 168.05 165.82° 135.24 7489 244.00 244.00 MinPts 168.07 165.78 135.26 72.89 258.74 258.74 MInPt-O-EOU 168.33 165.99 1355.8l 29273 292.73 MinPt-0SF 327.29 310.77 294.48 MGM 899.75 885.21 MinPt-O-SF 4135.92 4110.87 4098.8.=Ha 1564.17 1430.28 MinPt-O-SF 5248.29 5212.97 5195.8.=En 2042.54 1770.03 MinPt-O-SF 5533.61 5496.64 5478.6 Mi. 2150.26 1844.58 MinPt-O-SF 9638.90 9586.10 9560.19 185.99 2565.54 2089.03 TD OP03-P05PB2(Def Survey) Par 167.94 166.64® 128.45 64.00 64.00 MinPts 168.0 ' 165.8. 135.2• 74.89 244.00 244.00 MinPts 168.07 165.78 135.26 72.89 258.74 258.74 MinPt-O-EOU 168.33 165.99 135.5.=an 292.73 292.73 MinPt-OSF 32729 310.77 294.48 EDIE 899.75 885.21 MinPt-O-SF • 4135.92 4110.87 4098.8:MEE 1564.17 1430.28 MinPt-O-SF 5248.29 5212.97 5195.8.MMIZ:i. 2042.54 1770.03 MinPt-O-SF 5533.61 5496.64 5478.6 =1.lnn 2150.26 1844.58 MinPt-O-SF 7564.38 7518.26 7495.71 167.71 2359.81 1979.15 TD Oliktok Point I-1A-106(P5)(Def Plea) Pass 184.58 183.47 151.77 164.60 0.00 0.00 Surface MOM 183.47® 164.55 40.10 40.10 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 6 of 24 • Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 184.68 183.36 151.87 138.95 8420 8420 MinPt-O-EOU 351.36 340.16 318. illEfi 791.57 783.63 MinPt-O-SF 382.48 370.21 349.67®' 828.44 818.55 MinPt-O-SF 2092. MIME 20598.=NU 1217.35 1164.94 MinPts 7247.45 7224.94 7214.6MEM 1005.35 981.59 MinPt-O-SF 11760.06 11653.04 11600. .MIME 1384.68 1282.88 MinPt-O-SF • 13518.15 13398.20 13339.18 114.51 1623.11 1472.89 TD Oliktok Point I-1(Def Survey) Pass I 184.58 183.47 151.77 164.60 0.00 000 Surface 184.58 183.47 151.77 164.55 40.10 40.10 MinPts 184.68 183.36 151.87 138.95 84.20 84.20 MinPt-O-EOU 351.36 340.16 378.5 31.27 791.57 783.63 MinPt-O-SF 382.48 370.21 349.67 31,08 828.44 818.55 M1nPt-OSF , 1942.49 1925.32 1909.68 113.10 1218.49 1165.89 TD 7211.21 7189.01 7178.4.=ME 1038.87 1011.53 MinPt-O-SF 7799.08 7770.96 7757.3.MERE 1101.60 106665 MinPt-O-SF SP36-W5(P2)(Def Plan) Pate 11117883.331 17880.171 17850.5 5669.75 251.06 251.06 MinPts 17883.72 17880.43 17850.91 5432.8 278.83 278.83 MinPt-O-SF 17883.97 17880.70 17851.1 5481.9 301.04 301.04 MinP1-0SF 17883.61 17882.38 17850.80 14610.29 0.00 0.00 Surface 10758.02 10539.45 10431.63 49.87 12562.86 3414.03 MinPt-CtCt 7060.23 6718.11 6548.40 20.79 17698.70 3374.41 MinPt-CtCt 6216.60 5809.911 5607 841 15.381 19438.28 3350.95 MinPts S135-W4(P2)(Def Plan) o '/ Pa 1 17882.54 17879.3at 17849.7 5676.98 251.06 251.06 MinPts 17882.95 17879.85 17850.1 5431.9 278.86 278.86 MinPt-OSF 17883.20 17879.92 17850.3 5481. 301.10 301.09 MinPt-O-SF 17882.83 17881.60 17850.02 14609.65 0.00 0.00 Surface 11004.29 10785.65 10677.77 50.99 12566.17 3414.01 MinPt-CtCt 8303.87 7964.85 7796.43 24.65 17625.50 3374.82 MinPt-0tCt 7234.68 6828.181 6626.021 17.891 19438.28 3350.95 MinPts SP33-W3(P2)(Def Plan) Pass If 17880.861 17877.711 17848.05 5686.87 251.06 251.06 MinPts 17881.30 17878.00 17848.49 5430.2 278.91 278.97 MinP1-0-SF 17881.51 17878.23 17848.7 54591 298.41 298.41 MinPt-O-SF 15159.76 14898.77 14788.77 58.30 15583.39 3394.91 MinPt-O-SF 17881.18 17879.95 17848.37 14608.30 0.00 0.00 Surface 10879.1 10659.45 10551.16 50.21 12567.05 3414.01 MinPt-CtCt 8733.10 8394.49 8226.23 25.94 17617.45 3374.87 MinPt-CtCt 8171.79 7765.08 7562.60 20.18 19438.28 3350.95 TO SI32-W2(P2)(Def Plan) Pass 1 17888031 17876.891 17847.23 5684.33 251.06 251.06 MinPts 17880.48 17877.19 17847.6 5429.'' 278.94 278.94 MinPt-O-SF 17880.69 17877.41 17847.8.MME111 298.46 298.46 MinPt-OSF 15232.51 14971.73 14841,83 58.63 15583.26 3394.92 MinPt-O-SF 17880.36 17879.14 17847.55 14807.64 0.00 0.00 Surface 11060.19 10839.12 10730.14 50.73 12568.76 3414.01 MinPt-CtCL 9454.99 9047.19 8843.91 23.25 19438.28 3350.95 TD Kigun 1(Def Survey) Pass 0111M 17127.1 17097.0'. 6302.26 162.14 162.14 MinPts 17130.0.MEM 17097.19 5738.50 197.17 197.17 MinPt-0-EOU 015M.1111M0 MEM 4840.41 276.48 276.46 MinPts 17130.0,NEM 17097.29 4823.12 278.41 278.41 MinPt-O-EOU 10687.47 mom 10087.84 OWE 19438.28 3350.95 MinPts Kigun 1 PB1(Def Survey) Pass 7•-'=.85 17127.13=q 6302.26 162.14 162.14 MinPts 17130.00 17127.01 17097.19 5738.50 197.17 197.17 MinPt-O-EOU 1 17130.09 17126.55 17097.21 484041 276.46 276.46 MinPts 17130.09 17126.54 17097.29 4823.12 278.41 278.41 MinPt-O-EOU 1 10687.47 10287.18 10087.841 26.801 19438.28 3350.95 MinPts Tuvaaq ST 1(Def Survey) Pass MIME 17127.1'1E 6302.26 162.14 162.14 MinPts 17130...ABM 17097.19 5738.50 197.17 197.17 MinPt-O-EOU 1111=111131111E .�J 4840.41 276.46 276.46 MinPts 17130..' , 17097.29 4823.12 278.41 278.41 MinPt-0-EOU .3t .®. 28.80 19438.28 3350.95 MinPts SP30-W 1(P2)(Def Plan) Pass 10978.71 10630.81 10457.47 31.66 17865.90 3373.47 MinPt-CtCt 17878.11 17874.82 17845.30 5426.95 279.03 279.03 MinPt-O-SF 17878.32 17875.05 17845.52 MOM 298.61 298.61 MinPt-O-SF 15245.12 14983.90 14853 79 MIME 15584.04 3394.91 MinPt-OSF 17877.99 17876.77 17845.19 14805.70 0.00 0.00 Surface 11509.6. 11196.96 11041.18 36.94 16953.75 3378.57 MinPt-CtCt 11929.84 11821.61 56.12 12572.75 3413.98 MinPt-CtCt 10741.83 10336.31 10134.14 26.56 19438.28 3350.95 TD 12191.37 11972.01 11863.6 1111111EE 12649.30 3413.60 MinPt-OSF 11016. 10671.89 10500.07 32.05 17796.44 3373.86 MinPt-CtCt 1098144 10629.791 10454.541 31.331 17977.69 3372.76 MinPts 0129-S2(P2)(Def Plan) Pass e77 261. 17873.95 17844 45 5400.71 285.06 265.06 MinPt-O-EOU 17877.25 17873 95 17844. 5409.69 267.86 267.86 MinPts , 17877.51 1787423 17844.7 5453. 298.66 298.65 MinPt-O-SF EMT 15230.30 15138.09 83.59 10758.95 3265.18 MinPt-CtCt Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 7 of 24 U Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)1 EOU,lftL Dev.(ft) Fact. MD(ft) I TVD(ft) Alert IMinor I Major 15419. 15228.29 15132.99 80.90 11048.54 3303.24 MinPt-O-EOU 15428.04 15229.96 15131.46 78.31 11339.85 3341.53 MinPt-O-ADP - 17877.18 17875.95 17844.37 14605.03 0.00 0.00 Surface MIME 17874.3: 7844 371 6390.66 198.10 198.10 MinPts 14985.8: 14669.07 14511.16 47.45 17079.49 3378.39 MinPt-CtCt 14986.6 14655.45 14490.34 45.38 17495.27 3375.72 MinPt-CtCt 10492.29 10312.09 30.11 17858.24 3373.51 MinPt-CtCt 10855.2% 10490.47 10308.827 29 88': 17943.12 3373.03 MinPts 1.1=31E Entrigg10381.64® 17080.79 3378.39 MinPts 11497.03 11248.67 11126.31 46.96 12569.71 3414.00 MinPt-OSF 10905.1+EgREEE Ea86i® 16560.61 3380.41 MinPts 11048.64 10776.80 10641.87® 13437.77 3395.77 MinPt-0SF t Einar, 10766.0• 10628.1: 40.05 1406357 3391.14 MinPts 15161.87 14943.27 14834. -mziaz 12627.92 3413.71 MinP1-0SF wpm 14838.27 14690.69 51.27 16550.50 3380.70 MinPt-CtCt 14615.09 14210.51 14008.71 36.21 19438.28 3350.95 TD munzu. 14669.01 '1wo 17081.24 3378.38 MinPts 14660,2* 14309.6 EIM'I..Mailn 17943.49 3373.03 MinPts 14943.45 14834.85 69.80 12590.26 3413.89 MinPt-CtCt 10488.98 10306.94 29.81 17969.76 3372.83 MinPt-CtCt 10854.6: 10488.86 10306.66 29.79 17980.28 3372.73 MinPt-O-EOU 10854.82 10488.8: 10306.6 29.78 17984.49 3372.68 MinPt-O-ADP 10885.94 10516.72 10332.6_)i®l 18128.24 3369.68 MinPt-O-SF • 10849.22 iiimme 0279.0•' $8 18449.56 3360.24 MinPts 10509.5'EMIEEI ENE111 18611.54 3357.45 MinPts 10899.68 10560.57 10391.7 MEM 17162.31 3378.06 MinPt-OSF T:1 MECO MI= 46.96 12497.01 3414.35 MinPts MIM?NEMER M* '10 46.68 12650.77 3413.59 MinPts M:, *1 memo 46.85 1250529 3414.31 MinPts : 1 10776.46 m0, 13369.71 3399.91 MinPts 10906... *M: ,R Nam�.ct 16643.62 3379.02 MinPts 11=1 10776.43 10641.31 40.88 13486.42 3393.26 MinPt-CtCt 11048.7. 1 10640.32 40.76 13578.26 3391.25 MinPt-O-EOU 11048.77 10775.:' 10640.3. 40.75 13580.76 3391.25 MinPt-0-ADP 11066.16 10790.64 10653.6*I l:01M 13703.57 3391.14 MinPt-O-SF 11044.54 10786.81 10628.6 jjjjjjjjjj 14118.18 3390.73 MinPt-O-SF 15118.061 ,MO40 18734.10 3356.67 MinPts SP27-N1(P3)(Def Plan) Pap 11739.33 1133374 11131.45 29.01 19438.28 3350.95 TD 17875.64 17872.35 17842.8 1.=1:11 279.12 279.12 MinPt-0SF 1787586 17872.58 17843.* mums 298.75 298.75 MinP1-0SF 15297.47 15036.41 14906.4 Emma' 15583.06 3394.92 MinP1-0SF 17875.53 17874.30 17842.72 14603.68 0.00 0.00 Surface NEENE 12129.94 11976.74 40.59 16811.88 3378.77 MinPt-CtCt 12795.12 12575.55 12466.991 58.92 12632.48 3413.69 MinPt-0SF I 12064.971 11687.03( 11498.55 32.00 18809.48 3356.19 MinPts S125-N2(P2)(Def Plan) Pap 12640.32 12231.96 12028.27 31.03 19438.28 3350.95 TD 17874.14 17870.84 17841.33 MEM 279.18 279.18 MinPt-O-SF 17874.35 17871.07 17841 54 IMMUZI 298.85 298.85 MinPt-0SF 14902.36 14655.32 14532.29 60.56 15095.56 3400.70 MinP1-OSF 15368.41 15107.80 14977.98'."1, 15584.10 3394.91 MinPt-0SF 17874.02 17872.80 17841.21 1460246 0.00 0.00 Surface NEEEDE 12610.18 12456.14 41.93 16799.73 3378.79 MinPt-CtCt 12702.67 12347.88 12170.9 IjjjjjjjjjgREE 17980.58 3372.72 MinPt-0SF 13449.74 1322759 13117.5 12640.42 3413.65 MinPt-OSF 13382.711 13165.16 13067.38 68.32 11192.73 3322.19 MinP1-CtCt 13367.31 13164. 13063.72 66.47 11447.52 3355.68 MinPt-0-EOU 13367.41 13164.2413063.70 66.45 11451.10 3356.15 MinPt-O-ADP 13445.32 13223.26 13113.24 61.101 12646.49 3413.81 MinPt-OSF 13430.24 13209.51' 13100.09 61.36 12723.20 3413.19 MinPt-O-ADP 13430.1 13209.4 13100.10 61.38 12727.29 3413.17 MinPt-O-EOU I 13430.0 13209.56 13100.24 61.42 12735.49 3413.12 MinPt-CtCt 12838.63 12518.061 12358.26` 40.17' 17091.33 3378.37 MinPts I 12740.22( 12353 92 12161.26` 33.06 18947.46 3355.31 MinPts SP23-N3(P3)(Def Plan) Pap 14405.44 14297.66 67.83 12596.95 3413.86 MinPt-CtCt 17871.23 17867.93 17838.4.=Mal1 279.29 27929 MinPt-0SF 17871.44 17868.16 17838.6 MX= 299.05 299.04 MinPt-0SF 15375.53 15114.60 1498463 mual 15583.99 3394.91 MinPt-0SF 17871.11 17869.88 1783830 14600.08 0.00 0.00 Surface 13625. MUNE lam.*' 42.42 17227.45 3377.60 MinPts 13674.9 minEE 35.31 19029.57 3354.78 MinPts 13691.64 13290.53 13090.47 34.22 19328.11 3351.99 MinPt-0-ADP 13699.84 13293.97 13091.53 33.83 19438.28 3350.95 TD 13463.14 13368.11 71.83 11009.74 3298.14 MinPt-CtCt 13655,-:ME= 13367 48 71.59 11040.48 3302.18 MinPt-O-EOU 13655.84 13462.91'11 71.49 11054.46 3304.02 MinPt-O-ADP 13821.65 13618.55 13517.94 68.68 11522.33 3364.75 MinPt-O-SF 14367.56 14152.27 14045 45® 12099.35 3407.75 MinPt-O-SF 13818.94 13603.78 13496.86 mmcp. 12956.76 3411.59 MinPt-O-SF 13806.61.MEM NEEEMEI 64.67 12991.74 3411.31 MinPts 13806.61 13591.88 13485.15 64.67 12992.64 3411.30 MinPt-CtCt MEM 13248.43 13110.12 45.89 15988.62 3394.09 MinPt-CtCt 13527.25 mismum 13107.92 48.50 16051.73 3394.00 MinPt-O-EOU ' 13528.09 13247. MIME 48.39 16069.36 3393.95 MinPt-O-ADP 14619.5:EaDEEE E.:mzFAE 12627.68 3413.71 MinPts SP24-SEI(P2)(Def Plan) Pass I 14217.74 13905.851 13750.401 45.73 16812.85 3378.77 MInPts 15094.59 14690.14 14488.41 37.41 19438.28 3350.95 7D Drilling Office 2.0.960.0 Nikaitchug\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 8 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 17871.94 17868.63 17839.13 5395.07 267.99 267.99 MinPt-O-EOU I 17871.94 17868.64 17839138 5404.46 270.81 270.81 MinPts 17872.19 17868.91 17839 5446.791 299.00 298.99 MinPt-O-SF 15483. 15305.95 15217.73 87.75 10372.95 3214.45 MinPt-CtCt 15483.76 15305.6 15217.17 87.47 10400.51 3218.07 MinPt-O-EOU 15484.16 15305.7 15217.061 87.31 10416.33 3220.15 MinPt-O-ADP 17871.86 17870.64 17839.05 14600.69 0.00 0.00 Surface MIMED 17869.06 6386.25 198.10 198.10 MinPts 15350.35 14983.91 14801.1:M"'1 18586.34 3357.62 MinPt-O-SF 15305.87 15008 14859 90 51.59 16600.40 3379.46 MinPt-O-EOU 15139.82 1478916 14614.32 43.291 17957.15 3372.94 MinPts I 14263.11 13884.1 13695.08 37.73 18755.27 3356.53 MinPts 14242.04 13912. 13748.14 43.34 17334.21 3376.85 MinPts 14260.46 13903.20 13725.06 40.02 18128.86 3369.66 MinPt-0tCt 14243.3 13921.11 13760.48 44.33 17118.31 3378.29 MinPt-CtCt 14353.83 14143.91 14039.,.mom 11448.72 3355.84 MinPt-O-SF 15031.50 14819.23 14713.91.11MM 11881.79 3392.58 MinPt-O-SF 15048.69 14836.19 14730.7 11111111111'1'16 11898.55 3393.75 MinPt-O-SF 15677.21 15464.12 15358.08 73.91 12976.07 3411.44 MinPt-O-ADP 15677.1,.11111CIRE 15358.08 73.91 12976.74 3411.43 • MinPt-O-EOU 1 15464.13 15358.09 73.92 12978.07 3411.42 MinPt-CtCt MI=ElEiniii MIMES 59.68 13369.97 3399.89 MinPts MIECIMEIMIEWE 43.36 17329.48 3376.88 MinPts 80, l Ngourg. 13746 881 43.38 17324.75 3376.92 MinPts NEE= 13910.31 13746 26 43.40 17320.01 3376.95 MinPt-CtCt 14263.7,MEI= 13706.36 man18551.77 3358.00 MinPts l8 13909.61 m0, 43.42 17315.26 3376.98 MinPts 11118 13908.9.MIME 43.44 17310.51 3377.02 MinPts MI= 13908.2 won 43.46 17305.76 3377.05 MinPts Ez=.1•ErrmozamEt0.741643.48 17301.00 3377.08 MinPts MI= 13906.8 ME= 43.49 17296.24 3377.12 MinPts MEM 13906.1 r MEMO 43.51 17291.47 3377.15 MinPts 43.53 17286.70 3377.18 MinPts NEER. 13904.86 EEKIKE 43.55 17281.92 3377.22 MinPts mmilm. I 13740 91 43,57 17277.14 3377.25 MinPts 14230.9613903.56,®� 43.59 17272.35 3377.28 MinPts Emma 13902.91.HW 43.61 17267,56 3377.32 MinPts INDEOMIMECINga.111= 43.63 17262.77 3377.35 MinPte Mi 13901.6'isEETE 43.65 17257,97 3377.39 MinPts MIENI811 13901 01 MIEZMIE 43.67 17253.17 3377.42 MinPte MEM3900 3!MEM 43.69 17248.36 3377.45 MinPts 7x"411111111 1111111/ 43.72 17243.55 3377.49 MinPts 1r .a 43.74 17238.74 3377.52 MinPts 11111111E.1111111 43.76 17233.92 3377.55 MinPts 1111111 OM 111111111'' 43.78 17229.10 3377.59 MinPts .11= 13897.36 w'7 43.80 17224.27 3377.62 MinPts IllirEIES NM=WOKE, 43.82 17219.44 3377.66 MinPts • 11111111/ :fir. ' 43.84 17214.61 3377.69 MinPts 15291.22 14925.07 14742.49®1 18525.10 3358.42 MinPt-O-SF Sx34-N Sand(P2)(Def Plan) Pass L17882.01 17879.., 17849.201 6008.65 251.06 251.06 MinPts ,, 17882.0. 17879.0 17849.21 5974.53 259.41 259.41 MinPt-O-EOU 14090.08 13997.88 77.40 10746.48 3263.54 MinPt-CtCt 14276.0 14089.9 13997,64 77.30 10759.38 3265.24 MinPt-0-EOU 14276.24 14090... 13997.6. 77.25 10765.90 3266.09 MinPt-O-ADP 14518.47 14318.58 14219. P EINEM 11451.14 3356.16 MinPt-O-SF 15401.02 15186.85 15080.2 fSE 12100.93 3407.86 MinPt-OSF 17882.01 17880.79 17849.20 14608.98 0.00 000 Surface 1456579 14159.73 13957.19 35.96 19438.28 3350.95 TD 14459.99 14246.29 14139.94 13013.61 3411.13 MinPt-O-SF • �-. .' C MUER 67.98 13022.96 3411.05 MinPts 1111 1394071 13805.88 52.70 15806.86 3394.38 MinPt-CtCt 1421207 13940.02 13804.49 52.43 15847.03 3394.32 MinPt-O-EOU ' 14213.21 13940.25 13804.26 5226 15873.25 3394.28 MinPt-O-ADP 15642.61.1=1:'��®1 12622.70 3413.73 MinPte SP22-FN1(P2)(Def Plan) Pass 15103.63 14698.53 14496.47 37.37 19438.28 3350.95 TD 17870.4 17867.1 17837.62 5391.37 26802 268.02 MInPt-0-EOU 17870.4 17867.1 17837.6 5401.30 270.85 270.85 MinPts 17870.68 17867.40 17837.8 5444.71 299.10 299.09 MinPt-O-SF �: 7 15306.18 15218.01 87.79 10385.74 3213.50 MinPt-CtCt 15483.9. 15305.9. 1521745 87.51 10393.51 3217.15 MinPt-0-EOU • 1548430 15306...NEM 87.36 10407.85 3219.03 MinPt-O-ADP 17870.35 17869.12 17837.54) 14599.45 0.00 0.00 Surface MIME 17867.5 17837.5. 6384.98 198.10 198.10 MinPts 15353.02 14985.85 14802.7 419211 18583.37 3357.65 MinPt-O-SF I 15308.571 15011.05 14862.78 5162 16576.27 3379.97 MinPts 15309.70 15011.28 14862.56 51.47 16605.52 3379.37 MinPt-O-ADP I 15241.55 14924.24 14766 0748 181 17081.48 3378.38 MinPte 15147.69 14798.73 14624.74 43.53 17893.90 3373.31 MinPt-CtCt 15148.62 14797.351 14622 211 43.241 17957.82 3372.94 MinPte 15914.85 15695.49 15586 31® 12622.97 3413.73 MinPt-O-SF 15893.92 1567491 15565 91 72.901 12842.50 3413.63 MinP4-0SF 15681.58 15468.411 15362.31 73.90 12982.00 3411.39 MinPt-O-ADP 15681.56 15468.4 15362.32 73.91 12983.14 3411.38 MinPt-O-EOU 15681.54 15468.42 15362.35 73.92 12985.41 3411.36 MinPt-CtCt 15291.32 14912.71 14724 O440571 18849.12 3355.94 MinPts 5119-FN2(P2)(Def Plan) Pass 15258.83 14853.69 14651 61 37.75 1943828 3350.95 70 17868.01 17864.73 1783524 5385.37 268.08 268.08 MinPt-O-EOU 17868.0 17864 73 1783523 5396.21 270.91 270.91 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 9 of 24 Offset Trajectory Separation Allow . Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor ] Major 17868.29 17865.01 17835.48 5441.57 299.25 299.24 MinPt-O-SF MEM 15325.85 15238.42 88.65 10292.31 320385 MinPt-CtCt 15501.9,mama 15238.00 88.44 10312.27 3206.47 MinPt-O-EOU 15502.26 15325.7.1113=, 88.33 10322.55 3207.82 MinPt-O-ADP 17867.96 17866.74 17835.15 14597.50 0.00 0.00 Surface 17867.96 17865.161.1M14 6383.05 198.10 198.10 MinPte 15380.7. 15082.07 14933.24 51.67 16610.94 3379.29 MinPt-O-EOU 15313.38 14961.76 14786.45 43.6 17986.84 3372.65 MinPt-O-SF 15865.90 15649.74 15542.1 73.7 12821.05 3412.58 MinPt-0SF 15718.46 15503.701 15397.8 74.21 13010.54 3411.16 MinPt-O-ADP 15716.45 15503.6 15397.81 74.21 13011.04 3411.15 MinPt-O-EOU 15716.45 15503.70 15397.81 74.21 13011.53 3411.15 MinPt-CtCt 15376.95 14997.58 14808.391 40.641 18866.89 3355.82 MinPte S117SE2(P2)(Def Plan) - Pass MEEEEE 14973.13 14808.42 46.45 17406.03 3376.35 MinPt-CtCt 15332.17 14927.27 14725.30 37.96 19438.28 3350.95 TD MIMEO=ECO 18366.70 3362.68 MinPte 17865.9.Ma= 17833.12 5381.71 268.13 268.13 MinPt-O-EOU [117865.9. 17862.611 5392.88 270.98 270.98 MinPte 17866.17 17862.89 17833.36 MEM] 299.40 299.40 MinP1-0SF FIIME.mammimr=® 17953.24 3372.97 MinPts NEMEC 15347.55 15260 77 89 43 10228.96 3195.52 MinPt-CtCt 15522.3.MEMZE 15260.47 89.28 10243.61 3197.45 MinPt-0-EOU 15522.52 15347... 15260.43 89.19 10251.13 3198.44 MinPt-O-ADP 15300. 14989.40 14834.39 49.35 16846.50 3378.72 MinPt-CtCt 15301.1 14989.3Y 14833.97 49.23 16868.97 3378.69 MinPt-O-EOU 15308.3 14970.02 1480132 45.37 17620.01 3374.85 MinPte 15307.61 14969.45 14800.87 45.40 17615.16 3374.88 MinPte 15330.51 14979.31 14804.20 43.771 17953.53 3372.97 MinP1-0SF won 14981.72 1482177 47.83 17136.57 3378.21 MinPt-CtCt 15308.2' 14969 9, 14801 261 45.37 1761941 3374.86 MinPte 17865.84 17864.61 17833.03 14595.77 0.00 0.00 Surface 17865.8 17863.0,.®. 6381.22 198.10 198.10 MinPte IIS 14979.0 14803 94 IMO 1795383 3372.97 MinPte MOW 14959.89 14783.73 43.46 18034.33 3371.92 MinPt-CtCt 15308.1, 14969.8 14801.201 45.38 17618.81 337486 MinPte IMEEn IIIEEME NampFE 43.99 17905.10 3373.25 MinPte 15492.58 15125.86 14943...IMEIM 18579.89 3357.68 MinPt-O-SF 15295.76 14991.48 14839.83 50.43 16648.09 3379.01 MinPt-CtCt 15330.01 14978.7595114803.6 43.77, 17954.14 3372.96 MinPte 15313.19 1495914783.69 43.46 18035.22 3371.81 MinPts 15295.76 14991.43 14839.75 50.42 16649.62 3379.00 MinPt-CtCt 15307.52 14989.39 14800.81 45.40 17614.54 3374.89 MinPte 15329.76 14978 14803.4 43.771 17954.45 3372.98 MinPts 15313.19 14959.83 14783.65 43.45 18036.13 3371.89 MinPt-CtCt 15434.02 15116.92 14958. 48.8 17096.86 3378.35 MinPt-O-SF 15307.99 14969.72 14801.0 45.38 17617.60 3374.87 MinPte 15307.43 14969.33 14800.7 45.401 17613.92 3374.89 MinPte 15329.51 14978.28 14803.1 43.7 17954.76 3372.96 MinPte 15220.31 14983.45 14865.51 64.52 13703.70 3391.14 MinPt-CtCt 15307.89 14969.6 14801.03 45.39 17617.00 3374.87 MinPte 1 15329.20 14975.9 14805.79 44.01 17901.43 3373.27 MinPte 15376.00 15024.96 14849.93 43.921e 17963.56 3372.89 MinPt-O-SF 1 15227.1 14985.71 14865.37 63.23 14126.51 3390.60 MinPte 15307. 14969.3 14800.77 45.41 17612.47 3374.90 MinPte 15327.73 14978.78 14804.80 44.05 17893.52 3373.31 MinPt-OSF 15581.78 15376.93 15275.0 78.44 11449.16 3355.89 MinPt-O-SF 15998.73 15782.54 15674.94, 74.34 12773.19 3412.89 MinPt-O-SF 15908.32 15692.90 15585.68 74.18 12854.16 3412.35 MinPt-O-SF 15749.28 15536.74 15431.04 74.46 13024.88 3411.04 MinPte I 15749.27 15536.80 15431.06 74.48 13025.85 3411.03 MinPt-CtCt 15307.25 14969.351 14800.8 45.43 17608.75 3374.93 MinPts 15327.50 14978.60 14804.6 44.051 17892.13 3373.32 MinPt-O-SF I15258.69 15027.93 14913.08 66.42 13369.70 3399.91 MinPt-CtCt 15307.1 14969.401 14801.01 45.45 17605.02 3374.96 MinPte • 15327.26 14978.42 14804.49 44.061 17890.72 3373.33 MinPt-O-SF 1_15318.291 14959.691 14783.38 43.42 18045.35 3371.71 MinPte 15327.02 14978.24 14804.33 44.071 17889.29 3373.34 MinPt-OSF 1 15313.311 14959.68 14783.36 43.42 18048.29 3371.69 MinPte 15326.79 14978.06 14804.19 44.071 17887.83 3373.34 MinPl-OSF 1 15313.331 14959.68 14783.35 43.42 18047.24 3371.67 MinPte 15328.56 14977.88 14804.04 44.081 17886.36 3373.35 MinPt-OSF t15313.361 14959.68 14783.34 43.42 18048.19 3371.65 MinPte 15326.32 14977.71 14803.90 44.091 17884.86 3373.36 MinPt-OSF 1 15313.34 14959.64 14783.33 43.41 18049.14 3371.64 MinPte 15326.09 14977.54 14803.76 44.091 17883.34 3373.37 MinPt-OSF 1 15313.44 14959.64 14783.32 43.41 18050.10 3371.62 MinPts 15325.87 14977.37 14803.62 44.101 17881.81 3373.38 MinPt-O-SF 1 15313.451 14959.701 14783.32 43 41 18051.06 3371.60 MinPts 15325.64 14977.21 14803.48 44.111 17880.25 3373.39 MinPt-O-SF 15313.49 14959.71 14783.32 43.40 18052.03 3371.58 MinPts 15313.53 14959.7 14783.32 43.40 18053.00 3371.56 MinPts 1531386 14959.7 14783.32 43.40 18053.97 3371.54 MinPts 15313.61 14959.75 14783.32 4.139 18054.95 3371.52 MinPts 15313.65 14959.77 14783.33 43.39 18055.93 3371.50 MinPts 15313.70 14959.79 14783.331 43.39 18058.91 3371.47 MinPts 15313.75 14959.8 14783.34 43.39 1805789 3371.45 MinPte 15324.08 14976.11 1480261 44.16 17868.77 3373.45 MinPt-O-ADP 1 15313.801 14959. 14783.35 43.38 1805888 3371.43 MinPts 15323.87 14975.96 14802.50 44.17 17887.04 3373.46 MinPt-O-ADP 1 15313.851 14959.8 14783.37 43.38 18059.88 3371.41 MinPts 15323.65 14975.81 14802.39 44.18 17865.30 3373.47 MinPt-O-ADP • Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 10 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major L15313.91 14959.90 14783.38 43.38 18060.87 3371.39 MinPts 15323.63 14975.80 14802.37 44.18 17865.12 3373.47 MinPt-O-ADP L115313.961 14959.93 14783 40 43.37 18061.88 3371.37 MinPts 15323.44 14975.671 14802.28 44.18 17863.54 3373.48 MinPt-O-ADP 1_15314.021 14959 96 14783.42 43.37 18062.88 3371.35 MinPts 15323.23 14975.53 14802.17 44.19 17861.75 3373.49 MinPt-O-ADP I 15314.081 14960.00 14783.44 43.37 18063.89 3371.32 MinPts 15323.02 14975.39 14802.06 44.20 17859.95 3373.50 MinPt-O-ADP 1 15314.151 14960.03 14783.47 43.36 18064.90 3371.30 MinPts 15322.81 14975.25 14801.96 44.21 17858.12 3373.51 MinPt-O-ADP C-15314.221 14960.07 1478350 43.36 18065.91 3371.28 MinPts 15322.60 14975.11 14801.86 4422 17856.28 3373.52 MinPt-O-ADP 1 15314.281 14960.12 14783.53 43.36 18066.93 3371.26 MinPts 15322.39 1497498 14801.76 44.23 17854.41 3373.53 MinPt-O-ADP I 15314.34 14960.16 14783.56 43.35 18067.95 3371.23 MinPts 15322.19 14974.85 14801 67. 44.24 17852.53 3373.54 MinPt-O-ADP I 15314.431 14960.21 14783 59 43.35 18068.97 3371.21 MinPts 15321.98 14974.72 14801.58 44.24 17850.62 3373.55 MinPt-O-ADP I 15314.501 14960.26 14783.63 43.35 18070.00 3371.18 MinPts 15321.78 14974.59 14801.49 44.25 17848.70 3373.56 MinPt-O-ADP 1 15314.581 14960.31 14783.66 43.35 18071.03 3371.16 MinPts 15321.58 14974.46 14801.40 44.28 17848.75 3373.58 MinPI-O-ADP I 15314.66 14960.36 14783.70 43.34 18072.06 3371.14 MinPts 15321.38 14974.34 14801.32 44.27 17844.78 3373.59 MinPt-0-ADP I 15314.751 14960.42 14783.74 43.34 18073.10 3371.12 MinPts 15321.18 1497422 14801.23 44.28 17842.80 3373.60 MinPt-O-ADP 1 15314.831 14960.47 14783.79 43.34 18074.14 3371.09 MinPts 15320.98 14974.10 14801.15 44.29 17840.79 3373.61 MinPt-O-ADP I. 15314.921 14960.53 14783.841 43.33 18075.18 3371.07 MinPts 15320.78 14973.98 14801 08 44.30 17838.77 3373.62 MinPt-O-ADP ! 1 15315.011 14960.60 14783.88 43.33 18076.23 3371.04 MinPts 15320.59 14973.87 14801.00 44.31 17836.72 3373.63 MinPt-O-ADP I 15315.18 14960.66 14783.93 43.33 18077.28 3371.02 MinPts 15320.39 14973.76 14800.93 44.32 17834.65 3373.64 MinPt-O-ADP L 15315.191 14960.73 14783.99 43.32 18078.33 3371.00 MinPts 15320.20 14973.65 14800.86 44.33 17832.57 3373.66 MinPt-O-ADP 15315.291 14960.79 14784.04 43.32 18079.38 3370.97 MinPts 15320.01 14973.54 14800.80 44.34 17830.46 3373.67 MinPt-O-ADP I 15315.391 14960.87 14784.10 43.32 18080.44 3370.95 MinPts 15319.82 14973.43 14800.73 44.35 17828.34 3373.68 MinPt-O-ADP 1 15315.491 14960.94 14784.16 43.31 18081.50 3370.92 MinPts 15319.63 14973.33 14800.67 4436 17826.19 3373.69 MinPt-O-ADP 1 15315.591 14961.01 14784.22 43.31 18082.57 3370.89 MinPts 15319.44 14973.23 14800.61 44.37 17824.03 3373.70 MinPt-O-ADP I 15315.691 14961.09 1478428 43.31 18083.64 3370.87 MinPts 15319.28 14973.13 14800.55 44.38 17821.84 3373.72 MinPt-0•ADP I 15315.801 14961.17 1478435 43.31 18084.71 3370.84 MinPts 15319.07 14973.03 14800.50 44.39 17819.64 3373.73 MinPt-O-ADP 1L15315.911 14961.25 14784.41 43.30 18085.78 3370.82 MinPts 15318.89 14972.93 14800.44 44.40 17817.42 3373.74 MinPt-0-ADP [5316.021 14961.34 14784.48 43.30 18086.86 3370.79 MinPts 15318.71 14972.84 14800.3; 44.41 17815.17 3373.75 MinPt-O-ADP 1_15316.141 14961.421 14784.56 43.30 18087.93 3370.76 MinPts 15318.53 14972.74 14800.34 44.42 17812.91 3373.77 MinPt-O-ADP 1 15316.25 14961.51 14784.63 43.29 18089.02 3370.74 MinPts 15318.35 14972.65 14800.30 44.44. 17810.63 3373.78 MinPts 1 15316.37 14961.60 14784.71 43.29 18090.10 3370.71 MinPts 15318.17 14972.56 14800.25 44.45 17808.33 3373.79 MinPts I 15316.49 14961.69 14784.79 43.29 18091.19 3370.68 MinPts 15317.99 14972.48 14800.21 44.46 17806.01 3373.81 MinPts I 15316.62 14961.79 14784.87 43.28 18092.28 3370.66 MinPts 1531781 14972.39 14800.17 44.47 17803.67 3373.82 MinPts I 15316.65 14961.82 14784.89 43.28 18092.60 3370.65 MinPts 15317.64 14972.31 14800.14 44.48 17801.31 3373.83 MinPts I 15316.74 14961.89 14784 95, 43.28 18093.37 3370.63 MinPts 15317.47 14972.23 14800.10 44.49 17798.93 3373.84 MinPts 1 15316.87 14961.99 14785.04 43.28 18094.47 3370.60 MinPts 15459.03 15092.53 14909.77 42.291 18520.25 335851 MinPt-O-SF SD37-DSP1(P4b)(Def Plan) . Pass 17882.';.11131ff 6242.32 250.80 250.80 MinPts 17885. 'MEM 17852.55 6208.30 259.12 259.12 MinPt-0-EOU tIMIE 15024.64 14933.41 83.35 10634.42 3248.81 MinPt-CtCt 15208.1 c MEW 14933.33 83.31 10639.02 3249.42 MinPt-O-EOU 15208.22 15024.61 83.29 10641.65 3249.76 MinPt-O-ADP 15269.95 15084.03 14991.5 NEM 10816.46 3272.74 MinPt-O-SF 15407.31 15193.60 15087.2'1111111136 13042.96 3410.88 MinPt-O-SF EI"I MILM112 Mr, 72.43 13043.16 3410.88 MinPts 6l1*1I14777.34 57.00 15706.04 3394.54 MinPts 15177.71 14910.47 11111M1 57.00 15706.04 3394.54 MinPt-O-ADP 15178.05 14910.79 14777.65®" 15706.19 3394.54 MinPt-O-SF 15552.99 15290.33 15159.49 59.43 15711.38 3394.53 TD 17885.34 17884.23 17852.53 16045.66 0.00 0.00 Surfsce 1 17885.341 17882.491 17852.531 6275.911 248.55 248.55 MinPts SD37-DSP1 current(Non-Def Survey) Pass 17886.1 17877.96 17853.3 ' 250.81 250.81 NImPts 17880.1,1111'x' 3063.37 281.29 281.29 MinPts 15226.82 15038.31 14944.6'®- 8 10519.82 3233.75 MinPt-O-SF 15207.06 15018.73 14925.1' r 10569.45 3240.27 MinPt-O-SF 15198.43 15012.0': 4919 41, 82.03 10629.44 3248.16 MinPt-O-ADP 15198 3,i.1=0 14919.42 82.06 10632.63 3248.58 MinPt-O-EOU I 15198.28 1501207 14919.53 82.11 10637.73 3249.25 MinPt-CICt Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 11 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor ANA Status Ct-Ct,jft)1 EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) ANA I Minor I Major 15439.30 15221.86 15113.64 71.33 13040.24 3410.91 MinPt-OSF 15396.70 15182.321 1507562 72.14 13042.39 3410.89 MInP1-0-ADP 15396.6 15182.31 1507563 72.15 13042.41 3410.89 MInPt-0{OU 1 15396.6 15182.34 15075.67 72.17 13042.45 3410.89 MInPt-CtCt 15253.98 14985.66 14851.99 57.06 15713.72 3394.53 TD 1 15167.11 14899.98 14766.91 56.99 15707.78 3394.54 MinPt-CtCt 15167.11 14899.98 14766.91 56.98 15707.79 3394.54 MinPt-O-EOU 15167.11 14899.98 14766.91 56.98 15707.81 3394.54 MinPt-0-ADP 15180.92 1491290 14779.38 56.85 15710.82 3394.53 MinPt-O-SF 15204.39 14935.87 14802.10 56.83 1571247 3394.53 MinPt-O-SF 15190.30 1492271 14789.41 56.97 15708.95 339454 MinPt-O-SF 5120-N4(P4)(Def Plan) Pass 17868.90 17865.60 17836..•81 279.38 279.38 MinPt-0SF 17869.12 17885.83 17836.31 MIME 299.20 299.19 MinPt-0SF 15435.04 15174.37 150445 MEM 1, 15583.92 3394.91 MinPt-0SF 17868.79 17867.56 17835.98 14598.18 0.00 0.00 Surface 15475.06 15106.74 14923.07=CM 18569.24 3357.78 MinPt-O-SF II= 15034.89 14835.31 38.67 19329.52 3351.97 MInPt-CtCt 15436.50 15031.83 14829.69 38.22 19438.28 3350.95 TD 15451.02 15133.7. "�'1 48.85 17072.99 3378.40 MinPt-O-ADP 1 15455.68 15102.98 14927.12 43.94 18064.86 3371.31 MinPt-CtCt 1545571/ 15102.94 14927.05 43.93 18068.39 3371.22 MinPt-O-EOU 15455.73 15102.95 14927.01 43.93 18069.63 3371.20 MinPt-0-ADP 1 14897.941 14725.41 14639.74 86.94 10070.91 3174.75 MinPts 14897.96 14725.41 14639.73 86.93 10071.63 3174.84 MinPt-O-ADP 15845.91 15644.00 15543.53 78.86 11523.59 3364.89 MinPt-0SF 16397.81 16185.06 16079.1 77.43 12101.63 3407.91 MinPt-OSF 15237.16 1502407 1491802 7183 13135.52 3409.57 MinPt-OSF 15195.98 1498294 14876.9 71:66 13139.35 3409.49 _ MinPl-0SF I15196.88 14982.79 14876.77 71.66 13139.39 3409.49 MinPts 15050.4 14799.41 14674.37 60.18 15214.74 3399.46 MinPts 15050.48 14799.41 146741 60.18 1521487 3399.46 MinPt-O-ADP 1_15444.801 15115.37 14951.1 47.04 17428.71 3376.19 MinPts SP16-FN3(P2)(Def Plan) Pass 15473.04 15067.87 14865.78 38.28 19438.28 3350.95 TD 178651 17861.86 17832.38 5376.84 268.15 268.15 MinPI-0-EOU 1 17865.18 17861.87 17832.3 5389.06 271.00 271.00 MinPts 17865.43 17862.15 178325 5437.4 299.45 299.45 MinPt-OSF 1 15524.61 15350.33 15263.72 89.62 10211.58 3193.24 MinPt-CtCt 15524.7 15350.2 15263.49 89.50 10222.32 3194.65 MinPt-O-EOU 15524.89 15350 2 15263.45 89.43 10228.92 3195.52 MinPt-O-ADP 16423.30 16206.87 16099.15 76.2 12102.58 3407.98 MinPt-O-SF 1 15646.771 15387.091 15257.74 60.4 15600.75 3394.75 MinPts 1786510 17863.88 1783229 1459517 0.00 0.00 Surface 17865.10 17862.3 178322 6380.60 198.10 198.10 MinPts 15536.68 15169.4 14986.2 42.4210 18575.19 3357.72MinPts 15493.95 15194.02 1504455 51.83 16851.10 3379.00 MinPt-CtCt 15501.41 15189.91 15034.72 49.93 16938.09 3378.59 MinPt-O-EOU 1 15499.73 15181.98 15023.60 48.93 17151.91 3378.12 MinPt-CtCt 15499.73 15181.94 15023.61 48.93 17152.81 3378.12 MinPts 1 15499.56 15178.23 15018.06 48.38 17248.20 3377.45 MinPt-CtCt 15505.19 15168.51 15000.65 46.18 17811.65 3374.91 MinPt-O-EOU 1550532 15168.5 15000.611 46.17 17613.93 3374.89 MinPt-0-ADP 1 15511.031 15158.98 1498344 44.18 18038.28 3371.85 MinPt-CtCt 1551108 15158.9'7 14983.43 44.18 18040.46 3371.81 MinPI-0-EOU 15511.05 15158.9 14983.43 44.18 18041.56 3371.79 MinPt-O-ADP 15513.91 15161.65 14986.01 44.16' 18085.95 3370.81 MinPt-O-SF 15847.49 15633.38 15526.82 74.351' 12936.94 3411.75 MinPt-0SF 15757.83 15545.431 15439.72 74.53 1303531 3410.95 MinPts 15757.82 15545.43 15439.73 7453 13036.09 3410.94 MinPt-CtCt 15493.20 15201.22 15055.72 53.24 16430.64 3384.22 MinPt-CtCt 15513.98 15133.511 14943.771 40.881 18890.60 3355.67 MinPts • 5120-N4PB1(P1)(Def Plan) Peas 1 17868.461 17865.311 17835.65 566249 251.08 251.08 MinPts 17868.90 17865.60 17836.09 5417.14 279.38 279.38 MinPt-O-SF 17869.12 17865.83 17836.31 5442.63 299.20 299.19 MinP1-0SF 15171.44 14958.41 14852.38 71.54 13142.30 3409.42 MinPt-O-SF 15169.67 14956.71 14850.72 71.56 13143.30 3409.40 MinPts I15169.67 14956.71 14850.72 71.56 13143.33 340940 MinPt-CtCt 15024.86 14774.09 14649.20 60.15 1520274 3399.60 MinPt-CtCt 15024.86 14774,091 1464920 60.15 1520286 3399.60 MinPt-O-EOU 15024.87 147740,811 14649.20 60.15 15202.92 3399.60 MinPt-O-ADP 15028.52 14777.58 14652.61 60.12 15206.81 3399.55 MinP1-0SF 15435.04 15174.37 1504453 59.43 15583.92 3394.91 MinPt-0SF 15666.75 15407.34 15278.13 60.62 15609.13 3394.70 TD 17868.79 17867.56 17835.98 14598.18 0.00 0.00 Surface 1 14882.65 14708.65 14622.23 86.10 10155.97 3185.93 MinPt-CtCt 14882.69 14708.62 14622.17 86.07 10159.91 3186.45 . MinPt-O-EOU 14882.73 14708.63 14622.16 86.06 10161.88 3186.71 MinPt-O-ADP 14919.86 14744.07 14656.70 85.371 10295.31 3204.24 MinPt-O-SF 5113-FN4(P2)(Def Plan) Pao 15645.23 15240.07 15037.97 38.71 19438.28 3350.95 TD 17862 9 17859.66 1783018 5371.08 268.21 268.21 MinPt-O-EOU 1 17862.9 17859.66 178301 5384.15 271.06 271.06 MinPts 17863.23 17859.94 17830.4 5434.4 299.60 299.60 MinPt-0SF 1 15539.21 15365.87 15279.74 9020 10165.07 3187.13 MinPt-CtCt 15539.33 15365,781 15279.54 90.08 10174.91 3188.42 MinPt-O-EOU 15539.45 1536581/ 15279.52 90.04 10178.94 3188.95 MinPt-O-ADP 16750.95 16534.51 16426.78 77.741 12100.86 3407.86 MinPt-0SF 16796.27 16579.11 16471.02 77.6 12301.11 3415.34 MinPt-OSF Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 12 of 24 • • Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 17862.90 17861 67 17830.09 14593.37 0.00 0.00 Surface 17860.0' 6378.74 198.10 198.10 MinPts 15820.78 REEIEE wom 42.64 18572.13 3357.75 MinPts 15621.28 15253.97 15070.81�":.;, 18577.45 3357.70 MinPt-O-SF fir'�--4 52.09 16651.33 3379.00 MinPts 49.19 17164.35 3378.04 MinPts MIME 15341.00 15168.21 45.39 17836.57 3373.63 MinPt-CtCt E" 15263.15 15087.41 44.42 18131.68 3389.58 MinPt-CtCt 15617.7:MEM 15085.87 44.12 18188.07 3367.92 MinPt-O-EOU 15625.28 15264.40 15084.46 43.41 18323.09 3363.96 MinPt-O-ADP 15809.89 15596.97 15490.9• 13010.24 3411.16 MinPt-O-SF 15782.3 MM.mamas74.71 13047,07 3410.85 MinPts E�, 15570.15 15464.53 74.71 13047,40 3410.84 MinPt-CICt I 15273.63 15138.19 57.39 15892.36 3394.25 MinPt-CtCt 15549.2'MEM 15133.28 56.20 16048.53 3394.00 MinPt-O-EOU 15550.91 MM. 15130.26 55.58 16140.08 3392.73 MinPt-O-EOU 15558.38 15271.7'1.11E112 54.47 16291.40 3388.30 MinPt-O-ADP ORM 18905.30 3355.58 MinPts SP12-SE3(P2)(Def Piet)) Pass 17861.0611 17857.73 1782825 5365.64 268.26 268.26 MinPt-O-EOU 17861.0511 17857.73' 17828 25 5379.52 271.12 271.12 MinPts 17861.30 17858.01 17828.491 5431 491 299.75 299.74 MinP1-0SF 1 15556.5 15384.26 15298 64 90.85 10114.28 3180.45 MinPt-CtCt 15556.6 15384.1 15298.50 90.77 10121.58 3181.41 MinPt-O-EOU 15556.69 15384.2 15298.4 90.74 10123.44 3181.65 MinPt-O-ADP 16175.91 15974.59 15874.421 80.741 11480.81 3359.92 MinPt-O-SF 17860.97 17859.74 17828.16 14591.79 0.00 0.00 Surface 17880.97 17858.1 :�: 9 6377.03 198.10 198.10 MinPts 15724.35 15357.20 15174.12 42.94 18598.15 3357.54 MinPt-CtCt 15722.87 15332.96 15138.44 40.41 19106.04 3354.08 MinPt-CtCt 15724.04 15331.7 15136.14 40.18 19156.17 3353.61 MinPt-O-EOU 15725.12 15331.98 15135.91 40.10 19175.44 3353.42 - MinPt-O-ADP 15795.92 15394.12 15193.71 39.411 19385.46 3351.64 MinPt-0-SF 15826.44 15424.26 15223.66 39.45 19372.89 3351.57 TD 15726.98 15395.31r 15229.977.56 17499.46 3375.69 MinPt-O-ADP 15735.44 15383.52 15208.05J) 44.841 18075.74 3371.06 MinPt-O-SF 15733.01 15368.71 15187.06 43.30 18407.16 3361.49 MinPt-CtCt 15733. 15367.44 15184 96 43.10 18445.47 3360.36 MinPts 15825.09 15482.74 15312 06 46.31 17744.19 3374.15 MinPt-O-SF 16088.32 15720.68 155373 43.8 18455.44 3360.07 MinPt-O-SF imin.. 15904.32 15751.29 52.97 16766.61 3378.84 MinPt-CtCt 15831.37 15618.82 15513.0. 13031.88 3410.98 MinPt-0SF 15809.9 MEMO 74.92 13057.76 3410.75 MinPts 15809.9. 15597.95 15492.45 74.93 13058.06 3410.75 MinPt-CtCt MIME. 16360.37 16249.95 75.08 13118.09 3409.93 MinPt-C1Ct1 16582.3 16360. 16249.71 75.00 13128.85 3409.72 MinPt-O-EOU 16582,46 16360.28 1624969'1 74.96 13133.34 3409.62 MinPt-O-ADP MEM 15322.91 1519019 58.72 15744.73 3394.48 MinPt-CtCt 1559024® 15188.55 58.36 15790.98 3394.41 MinPt-O-EOU 15591,57 15322.401 1518830 58.13 15820.05 3394.36 MinPt-O-ADP 1561598 15339.40. 15200.10 56.06 16108.29 3393.50 MinPt-O-ADP 15685.51 15388.51 15240 51 Imo90 16560.61 3380.41 MinPt-O-SF MIM?.13M.won imEig 18736.09 3356.66 MinPts 16430.91 1111Eng 16063:64 6728 14534.09 338298 MinPt-O-EOU 16430.98 16185.7 16063.6' 67.27 14537.41 3382.92 MinPt-O-ADP 16443.56 16190.4. 16064. ' 65.21 14940.09 3396.65 MinP1-0-ADP IIIMILE MIME:EMCEE MLUEE 18880.82 3355.73 MinPts SP10-FN5(P2)(Del Plan) Paas 1 15851.351 15468.54 15277 64 41.521 18940.06 3355.35 MinPts 15946.06 15540.86 15338.75 39.45 19438.28 3350.95 TD 17859.51 17856.2• 17826.76 5360.23 268.30 268.30 MinPt-0-EOU ' 1 17859.5 17856.2. 17826.76 5375.06 271.17 271.17 MinPts 17859.81 17856.52 17827.00=En 299.85 299.85 MinPt-O-SF ' EME 15391.31 15305.91 91.12 10092.37 3177.57 MinPt-CtCt 15563.2 NEEIEg 15305.77 91.04 10098.91 3178.43 MinPt-O-EOU 15563.29 15391.25 91.02 10100.57 3178.65 MinP1-0-ADP 16305.32 16104.38 16004.40'M5. 11450.96 3356.13 MinPt-O-SF 17281.61 17065.17 16957.••MI. 12097.72 3407.64 MinPt-O-SF 17344.37 17127.15 17019.0 MILE.1 12297.72 3415.35 MinPt-O-SF • :fir 1 IIIMME 15562.65 75.65 13077.13 3410.56 MinPts 17859.48 17858.26 17826.67 14590.57 0.00 0.00 Surface MY: 17856.6,Iy •1 6375.79 198.10 198.10 MinPts 15802.8 MEM EMU 43.11 18598.21 3357.54 MinPts 1ZECIE'llESZECIMICEIE.319335352.76 16643.09 ' 3379.02 MinPts �"1 ___wag 49.82 17162.34 3378.06 MinPls 15841.40 15628.95 15523.21) 13043.32 3410.88 MinPt-O-SF 15821,56 15609.6.®" I 75.00 13063.47 3410.70 MinPt-O-ADP L15®.1582155 15609.6. 15504.15 75.00 13063.72 3410.70 MinPt-O-EOU 15609.62 15504.16 75.00 13063.97 3410.70 MinPt-CtCt 1534530 15213.87 59.38 15669.94 3394.60 MinPt-CtCt 15609.58 15344.88 15213.02 59.19 15693.29 3394.56 MinPt-O-EOU 15610.28 15345.01 NEM 59.06 15708.95 3394.54 MinPt-O-ADP 5108-FN6(P2)(Def Plan) Pass I15991.45) 15607 73) 15416.34 41.781 18958.09 3355.24 MinPts 16154.44 15749.18 15547.04 39.96 19438.28 3350.95 TD • 17858.35 17855.06 17825. 'MEMO 299.95 299.95 MinPt-O-SF 15384.94 15299.69 91.24 10074.82 3175.26 MinPt-CtCt 15556. • 15384.88_ 15299.58 91.19 10079.21 3175.84 MinPt-O-EOU 15556.57 15384.8:'® 91.17 10080.70 3176.04 MinPt-O-ADP 16509.68 16308.84 16208.91 82.60 11450.80 3356.11 MinPt-OSF • 17802.64 17588.39 17478.76 Ma. 12097.46 3407.62 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 13 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft), EOU(ft`Dev.1ft1.., Fact. MD(ft) I TVD(ft) Alert I Minor I Major 15866.86 15655.79 15550.75 75.52 13079.61 3410.53 MinPts 17858.01 17856.79 17825.20 14589.38 0.00 0.00 Surface 15890.96 15523.18 15339.78 43.32 18597.34 3357.54 MinPts 15873.08 15572.98 15423.42 53.06 16645.45 3379.01 MinPts 15903.89 15585.78 15427.21 50.15 17162.68 3378.05 MinPts 15836.72 15624.36 15518.68 74 921 13055.23 3410.78 MinPt-OSF 15819.94 15608.01 15502.56 75.00 13070.02 3410.64 MinPt-O-ADP 15819.93 156080 15502.56 75.00 1307022 3410.63 ' MinPts 15615.10 15353.19 15222.73 59.84 15613.12 3394.69 MinPt-CtCt 15615.15 15353.12 1522260 59.81 15615.15 339468 MinP1-0-EOU 15615.40 15353.12 15222.47 59.76 15621.22 339467 MinPt-O-EOU 15615.74 15353.19 15222411 59.70 15628.39 3394.66 MinPt-O-ADP S107-SE4(P2)(Def Plan) Paas 1 16697.901 16346.54 16171.351 47.651 1798942 3372.62 MinPts 16488 91 16084.04 15882.10 40.82 19438.28 3350.95 TD 1688063 16528.88 16353.4.INCE18005.07 3372.41 MinPt-O-SF 17857. 17854.1 17824.63 5352.07 268.36 268.36 MinPt-O-EOU 1 1785743 17854.1 17824.6 5368.32 271.23 271.23 MinPts 17857.68 17854.39 17824.8 5426.361 300.00 300.00 MinPt-OSF 16188.48 15871.37 157133 51.21 17081.67 3378.38 MinPts 15580.95 15410.14 15325.27 91.79 10042.25 3170.98 MinPt-CtCt 15580.98 15410.110 15325.20 91.75 10045.03 3171.35 MinPt-O-EOU 15581.02 15410.11 15325.19 91.73 10046.43 3171.53 MinPt-O-ADP 16700.20 16500.35 16400.92 83.971 11427.35 3353.03 MinPt-O-SF 1 16190.391 15873.34 15715.28 51.22 17080.28 3378.39 MinPts 16883.49 16531.73 16356.34 48.131 18005.43 3372.41 MinPt-O-SF I15890.01 15679.1 15574.16 75.70 13080.52 3410.51 MinPts 16190.3 15873.3 15715.24 51.21 17081.04 3378.38 MinPts 16529.74 16178.46 16003.31 47.191 17989.54 3372.62 MinPt-O-SF 17857.34 17856.12 17824.53 14588.83 0.00 0.00 Surface 17857.3 17854.54 17824.53 6373.97 198.10 198.10 MinPts 16009.8 1564243 1545923 43.69 18599.66 3357.53 MinPts 16000.7 15700.88 15551.46 53.54 16646.71 3379.01 MinPts 16535.08 16183.80 16008.6 47.20 17989.29 3372.82 MinPt-OSF 16097.24 15787.15 15632.60 52.0 16905.25 3378.64 MinP1-0SF 0 16098.76' 15788.54 15633.92 52.06 16908.84 3378.63 MinPts 16030.3 15712.5 15554.19 50.60 17162.58 3378.05 MinPts 16537.75 16186.47 16011.33 47.211 17989.18 3372.62 MinPt-O-SF 1 16030.351 15712.481 15554.03 50.58 17165.54 3378.03 MinPts 16237.20 15900.78 15733.06 48.40 17613.65 3374.90 MinP1-0SF 16349.17 16010.18 15841.17 463 17668.06 3374.58 MinPt-O-SF 1 16351.52 16012.461 15843.42 48.36 17669.77 3374.57 MinPts 16422.03 16081.19 15911.26 48.32 17712.28 3374.33 MinPt-O-SF 1 16359.01 16007.51 15832.32 46.67 18007.18 3372.38 MinPts 16127.0 15775.0 15599.52 45.94 18080.32 3370.95 MinPts 17162.40 16794.80 16611.49 46.81 18455.35 3360.07 MinPt-O-SF 1 16983.84 16783.171 16683.34 85.06 11467.03 3358.20 MinPts 15864.58 15652.50 15546.96 75.14 13061.97 3410.72 MinPt-O-SF 15849 15637.861 15532.51 7522 13073.42 3410.60 MinPts 1 15849.55 15637.86 15532.51 75.22 13073.60 3410.60 MinPt-CtCt 1655927 16207.99 16032.8 N' I 17988.41 3372.63 MinPt-O-SF MUM 17513.46 17403.74 80.81 13118.52 3409.92 MinPt-CtCt 17734.01 MIME. 17403.52 80.73 13128.45 3409.72 MinPt-O-EOU 1773412 17513.3:1111= 80.69 13132.58 3409.64 MinPt-O-ADP 15649.1 15387.98 15257.90 60.15 15603.60 3394.73 MinPt-CtCt 1564916 15387.96 15257.85 60.13 15604.48 3394.72 MinPt-O-EOU 15649.23 15387.97 15257.83 60.12 15605.38 3394.72 MinPt-O-ADP 16561.97 16210.70 16035.55 47.28 17988.33 3372.63 MInPt-OSF 1 16097.801 15730.931 15547.99 43.99 18506.86 3358.78 MinPts SP05-FN7(P2)(Def Plan) Pass 1 16271.24 15886.231 15694.24 42.371 18988.32 3355.05 MinPts 16485.47 16080.27 15878.17 40.78 19438.28 3350.95 TD 17855.31 17852. 17822.53 5347.76 268,41 268.41 MinPt-O-EOU 12 3 17852. 17822.5 5364.47 271.30 271.30 MinPts 17855.57 17852.28 17822.76 5423.8 300.16 300.16 MinPt-O-SF 15589.46 15419.06 15334.39 92.06 10020.18 3168.08 MinPt-CtCt 15589.5*IMIRMIE. 15334.33 92.02 10022.73 3168.42 MinPt-O-EOU 15589.53 15419.0'1 1468'586 92.01 10024.02 3168.59 MinPt-0-ADP 16957.59 16756.73 16656.7• 84 11450.83 3356.11 MinPt-O-SF 18540.09 18324.24 18216.81 8628 12060.94 3405.08 MinPt-O-SF 15902.6 sumiz 15586.81 75.76 13083.93 3410.47 MinPts 17855 24 17854.01 17822.43 14587.11 0.00 0.00 Surface 17855.24 17852.4417822.4 6372.17 198.10 198.10 MinPts 17855.50 17852.15 17822.69 5329.12 243.10 243.10 MinPt-O-EOU 16105.15 15737.36 15553.95 43.90 18599.73 3357.53 MinPts 16115.29 15815.12 15665.53 53.86 1664841 3379.01 MinPts 16152.89 15834.81 1567626 50.94 17162.88 3378.05 MinPts 16411.94 16075.10 15907.18 48.86 17613.83 3374.89 MinPt-O-SF 15877.51 15665.44 15559.9 75.211 13068.01 3410.66 MinPt-O-SF 15862.56 15650.891 15545.55 75.29 13077.84 3410.55 MinPts 15862.55 15650.89 15545.55 75.29 13078.00 3410.54 MinPt-CtCt 15666.34 15405.56 15275.65 60.30 15595.20 3394.79 MinPI-CICt 15666.38 15405.52 15275.58 60.28 15596.21 3394.78 MinPt-O-EOU 15666.41 15405 53 15275.581 60.27 15596.56 3394.78 MinPt-0-ADP SP18-N5(P4)(Del Plan) Pass 16660.16'+ 16161.8: 17469.83 3375.90 MinPts 17866.69 17863.39 17833.8:MUM 279.25 279.24 MinPt-O-SF 17866.90 17863.62 17834.0t.mmEE5N. 299.12 299.12 MinPt-O-SF MIEM12 .,1111.lIShá1 90.44 10098.90 3178.43 MinPts 15157.85 14944.97 14839.0. 51M 13193.08 3408.05 MinPt-O-SF '.1311M 14944.96 14839,01 71.53 13193.39 3408.04 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 14 of 24 Offset Trajectory _ Separation Allow Sep. Reference Trajectory Separation Factor Alert Status • _Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 15049.27 14803.75 1468148 61.54 15040.62 340020 MinPt-CtCt 15049.28 14803.73 1468145 61.53 15041.36 3400.21 MinPt-0-EOU 15049.31 14803.7 14681. 61.53 15042.10 3400.22 MinPt-O-ADP 1548009 15219.70 15089. 59.671 15583.01 3394.92 MinPt-O-SF 17866.57 17865.35 17833.77 14596.37 0.00 0.00 Surface 16653.8: 16284.20 16099.85 45.17 18598.66 3357.53 MinPt-CtCt 16656.8 16250.84 18048.33 41.12 19420.79 3351.11 MinPt-CtCt 16656.86 16250.07 16047.17 41.04 19438.28 3350.95 TO 16615.93 16314.02 16163.56 55.21 16648.37 3379.01 MinPt-CtCt 1662840 16308.53 16149.09 52.14 17162.18 3378.06 MinPt-CtCt 16654.15 16299.46 16122.61 47.08 18129.15 3369.65 MinPts 16654.15 16299. 16122.58 47.08 18129.63 3369.64 MinPts 14793.98 14627.14 14544.34 89.33 9759.51 3133.82 MinPt-CtCt 14793.98 14627.131 14544.32 89.32 9760.34 3133.93 MinPts 14903.06 14734.13 14650.301 88.881 9869.15 3148.23 MinPt-O-SF 17770 27 17552 72 17444.441 82.051 12100.71 3407.85 MinP1-0-SF 15410.85 5198 001 15092 071 72 73 1322036 3407.13 MinPts SP04SE5(P2)(Def Plan) Pass 16735 66 IMIE.MEIME' IIM 17498.71 3375.70 MinPts 111111 '�' '.n14 16689.3 ® 17623.49 3374.83 MinPts 17854.92 17851.83 17822.15423 08 300.21 300.21 MinPt-OSF _ 16427.76 16270.87 53.29 17026.29 3378.46 MinPts 17198.38 16846.69 16671. ''NM= 18015.79 3372.25 MinPl-OSF NEM 15408.51 15323.89 92.04 10012.88 3167.12 MinPt-CtCt 15578.: 5408 48. 15323.83 92.01 10015.06 3167.41 MinPt-O-EOU • 15578.88 15408.':MIME. 92.00 10016.16 3167.55 MinPt-O-ADP 16827.08 16635,17 16539.71 MM 11034.41 3301.38 MinPt-O-SF jjjjj64 WIRE MEM.MEM 17092.29 3378.36 MinPts 16738.9. 16406 8,MEM MIM 17501.03 3375.88 MinPts NEM EM12 15568 8, 75.60 13085.29 3410.45 MinPts 17202.25 16850.56 16675.21 49.05 18015.67 3372.25 MinPt-O-SF 16746.38 16428.88 16270.6 - 17091.83 3378.37 MinPt-O-SF MIME 16410.0 EIMM MIM 17503.33 3375.67 MinPts 17854.59 17853.37 17821.78 14586.58 0.00 0.00 Surface I 16749.621 16434.271 16277.08 53.28 17030.72 3378.46 MinPts 17206.12 16854.44 16679.09 49.06 18015.55 3372.25 MinPt-O-SF 16745: 16413.25 16247.63 50 55 17505.62 3375.65 MinPts 16445. 16092.44 15916.48 46.73 18130.22 3369.62 MinPt-CtCt 17210.00 16858.31 16682.96 49.07 18015.44 3372.25 MinPt-0SF 16299.93115931.93 15748. 44.41 18598.22 3357.54 MinPts 16590.39 16203.37 16010. 42.911 19030.36 3354.78 MinPt-0SF 16915.74 16517.46 16318.82 42.58 19286.81 3352.38 MinPt-O-SF • 17393.71 16990.23 16788.99 43.21 19406.42 3351.25 TD 16364,491 16064.171 1591450 54.67 16647.41 3379.01 MinPts 16753.05 16435.57 16277.33 52.93 17090.91 3378.3T MinPt-O-SF I 16748.761 16416.44 16250.78 50.55 17507.90 3375.64 MinPts 17213.87 16862.19 16686.84 49.08 18015.34 3372.25 MinPt-O-SF 16411.07 16092.79 15934.14 51.72 17182.86 3378.05 MinPts 16752.05 16419.64 16253.93 50.54 17510.16 3375.62 MinPts 16411.07 16092.74 15934.07 51.71 17184.30 3378.04 MinPts 17217.75 16866.07 1669072 49.09 18015.23 3372.26 MinPt-O-SF I 16758.661 16426.071 16260.26 50 54 17514.85 3375.59 MinPts 17225.52 16873.84 16698.49 49.12 18015.04 3372.26 MinPt-OSF I 16761.971 16429.291 16263.44 5053 17516.87 3375.57 MinPts 17229.40 16877.73 16702.36 49.13 18014.94 3372.26 MinPt-O-SF 18036.63 17669.45 17486.35 49.25 18455.15 3360.08 MinPt-OSF I 16765.291 16432.521 16266.62 50.53 17519.08 3375.56 MinPts 17233.29 16881.62 16706.27 49.1 18014.85 3372.26 MinPt-OSF I 16768.611 16435.751 16269.82 50.5 17521.27 3375.54 MinPts 17237.19 16885.51 16710.17 49.15 18014.76 3372.26 MinPt-O-SF I 16771.94 16439.001 16273.02 50.52 17523.46 3375.53 MinPts ' 17241.08 16889.41 16714.07 49.16 18014.68 3372.26 MinPt-O-SF I18780.02 16462.0 16304.38 53.02 17087.34 3378.37 MinPts 16775.28 16442.2 16276.22 50.52 17525.62 3375.51 MinPts 15867.07 15655.05 15549.53 75.18 13075.63 3410.57 MinPt-O-SF 15854.68 15643.001 15537. 75 24 13081.68 3410.50 MinPts 1 15854.6 15643.00 15537.65 75 24 13081.79 3410.50 MinPt-CtCt 1724498 16893.31 16717 961 45171 18014.60 3372.27 MinPt-O-SF 16783.42 16466.0 16307 791 53 04j 17086.90 3378.38 MinPts 16778.63 16445.5 16279 1 50 511 17527.78 3375.50 MinPts 15662.47 15402.02 15272.29 60 36 15586.90 3394.87 MinPt-CtCt • 15662.48 15402.01 1527227 60.36 15587.14 3394.87 MinPt-O-EOU ' 1566250 15402.02 15272.27 60.35 15587.39 3394.87 MinPt-O-ADP 17248.88 16897.21 16721.8 49.18118014.52 3372.27 MinPt-O-SF I16781.9 16448.771 1628266 50 51 17529.92 3375.48 MinPts 16447.8'41 16094.76 159187 46.71 18133.58 3369.52 MinPts 17252.78 16901.11 16725.7 49.19 18014.45 3372.27 MinPt-O-SF I16413.73116095.261 15936.5. 51.7$ 17167.57 3378.02 MinPts 16785. 16452.• 16285 881 50.51 17532.05 3375.47 ' MinPts 17256.69 16905.02 16729.68 49.21 18014.38 3372.27 MinPt-O-SF I16416.38 16097 781 15938.98 51.6: 17170.83 3378.00 MinPts 16788.7 16455 32 16289.12 50.5. 17534.16 3375.45 MinPts 17260.59 16908.93 16733.59 49.2 18014.31 3372.27 MinPt-O-SF I16419.0 16100 30 15941.431 51.67 17174.09 3377.97 MinPts 16792.0 16458.60 16292.361 50.50 17536.26 3375.44 MinPts 17264.50 16912.84 16737 501 49.23 18014.25 3372.27 MinPt-O-SF I16421.6911 16102.83 15943 89 51.66 17177.35 3377.95 MinPts 16795.45 16461.• 16295.611 50.50 17538.35 3375.42 MinPts 17288.42 16916.75 16741 411 49.24 18014.19 3372.27 MinPt-O-SF I16424.34 16105.351 15946.34 51.64 17180.62 3377,93 MinPts - 16798.83 16465.20 16298.871 50.50 17540.42 3375.41 MinPt-O-SF 17272.33 16920.67 16745.331 49.25 18014.14 3372.27 MinPt-O-5F Drilling Office 2.0:960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 15 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft EOU(ft Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major L 16427.00 16107.871 15948.80 51.63 17183.88 3377.90 MinPts 16802.22 16468.50 16302.131 50.491 17542.47 3375.39 MinPt-O-SF 17272.82 16921.16 16745.82 49.25 18014.13 3372.27 MinPt-O-SF F16429.661 16110.401 15951.26 51.62 17187.14 3377.88 MinPts 16805.62 16471.82 16305.41 50.491 17544.52 3375.38 MinPt-O-SF 1 17276.25 16924.58 16749.241 49.26! 18014.08 3372.27 MinPt-O-SF % 16432.32 16112.92 15953.72 5160 17190.41 3377.86 MinPts 16809.02 16475.14 1630868 50.49 17546.55 3375.36 MinPt-O-SF 17280.17 16928.50 16753.16 49.27 18014.03 3372.27 MinPt-O-SF 16434.98 16115.45 15956.17 51.59 17193.67 3377.84 MinPts 16812 43 16478 46 16311.9711 50.49 17548.57 3375.35 MinPt-O-SF 17284.09 16932 42 16757.0' 49.28 16013.99 3372.28 MinPt-O-SF 16437.63 16117.97 159586. 51.58 17196.93 3377.81 MinPts 16815.85 16481.80 16315.26 50.49 17550.57 3375.34 MinPt-O-SF 17288.01 16936.35 16761.01 49.30 18013.94 3372.28 MinPis 16440.29 16120 501 15961.091 51.56 17200.19 3377.79 MinPts 16819.27 16485 14 16318 5611 50.481 17552.56 3375.32 MinPt-O-SF 1 17291 9411 16940 2711 16764.9411 49.311 18013.90 3372.28 MinPts 1 16828.2011 16510.8711 16352 6911 53 191 17081.56 3378.38 MinPts L 16442.9511 16123.0211 15963.5511 51.55 17203.46 3377.77 MinPts 16822.69 16488 48 16321 87 50.4: 17554.53 3375.31 MinPt-O-SF 1683168 16514.42 16356.27 53.21 17079.61 3378.39 MinPt-O-SF 17295.86 16944.2., 16768.86 49.32 18013.87 3372.28 MinPts 16831.68 16514.36 16356.19 53.20 17081.18 3378.38 MinPts 16445.611 16125. 15966.01 51.54 17206.72 3377.74 MinPts 16826.13 16491.84 16325.18 50.48 17556.49 3375.30 MinPt-O-SF 16755.35 16422.85 1625710 50.54 17512.41 3375.60 MinPt-O-SF 16763.61 16411.3' 16235.77 47.72 18053.60 3371.54 MinPts 16448.27 16128 071 15968.,, 51.52 17209.98 3377.72 MinPts 16829.57 16495.20 16328. . 50.481 17558.44 3375.28 MinPt-O-SF L-16_81 16484 30 16308.7 47.9 18043.32 3371.75 MinPts I 16450 941 16130 60 15970.9. 51.51 17213.24 3377.70 MinPts 16833.01 16498.56 16331.:' 50.46 17560.37 3375.27 MinPt-O-SF L- 16839 781 16487.70 16312.1' 47.96 18042.88 3371.76 MinPts L 16453.601 16133.13 15973. 51.50 17216.51 3377.68 MinPts 16836 46 16501 94 16335.16 50.47 17562.29 3375.25 MinPt-O-SF 1_184663.71671. 16491.101 16315.5 47.97 18042.46 3371.77 MinPts 16135 65 15975.: 5148 17219.77 3377.65 MinPts 16839.92 16505.31 16338. . 50.47. 17564.20 3375.24 MinPt-O-SF 16846 571 16494.50' 16318.', 47.981 18042.03 3371.78 MinPts 16458.921 16138.18 15978.36 51.47 17223.03 3377.63 MinPts 16843.38 16508.70 16341.85 50.47 17566.09 3375.23 MinPt-O-SF 16849.94. 16497.921 16322.38'. 47.99 18041.61 3371.78 • MinPts 1r 16461.5 16140 71 15980.76 51.46 17226.30 3377.61 MinPts 16846.85 16512.09 16345.21 50.47 17567.96 3375.22 MinPt-OSF 11 6853.40 16501.3 16325." 48 00 18041.19 3371.79 MinPts 16464.2 16143.24 15983.2. 51.44 17229.56 3377.58 MinPts • 16850.33 16515.49 16348.57 50 47 17569.82 3375.20 MinPt-OSF • 16856.8211 16504 7711 16329.2311 48.011 18040.77 3371.80 MinPts 16466.9111 16145 771 15985 68 51.43 17232.82 3377.56 MinPla 16853.81 16518.90 16351 9411 50 471 17571.87 3375.19 MinPt-O-SF 16860 2511111=12 16332 671 48 02j 18040.36 3371.81 MinPts 16469 581 16148 29 15988 15 51 42 17236.08 3377.54 MinPts 16857 29 16522.31 16355.311 50471 17573.51 3375.18 MinPt-O-SF 16863 681] 16511 64 16336 11 48.03 18039.95 3371.82 MinPts 16472.2 16150.8 15990.61 51.40 17239.35 3377.52 MinPts 16860.79 16525.73 16358.69 50.43 17575.33 3375.16 MinPt-O-SF 6867.11 16515.0 16339.56 48 0 18039.55 3371.82 MinPts 16474.910 16153.35 ' D7 51.39 17242.61 3377.49 MinPts 111rrr---16864.28 16529.15 16362.08 50.47 17577.13 3375.15 MinPt-OSF 6870.57 16518.54 16343.01 48.06 18038.14 3371.83 MinPts 16477.57 16155.88 15995.53 51.38 17245.87 3377.47 MinPts 16867.79 16532.58 16365 4711 50.471 17578.93 3375.14 MinPt-O-SF F 16874.0.' 16522 D011 16346 4711 48.071 18038.74 3371.84 MinPts 16480.2' 16158.42 15998.00 51.36 17249.13 3377.45 MinPts 16871.30 16536.02 16368.8811 50.471 17580.70 3375.13 MinPt-O-SF 16877 48 6525 461 16349 940 48.081 18038.35 3371.85 MinPts 16482.90 16160.95 16000.46 51.35 17252.40 3377.42 MinPts 16874.81 16539.46 16372.2: 50.47 17582.47 3375.11 MinPt-O-SF 16880.9 16528.9 16353.4. 48.09 18037.95 3371.85 MinPts 16485.57 16163.48 16002.9. 51.34 17255.66 3377.40 MinPts 16878.33 16542.91 16375.7. 50.471 17584.22 3375.10 MinPt-O-SF 16884.42 16532.411 16356.•. 4810 18037.56 3371.86 MinPts 16488.24- 16166.01 16005.3' 51.32 17258.92 3377.38 MinPts 16881.86 16546.37 16379.1. 50.471 17585.95 3375.09 MinPt-O-SF 16887.90116535.8911 16360. : 48.11 18037.18 3371.87 MinPts 16490.91 16168. 16007.8 51.31 17262.18 3377.36 MinPts 16885.39 16549.83 16382 541 50.471 17587.67 3375.08 MinPt-O-SF 16891.381 16539.38 16363.88 48.12 18036.79 3371.88 MinPts 16493 57 16171.0 16010.32 51 30 17265.45 3377.33 MinPts 16888 93 16553.30 16385.98 50.47 17589.38 3375.07 MinPt-O-SF 16894 871 16542 88 16367.37 48.1 18036.41 3371.88 MinPts 16496.2' 16173611 16012.791 51.28 17268,71 3377.31 MinPts 16892.47 16556.77 16389.42 50 47 17591.07 3375.05 MinPt-O-SF 1 16898.3 16546.33 16370.88 48.14 18036.03 3371.89 MinPts 16498.91 16176.1 16015.25 5127 17271.97 3377.29 MinPts 16896.02 16560.25 16392.861 50 471 17592.75 3375.04 MinPt-O-SF 16901.871 16549 8 16374.39 48 15 18035.66 3371.90 MinPts 16501.58 16178.681 16017.72 51.26 17275.24 3377.26 MinPts 16899.57 16563.74 16396.32 50.47 17594.41 3375.03 MinPt-O-SF 1 16905.381 16553 401 16377.91 48 16 18035.29 3371.90 MinPts 16504 25 16181 21 16020.19 51 24 17278.50 3377.24 MinPts 16903 13 16567 23 16399.77 50.47 17596.06 3375.02 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point10120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 16 of 24 Offset Trajectory Se•aratlon Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft EOU(ft Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 17221.6 16869.9 1669461 49.1 18015.13 3372.26 MinPts 16504.8• 16197.9 16045.01 53. 16812.77 3378.77 MinPts 17794.36 17476.9• 17318.71' 56.23 17080.84 3378.39 MinPts 16506.9. 16183.751 16022.65 51.23 17281.76 3377.22 MinPts 6906.7* 16570.731 16403.24 50.47 17597.69 3375.01 MinPts 16507.56 16200.58 16047.58 53.94 16815.97 3378.77 MinPts 16509.5' 16186.28 16025.12 51.22 17285.02 3377.20 MinPts 16910.27 16574 23 16406.71 50.47 17599.32 3375.00 MinPt-O-SF I16915.9 16563.98 16388.4' 48.1' 18034.19 3371.93 MinPts 16512.2 16188.8 16027.5 5120 17288.26 3377.17 MinPts 16913.84 16577.744-11 16410.1' 50.471 17600.92 3374.98 MinPt-0-SF 18885.05 18643.131 18522.6 78.38 1453629 338294 MinPt-0-ADP 116512.261 16188.8 16027.5• 51.20 17288.29 3377.17 MinPts 16917.42 16581.26 16413.6 50.41 17602.51 3374.97 MinPt-O-SF 1 16514.941 16191.30 16030.0 51.19 17291.54 3377.15 MinPts 16921.01 16584.78 16417.16 50.4 17604.09 3374.96 MinPt-O-SF r16926. : 16574.61 16399 13 48.2 18033.13 3371.94 MinPts E11t.1V&00• 16193.921 16032.561 51.18 17294.79 3377.13 MinPts 16924.60 16588.31 16420 651 50.471 17805.65 3374.95 MinPt-O-SF I16930.11 16578.17 16402.69 48.24 18032.78 3371.95 MinPts 16520.316196.481 16035.05 51 17 17298.02 3377.11 MinPts 16928.19 16591.84 16424.16 50 471 17607.20 3374.94 MinPt-O-SF 18239.92 17872.04 17688.5• 49 711 18489.85 3359.18 MinPt-O-SF I16933.61 16581.73 16406.2 48.2516 18032.44 3371.96 MinPts 16523.0 16199.0 16037.56 51.15 17301.24 3377.08 MinPts 16931.79 16595.38 1642766 50_)4 17608.74 3374.93 MinPt-O-SF 18202.06 17834.32 17650.• 49.6 1848243 3359.34 MinPt-O-SF IL16937.2 16585. 16409.8. 4826 18032.09 3371.96 MinPts L 16525.7 18201 16040.07 51.14 17304.46 3377.06 MinPts 16935.40 16598.92 16431.1: 50.48 17610.25 3374.92 MinPt-O-SF E16940.80 16588.87 16413.3• 48271 18031.75 3371.97 MinPts 16528. 16204.22 16042.5• 51.1"""3"""��/��1 17307.65 3377.04 MinPts 16939.01 16602.47 16434.61 50.4 17811.76 3374.91 MinPt-0SF 1010944.31 16592.4 16416.97 48.2 18031.42 3371.98 MinPts AAIAAI����--1653118 16206.8 16045.1 51.12 17310.84 17310.84 3377.02 MinPts 16942.63 16606.03 16438.2 50.41 17613.25 3374.90 MinPt-O-SF I16947.91 16596.03 16420.56 48.2 18031.09 3371.98 MinPts 16533.9 16209.42, 16047.671 51.11 17314.02 3376.99 MinPts 16946.25 16609.63 16441.81• 50.49 17613.66 3374.90 MinPt-O-SF [ 16951.53 16599.1 J 16424.1 48.3('JI 18030.76 3371.99 MinPts 16536.68 16212.04 16050. 51.09 17317.18 3376.97 MinPts 16949.87 16613.24 16445.41 50.50 17813.88 3374.89 MinP1-0SF I16955.1 16603.211 16427.7• 4831 18030.43 3371.99 MinPts 16539.41 16214 66 16052.7: 51 08 17320.33 3376.95 MinPts 16953.51 16616.86 16449.0.. 50.50 17614.10 3374.89 MinP1-0SF L 16958.711 16606.811 16431.3 • 48.32 18030.11 3372.00 MinPts S114-N6(P2)(Def Plan) Pass 17863.28 17860.12 17830.47 5658.27 251.08 251.08 MinPts 17863.72 17860.42 17830.91 5411. 279.59 279.59 MinPt-O-SF 17863.94 17860.65 17831.13 5435.4 299.55 299.55 MinPt-O-SF I15222.08 15009.161 14903.19 71.8 13172.17 3408.67 MinPte 15098.77 14851.28 14728.02 61.25 15102.44 3400.69 MinPt-CtCt 15098.79 14851.21 14728.00 6124 15103.18 3400.69 MinPt-O-EOU 15098.82 14851.2`071 14728. 61.23 15103.93 3400.69 MinPt-0,ADP 15497.51 15237.69 15108.2 59.871 1556242 3395.17 MinPt-O-SF 17863.60 17862.38 17830.80 14593.95 0.00 0.00 Surface 17872.57 17466.90 17264.57 44.16 19438.28 3350.95 TD man 14712.07 14628.48 89.00 9846.28 3145.23 Mi6Pt-CtCt 14880.4'®' 14628.46 0 88.99 9847.48 3145.38 MinPts 14940.80 14770.76 14686.3 ® 9931.81 3156.47 MinPt-OSF 18406.38 18204.89 18104.6.: - 11450.63 3356.09 MinPt-O-SF 18419.78 18218.15 18117.8 • 91.80 11456.44 3356.85 MInPt-OSF 18523.57 1832080 18219.911 11500.82 3362.31 MinPt-O-SF 19156.31 18939.97 18832 29 88.95 12101.27 3407.89 MinPt-O-SF 17898.671®:* 17421.66 56.40 17081.06 3378.38 MlnPts S102-SE6(P2)(Def Plan) --/1 Pap L_17936.751 17599.56117431 5� 53.3 17615.39 3374.88 MinPts 18465.99 18123.08 179521`9j1 54. 17754.11 3374.10 MinPt-O-SF 17853.31.1:1=E• 17820.57 5341.85 268.47 268.47 MinPt-O-EOU 17850.*•M.•] 5359.14 271.37 271.37 MinPts 17853.62 17850.32 17820.81111.EIM 300.32 300.31 MinPt-O-SF MIME. 16978.0. 17133.10 3378.23 MinPts E'I MIIIEM 16967.66 53.94 17313.38 3377.00 MinPts 18467.17 18115.68 17940.4 MEM 17983.02 3372.70 IKEISE I •' 18023.48 3372.12 MinPts 15604.30 15434.83 15350.63 92.66 9975.05 3162.15 MinPt-CtCt 15604.321111 15350.61 92.64 9975.87 3162.26 MinPt-O-EOU 15604.35 15434.8 .=I, 9203 9978.69 3162.37 MInP1-0-ADP 15775.47 15602.58 15516.67i,M8•3I 10117.25 3180.84 MinPt-O-SF 16995.8'IMM66 16820.63 3378.76 MinPts 17940.61 17603.401....I® 17615.74 3374.88 MinPts 15906.8. 15695.8.!NM:075 74 13087.37 3410.42 MinPts 17458.55 17140.41 16981.8 'II.MMEI 17132.62 3378.23 MinP1-0SF .M111 53 94 17315.85 3376.98 MinPts 18471.53 18120.05 17944.8* 17982.90 3372.70 MinPt-O-SF mum Exim2,man18022.97 3372.13 MinPts 17460.08 17152.76 16999.6* 16823.00 3378.76 MinPt-0-SF ��• r:, 17618.08 3374.88 MinPts 17853.28 17852.06 1782047 14585.51 0.00 0.00 Surface E17853.21 17850. 178204 70.43 8.10 198.10 MinPts 17462.3 17144.2 16985.6 6355 061 17132.13 3378.23 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 17 of 24 Offset Trajectory Separation Mow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)J EOU(ft` Dev.(!) Fact. MD(ft) I TVD(ft) Alert [ Minor 1 Major L 17461 5 1 17136.801 16974.9.. 53.93 17318.32 3376.96 MinPts 18475.90 18124.42 17949.17 52.71 17982.79 3372.70 MinPt-O-SF 1 17949 091 17596.82 17421.18 51.09 18022.45 3372.14 MinPts 17948.35 17611.09 17442.96 53.37 17616.42 3374.88 MinPts 17465.32 17140.48 16978.55 53.93 17320.79 3376.95 MinPts 18480.26 18128.79 17953.54 52.72 17982.68 3372.70 MinPt-OSF 17952.91 17600.65 17425.01 51.10 18021.95 3372.14 MinPts 16887.49 16519.43 16335.89 46.00 18597.49 3357.54 MinPts 17207.01 16854.03 16678.02 48.88 18130.24 3369.62 MinPts 17179.49 16879.07 16729.35 57.37 16647.42 3379.01 MinPts 17471.64 17164.04 17010.731 56.98 16830.11 3378.74 MinPt-O-SF 17473.80 17155.67 16997.1. 55.0" 17130.68 3378.24 MinPt-O-SF 17472.89 17147.85 16985.8. 53.922tltl 17325.73 3376.91 MinPts 17227.39 16909.03 16750.35' 54.22 17162.69 3378.05 MinPts 17227.39 16908.95 16750.21 54.26 17165.21 3378.04 MinPts 17231.16 16912.61 16753.83 54.26 17167.68 3378.02 MinPts 17963.90 17626.57 17458.40 53.41 17617.76 3374.87 MinPt-O-SF 17480.46 17155.2 16993.08 53.90 17330.67 3376.88 MinPts 17968.26 76 6 031 17440.4111 51.151 18019.95 3372.18 MinPts EREMI®I 17021.871 56.96 16837.22 3378.73 MinPts 17967.81 17630.46 17462.27 53.41 17618.09 3374.87 MinPt-O-SF 1 1748425/ 17158.901 16996.72 53.90 17333.13 3376.86 MinPts 17487 061 17179 08 1702558 56.96 16839.59 3378.73 MinPts 17971.72 17634.35 17466.16 53.421 17618.42 3374.86 MinPt-O-SF 17488.0, 17162.58 17000.35 53.89 17335.60 3376.84 MinPts 17975.64 17638.25 17470.04 53.4311 17618.75 3374.86 MinPt-O-SF 1 17491.821 17166.27 17003.98 53.89 17338.07 3376.82 MinPts 1 17494.7711 17186.601 17033.0111 56.95 16844.33 3378.72 MinPts 1 17979.5611 17642.151 17473.9411 53.-1 17619.07 3374.86 MinPts 1 17495.6111 17169.9511 17007.6111 53.88 17340.54 3376.81 MinPts 17983.49 17646.06 17477.84 53.4 17619.39 3374.86 MinPt-O-SF 1 17499.401 17173,6411 17011.25 53.88 17343.01 3376.79 MinPts 18519.64 18168.18 17992.941 17981.82 3372.71 MinPt-O-SF 11 179825911 17635.4111 17459.8211 51.221 18017.51 3372.22 MinPts 15897.58 15685.82 155804• 75.42 13083.58 3410.47 MinPt-O-SF 15886.60 15675.141 15569.901 75.47 13086.03 3410.44 MinPt-O-ADP 11 15886.5911 15675.1311 15565.90 75.48 13086.08 3410.44 MinPts 17502.49 17194.13 1717®®i 16849.07 3378.72 MinPt-O-SF 17987.43 17649.98 J 17619.71 3374.86 MinPts MIME® 17014.88 53.87 17345.48 3376.77 MinPts 18524.02 18172.56 17997.33 MEI 17981.75 3372.71 MinPt-O-SF 7991.48 MEE ME=® 18017.03 3372.23 MinPts 5699.11 15439.75 15310.57 60.76 15564.72 3395.14 MinPt-CtCt 15699.12 M'. 15310.54 60.75 15565.19 3395.14 MinP1-0-EOU 15699.15 15439.74 60.75 15565.67 3395.13 MinPt-O-ADP 15772.81 15511.05 15380.67 60.48 15602.39 3394.74 MinPt-O-SF 17506.34 17197.89 17044.15 MIZE 16851.44 3378.71 MinPt-O-SF 17989.39 11111 17483 69 111111111111111310 17619.87 3374.85 MinPts 17506.97 alliMil MOM 53.87 17347.95 3376.76 MinPts 18528.40 18176.95 18001.71®8 17981.67 3372.71 MinPt-O-SF 17993.41 MEM! 17465 66® 18016.80 3372.23 MinPts I®t'. 16828.78 16639.50 45.46 18859.39 3355.87 MinPts 17418.78 17031.71 16838.67=ME 19029.70 3354.78 MinPt-O-SF 17959.85 17554.45 17352.25 44.41 19438.28 3350.95 TD 17991.371 17653.9111 17485.66 53.47i1 17620.03 3374.85 MinPts 17510 76 17184.691 17022.15 53.86 17350.42 3376.74 MinPts 18532.79 18181.33 18006.10 52.88 17981.60 3372.71 MinPt-O-SF 17995.3 i 17643.21 17467.63 51.24 18016.56 3372.23 MinPts 17254 051 16899.58 16722 84 48.81 18164.57 3368.61 MinPts 17995.3211 17657.8411 17489.5811 53.471 17620.35 3374.85 MinPts 17514.55 17188.38 17025.79 53.86 17352.89 3376.72 MinPts 18537.17 18185.72 18010.49 52.89 17981.53 3372.71 MinPt-O-SF 17999.27 17647.12 17471.54 51.25 18016.09 3372.24 MinPts 17999.2811 17661.7711 17493 5111 53.481 17620.66 3374.85 MinPts 17518.3411 17192.0711 17029.421 53.85 17355.36 3376.70 MinPts 18541.56 18190.11 18014.871 52.901 17981.46 3372.71 MinPt-O-SF 18003,18 INEMEMI 17475 461 51.271 18015.62 3372.25 MinPts 18003.2•EMI211 17497.441 53.491 17820.98 3374.85 MinPts 17522.13=MEI 17033.061 53.85 17357.83 3376.69 MinPts 18545.94 18194.50 18019.261 52.921 17981.40 3372.72 MinPt-O-SF 18007.0911 17654 9611 17479.391 51.281 18015.15 3372.26 MinPts 18007.20 17669.66 17501.38 53.50 17621.30 3374.85 MinPts 17525.92 17199.44 1703669 53.84 17360.30 3376.67 MinPts 18550.33 18198.88 18023.65 52.93 17981.34 3372.72 MinPt-O-SF 18011.01 17658.89 17483.32 51.29 18014.69 3372.26 MinPts 18011.18 17673.62 17505.33 53.511 17621.61 3374.84 MinPts 17529.7111 17203.1311 17040.331 53.84 17362.77 3376.65 MinPts 18554.72 18203.27 18028.041 52.941 17981.28 3372.72 MinPt-O-SF 18014.93=mu17487.26 51.301 18014.23 3372.27 MinPts 18015.161 17677.581 53.521 17621.93 3374.84 MinPts 17533.5011 17206.8111 17043.961 53.83 17365.24 3376.63 MinPts 18559.11 18207.67 18032.441 17981.23 3372.72 MinPt-0-SF 18018.8711 17666.761 1749120® 18013.78 3372.28 MinPts 18019 1411 17681.541 17513.24 116 17622.24 3374.84 MinPts 17537.2911 17210.5011 17047 601 53.83 17367.71 3376.62 MinPts 18563.50 18212.06 18036.831 52.971 17981.18 3372.72 MinPt-O-SF 8022 80 17670.71 17495.151 51.331 18013.32 3372.29 MinPts 18023.13 17685.5 17517201 53.541 17622.55 3374.84 MinPts 17541.08 17214 19 17051.2 53.82 17370.18 3376.60 MinPts 18567.89 18216.45 18041.22 17981.13 3372.72 MinPt-O-SF • 18026.75 1767466 1749911 51.3 18012.87 3372.29 MinPts 18027.13 17689 49 17521 17 535 17622.85 3374.84 MinPts 1 17544.8711 17217.8811705487 53.81 17372.65 3376.58 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 18 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 18572.28 18220.84 18045.61 52.99 17981.08 3372.72 MinPt-O-SF 18030,7011 17678.6211 17503.0711 51.351 18012.43 3372.30 MinPts 18031.1311 17693.4811 17525.151 53.55 17623.16 3374.83 MinPts 1 17548.66 17221.56 17058.51 53.81 17375.12 3376.57 MinPts 18576.68 18225.24 18050.01 53.00 17981.04 3372.72 MinPt-O-SF 18034.66 17682.59 17507.04 51.37 18011.98 3372.31 MinPts 18035.14 17697.47 mg= 53.56 17623.46 3374.83 MinPts 17552.4511 17225.2511 17062.1511 53.80 17377.59 3376.55 MinPts 1 18581.07 18229.63 18054.4011 53.021 17981.00 3372.72 MinPt-O-SF 18038.62 17686.561 17511.021 18011.54 3372.31 MinPts 18039.151 17701.461 17533.111® 17623.87 3374.83 MinPts 0000 l 17228.941 17065.781 53.80 17380.05 3376.53 MinPts 18585.47 18234.03 18058.801 53.031 17980.97 3372.72 MinPt-O-SF 1804259117690.531 17515.001 51.391 18011.10 3372.32 MinPts 18043 1711 17705.4011 17537 011 53.571 17625.89 3374.82 MinPts 1 17560.0311 17232.6311 17069.421 53.79 17382.52 3376.51 MinPts 18589.86 18238.42 18063.201 53.041 17980.94 3372.72 MinPt-O-SF 1 18046.5611 17694.5211 17518.991 51.401 18010.67 3372.33 MinPts 1 18047.1911 17709.3411 17540.911 53.571 17627.88 3374.81 MinPts 17563.82 17236.32 17073.06 53.79 17384.99 3376.50 MinPts 18594,26 18242.82 18067.59 53.06 17980.91 3372.72 MinPt-O-SF 18050. •I 17698.51 17522.98 51.42 18010.24 3372.33 MinPts 18051. . 17713.29 17544.82 53.57 17629.87 3374.80 MinPts 17567,61. 17240.01 17076.70 53.78 17387.46 3376.48 MinPts 18598.65 18247.21 18071.991 17980.88 3372.72 MinPt-OSF 130541 :1)1 17526.981® 18009.81 3372.34 MinPts 18055.261 17717.251 17548 7411 53.571 17631.84 3374.79 MinPts 0000011000001 7080 34 53.78 17389,93 3376.46 MinPts 18603.05 18251.61 18076.3910000000011 17980.86 3372.72 MinPt-O-SF • 18058.52 17706.51r 99 00000 MO 18009,38 3372.35 MinPts 1 18059.301 772 2 17552.661 53.571 17633.80 3374.77 MinPts • 1 17575.2011 17247.3911 17083.9811 53.77 17392.40 3376.44 MinPts 18607.44 18256.01 18080.7811 53.091 17980.84 3372.72 MinPt-O-SF 1 18062.5211 17710.5111 17535.0011 51.451 18008.96 3372.35 MinPts 18063.3 1 17725.81 17556 5911 53.571 17635.74 3374.76 MinPts 7578 991 17251.081 17087.611 53.77 17394.87 3376.43 MinPts 18611.84 18260.41 18085.18® 17980.82 3372.72 MinPt-O-SF 1806652 17714.52 17539.0100000000001E' 18008.54 3372.36 MinPts 18067.39 17729.15 17560.53® 17637.67 3374.75 MinPts 17582.78 17254.77 1709125 53.76 17397.34 3376.41 MinPts 18616.24 18264.80 18089.58 53.12 17980.81 3372.72 MinPt-O-SF 18070.53 17718.54 17543.0 000000000000.x-• 18008.12 3372.37 MinPts 18071.45 17733.13 17564,47® 17639.59 3374.74 MinPts 1_ 17586.58 17258.461 17094.89 53.76 17399.81 3376.39 MinPts 18620.64 18269.20 18093.98 53.13 17980.80 3372.72 MinPt-O-SF 18074.5J1 17722.5611 17547.0611 51.491 18007.71 3372.37 MinPts 18075,5111 17737.1211 17568.4211 53.571 17641.49 3374.73 MinPts 1 17590 370 17262 1511 170985311 53.75 17402.28 3376.38 MinPts 18625.03 18273.60 18098.3811 53.141 17980.79 3372.72 MinPt-O-SF 1 18078.5711 17726.5911 17551.1011 51.501 18007.30 3372.38 MinPts1 18079.58 17741 111 17572.3713.57 17643.38 3374.72 MinPts 17594.16 17265.84 17102.17 53 75 17404.75 3376.36 MinPts 18629.43 18278.00 18102.771', 17980.79 3372.72 MinPt-O-SF 18082.60 000001 m0>l1 51.521 18006.89 3372.38 MinPts 18083,65 17745.11 17576.33= 17645.25 3374.71 MinPts 17597.96 17269.53 17105.81 17407.22 3376.34 MlnPts 18633.83 18282.40 18107.17® 17980.79 3372.72 MinPt-O-SF 18086.63 17734.67 17559.18® 18006.49 3372.39 MinPts 18087.72 17749.111 17580.2910=En 17647.11 3374.70 MinPts EIMME1 17273.2211 17109.451 53.74 17409.69 3376.32 MinPts 18638.23 18286.80 18111.57100000000000 8 17980.79 3372.72 MinPt-O-SF 18090.6711 17738.7211 17563.2311 51.541 18006.09 3372.40 MinPts 18091.801 17753 121 17584.261 53.571 17848.96 3374.69 MinPts 11111111 '' g1 17276.911 ® 17412.16 3376.31 MinPts 18642.63 18291.19 18115.971 53.191 17980.79 3372.72 MinPt-O-SF 18094.7111 17742.7711 17567.291 51.551 18005.69 3372.40 MinPts 18095.8911 17757.131 17588.24 53.571 17650.79 3374.68 MinPts 17609.341 17280.6100001 53.72 17414.63 3376.29 MinPts 18098.761 17746.82'1® 51.571 18005.30 3372.41 MinPts 18099 98M1® 53 571 I 17652.60 3374.67 MinPts 17613.141 17284.30100001 53.72 17417.10 3376.27 MinPts 18102.82 17750.89 00000 M 51.5 18004.91 3372.41 MinPts 18104.08 EMIIIE MEM 53.57 17654.40 3374.66 MinPts 17616.93 17287.99 00000[1 53.71 17419.57 3376.25 MinPts 18106 88 00001 17579.49 51.591 18004.52 3372.42 MinPts 18108.1811 17769.201 17600.2101 17656.19 3374.65 MinPts 17620.73 17291.68 17127.65 53.71 17422.04 3376.24 MinPts 18110.940 17759.031 17583.56 51.61 18004.13 3372,42 MinPts 00000000/ 17604.21 MEM 17657.97 3374,64 MlnPts 17624 5211 17295.38 00001 53.70 17424.51 3376.22 MinPts 18115.0111 17763.1100001". 51.62 18003.75 3372.43 MinPts 18116.391 17777.2811 17608211 53.581 17659.73 3374.63 MinPts 17628.321 17299.0711 17134.931 53.70 17426.97 3376.20 MinPts 18119.091 17767.1911 17591.731 51.631 18003.37 3372.44 MinPts 17633.751 17322 1611 17166.851 56.771 16929.66 3378.60 MinPts 18120 511 17781.3211 17612 221 53.581 17661.47 3374.62 MinPts 1 17632.111 17302.7611 17138.581 53.69 17429.44 3376.18 MinPts 18123.171 17771.2811 17595.821 51.641 18002.99 3372.44 - MinPts 17637.611.11=00001000000000 16932.03 3378.60 MinPts 18124.631 17616.24 mliED 17663.20 3374.61 MinPts 17635 91 17306.45 17142.22 53.69 17431.91 3376.17 MinPts 18127.2600001 17599.92 man 18002.62 3372.45 MinPts 17641.4811 17329.7011 17174.301000000000 16934.40 3378.60 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 19 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft), Dev.(ft), Fact. MD(ft) I TVD(ft) Alert Minor I Major 18128.75` 17789 .43 17620.26 53.58 17664.92 3374.60 MinPts 17639.71 17310.15 17145.86 5368 17434.38 3376.15 MinPts 18131.35 17779.47 17604.02 51.67 18002.25 3372.45 MinPts 17645.34 17333.47 17178.02 56.75 16936.77 3378.59 MinPts 18132.88 17793.45 17624.29 53.58 17666.62 3374.59 MinPts 17643.50 17313.84 17149.50 53.68 17436.85 3376.13 MinPts 18135.45 17783.571 17608.13 51.68 18001.89 3372.46 MinPts 1764921 17337.24 17181.74 56.75 16939.14 3378.59 MinPts 18137.01 17797.56 1762832 53,58 17668.31 3374.58 MinPts 17647.30 17317.54 17153.15 53.67 17439.32 3376.12 MinPts 18139.55 17787.68 17612.24 51.69 18001.52 3372.46 MinPts 17653.08 17341.01 17185.47 56.74 16941.51 3378.59 MinPts 18141.15 17801.63 17632.36 53.58 17669.98 3374.57 MinPts 17651.10 17321.23 17156.79 53.67 17441.79 3376.10 MinPts 18143.65 17791.80 17616.36 51.71 18001.16 3372.47 MinPte 17656.94 17344.78 17189.19 56.7 16943.88 3378.58 MinPts 18145.29 17805.70 17636.40/ 53.5 17671.64 3374.56 MinPts 17654.90 17324.93 17160.43 53.86 17444.26 3378.08 MinPts 18147.77 17795.92 1762048 51.72 18000.81 3372.47 MinPts 17660.81 17348.55 1719291 56.73 18946.25 3378.58 MinPts 18149.44 17809.79 1764045 53.59 17673.29 3374.55 MinPts 17658.70 17328.62 17164,07 53.66 17446.73 3376.06 MinPts 18151.88 17800.04 17624.61 51.73- 18000.45 3372.48 MinPts 17664.67 17352.32 17196.64 56.73 16948.62 3378.57 MinPts 18153.59 17813.87 17644.51 53.59 17674.92 3374.54 MinPts 1766249 17332.32 17167.72 53.65 17449.20 3376.05 MinPts 18156.00 17804.17 17628.74 51.75 18000.10 3372.48 MinPts 17668.54 17356.09 17200.36` 56.72 16950.99 3378.57 MinPts 18157.75 17817.96 17648.56 53.59 17676.53 3374.53 MinPts 1766629 17336.01 17171.36 53.65 17451.67 3376.03 MinPts 18160.13 17808.30 17632.88 51.76 17999.75 3372.49 MinPts 1767241 17359.86 17204.08 56.72 16953.36 3378.57 MinPts 18161.91 17822.06 1765263 53.59 17678.13 3374.53 MinPts 17670.09 17339.71 17175.01 53.64 17454.14 3376.01 MinPts 18164.26 17812.44 17637.02 51.77 17999.41 3372.49 MinPts 17676.28 17363.64 17207.81 56.71 16955.73 3378.56 MinPts 18166.07 17826.16 17656.70 53.60 17679.72 3374.52 MinPts 17673.89 17343.40 1717865 5363 17456.61 3375.99 MinPts 18168.40 17816.58 17641.17 51.78 17999.07 3372.50 MinPts 17680.14 17367 41 17211.53 56.71 16958.10 3378.56 MinPts 18170.24 17830.27 17660.77 53.60 17681.29 3374.51 MinPts 17677.69 17347.10 17182.30 53.63 17459.08 3375.98 MinPts 18172.54 17820.73 17645.32` 51.80 17998.73 3372.50 MinPts 17684.01 17371.18 17215.26 56.70 16960.47 3378.56 MinPts 18174.42 17834.38 17664.85 53.60 17682.85 3374.50 MinPts 17681.49 17350.80 17185.94 53.62 17461.55 3375.96 MinPts 18176.68 17824.88 17649.47 51.81 17998.39 3372.51 MinPts 17687.88 17374.95 17218.98 56.70 16962.84 3378.55 MinPts 18178.59 17838.50 17668.94 53.60 17684.39 3374.49 MinPts 17685.29 17354.49 17189.59 53.62 17464.02 3375.94 MinPts 18180.83 17829.04 17653.63 51.82 17998.06 3372.51 MinPts 17691.75 17378.73 1722271 56.69 16965.21 3378.55 MinPts 18182.77 17842.62 1767303 53.61 17685.92 3374.48 MinPts 17689.09 17358.19 1719323 53.61 1746649 3375.93 MinPts 18184.99 1783320 17657.80 51.84 17997.73 3372.51 MinPts 1769562 17382.50 1722643 56.69 16967.58 3378.55 MinPts 18186.96 17846.74 17677.12 53.61 17687.44 3374.47 MinPts 17692.89 17361.89 17196.88 53.61 17468.96 3375.91 MinPts 18189.15 17837.37 17661.97 51.8s� 17997.41 3372.52 MinPts 17479.01 17117.45 16937.16 480.7°11 18326.28 3363.80 MinPts Nikailchuq 4PB1(Def Survey) Paas 18587.09 18585.13 18554.2 9456.73 51.00 51.00 MinPts 18587.64 18584.79 18554.83 651921 165.92 16592 MinPt-O-EOU I18588.45 18584.15 18555.651 4318.14 408.88 408.80 MinPts 18588.74 18583.88 18555.93 3824.10 454.17 453.95 MinPt-O-EOU 18590.00 18584.1C. 18557.19 3150.41 515.55 514.92 MinP2-0-EOU I 18413.85 18366.48 18343.69 404.04 3000.64 224024 MinPt-CtCt 18413.86 18366.47 18343.68 403.89 3002.11 2240.55 MinPt-O-EOU 18413.86 18366.47 18343.68 403.85 3002.48 2240.63 MinPt-O-ADP 11496.97 18448.72 18425.48 397.851 3090.67 2256.86 MinPt-O-SF 18541.31 18493.00 18469.73 398.30 3105.36 2259.08 TD SP11-N7(P2)(Del Plan) Pass I17859.811 17856.64 17827.00 5624.59 251.09 251.09 MinPts 17860.23 17856.93 17827.4 5407.5 279.74 279.74 MinPt-OSF 17860.44 17857.16 17827.64 5430.4 299.80 299.80 M1nPt-OSF ' 15330.491 15117.611 1501167 72.34 13214.41 3407.34 MinPts 15330.51 15117.63 15011.68 72.341 13214.90 3407.32 MinPt-O-SF I 15233.05 14988.72 14867.04 62.59 15002.63 3399.26 MinPt-CtCt 15233.1 14988.7c1 14866.98 62.57 15005.02 3399.33 MinPt-O-EOU 15233.13 149887 14866.9 62,57 15005.63 3399.35 MinPt-O-ADP 15592.76 15333.28 15204.0 60.321 15566.37 3395.12 MinPt-O-SF 17860.11 17858.89 17827.30 14591.09 0.00 0.00 Surface 19051.59 18680.83 18495.94® 18595.08 3357.56 MinP1-0SF 19055.57 18647.54 18444.01 46.81 1943828 335095 TD 14765.57 14684.59 92.16 9554.59 3106.89 MinPt-CtCt 14928.77 EZEMI 14684.52 92.12 9558.55 3107.41 MinPt-O-EOU 14928.82 14765.55 9210 9560.52 3107.67 MinPt-O-ADP 15258.76 15089.52 15005.46 _ 90 76 9916.63 3154.47 MinPt-OSF 19238.24 19020.18 18911.641 88.62 13075.07 3410.58 M1nPt-OSF 19190.01 18972.39 18864.0:' 88.58 13098.77 3410.26 MinPt-OSF 19081.97 18865.44 18757.6 l' 13155.23 3409.11 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 20 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 18284.77 18041 84 17920 871 75.57 14942.53 3396.77 MinPt-O-SF 20715 6411 20483 621 20368 1011 13.9.211 12490.61 3414.39 MinPts SP01SE7(P2)(Def Plan) Pass MEM18264.2' 8 0 6.. E11E. 17345.41 3376.77 MinPts 19787.66 19449.31 19280.6 .MZIE 17640.92 3374.73 MinPts 17852.60 17849.1 -86 . 5202.20 251.10 251.10 MinPts 17852.94 17849.65 17820.1'"I 300.37 300.37 MinPt-O-SF 1946.21 y 57.21 17492.77 3375.74 MinPts 19790.43 19438.52 19263.0 mizEE 18001.83 3372.46 MinPt-OSF 15421.77 15337.53 92.53 9974.81 3162.12 MinPt-CtCt 15591.35 Eme 15337.51 92 52 9975.48 3162.21 MinPt-O-EOU 15591.37 15421.77. 52.51 9976.16 3162.30 MinPt-O-ADP 15668.19 15496.90 15411.7•111.1.4 10040.06 3170.70 MinPt-O-SF mum.man. 18105.81-M.Li', 17347.21 3376.76 MinPts MEM 19453.98' 19285.3'®j 17640.77 3374.74 MinPts 15886.22 15674.98 15569.85 75 55 13088.83 3410.40 MinPts 18950.56 18618.37 57.21 17494.57 3375.73 MinPts 19795.09 19443.18 19267.72 6I 18001.84 3372.46 MinPt-O-SF 21061 82 20692.84 20508.84®' 18512.47 3358.66 MinPt-O-SF 15709 05 El=MERE�l"1 15543.17 3395.41 MinPts 8598 90 .�1I 18110.14 MEE 17349.01 3376.75 MinPts 17852.60 17851.38 17819 80 14584.96 0.00 0.00 Surface 17852.60 17849.1• 17819.801 5226.96 248.10 248.10 MinPts 18954.91 18622.65 18457.01 57.21 17496.37 3375.72 MinPts 19799.74 19447.84 mum 56.42 18001.86 3372.46 MinPts 18603.23 18276.99 18114.36 57.19 17350.80 3376.74 MinPts _18606.66 18299.03 18145.71 60.67 16826.90 3378.75 MinPts _18959.26 18626.9' 18461.25 57.21 17498.16 3375.70 MinPts 19804.40 19452.50 19277.04 56.431 18001.88 3372.48 MinPt-O-SF 17454.04 17085.711 16902.05 47.51 18597.11 3357.54 MinPts 18607.57 18281.25 18118.59 57.19 17352.60 3376.72 MinPts 19273.36 18936.15 18768.03 57.32 17615.12 3374.88 MinPts 18963.61 18631.20 18465.48 57.22 17499.96 3375.69 MinPts 18015.10 17661.86 17485.73 51.14 18129.75 3369.63 MinPts 18147.17 17846.54 17696.72 60.56 16647.48 3379.01 MinPts - 18611.90 18285.51 18122.81 57.19 17354.40 3376.71 MinPts 18147.17 1784645 17696.58 60.54 16650.24 3379.00 MinPts 18967.95 18635.47 18469.72 57.22 17501.76 3375.68 MinPts 19813.71 19461.81 19286.3 56.46 18001.93 3372.46 MinPt-O-SF 18153.25 17834.67 17675.8: 57.16' 17162.96 3378.05 MinPts 18153.25 17834.64 17675.857.15+ 17163.91 3378.04 MinPts 18976.65 18644.02 18478.1. 57.22 17505.35 3375.65 MinPts 18981.00 18648.29 43 57.22 17507.15 3375.64 MinPts 19827.68 19475.78 19300 32, 56.501 18002.03 3372.45 MinP1-0SF 18985.35 1865256 18486.66 57.22 17508.95 3375.63 MinPts 19832.34 19480.43 19304.97 56.51 18002.06 3372.45 MinPt-O-SF L18989.701 18656 84 18490.90 57.22 17510.74 3375.62 MinPts 19836.99 19485.09 1930962 56.531 18002.11 3372.45 MInPt-O-SF L 18994.051 18661.111 18495.1' 57.22 17512.54 3375.60 MinPts 19841.64 19489.74 19314.2: 56.541 18002.15 3372.45 MinPt-OSF r 18646.13 18337.9318184.2'- 60.68 16842.05 3378.73 MinPts Lr 18998.40 18665.3 18499.3 57.22 17514.34 3375.59 MinPts 19846.30 19494.39 19318.9' 56. . 18002.20 3372.45 MinPt-O-SF 15884.99 15673.16 15567.7' 75. ' 13087.37 3410.42 MinPt-O-SF 15874.92 15663.361 15558.071 75.38 13088.42 3410.41 MinPts 15874.91 15663.36 15558.07 75.39 13088.44 3410.41 MinPt-C9Ct 18646.59 18319.61 18156.61 57.201 17368.77 3376.81 MinPts 18650.51 18342.22 18188.56 60.69 16843.73 3378.73 MinPts _19002.75 18669.661 18503.61. 57.22 17516.13 3375.58 MinPts 19850.95 19499.04 19323 581 56.571 18002.24 3372.45 MinPt-O-SF I 15430.34 15301.32 60.80 15550.18 3395.32 MinPt-CtCt 15689.3 per; 15301.30 60.79 15550.46 3395.32 MinPt-O-EOU 15689.40 15430.33 111031.1068 60.79 15550.75 3395.32 MinPt-0-ADP 15730.29 15469.44 15339.51 maiE. 15584.02 3394.91 MinPt-O-SF 16123.26 15857.28 15724.7:Min. 15693.53 3394.56 MinPt-O-SF 16188.44 15919.41 15786. : , 15721.28 3394.52 MinPt-O-SF 17200.30 16918.20 16777.63.11111111(.1 I0 16138.11 3392.79 MInPt-O-SF i 1734476'MIKE 16350.15 3386.57 MinPts 18650.93 18160 84 17370.57 3376.60 MinPts 19007.10 :�•,', 18507.85', 57.22 17517.93 3375.57 MinPts 19855.60 19503.69 193282. 18002.30 3372.45 MinPt-O-SF '�'.�:l 47.33 18902.19 3355.60 MinPts 1111.0=,.[IME 18165.07 1 17372.37 3376.58 MinPts �' irl '.��'''{ 57.22 17519.73 3375.55 MinPts 19860.25 19508.34 19332.88 0 18002.35 3372.45 MInPt-O-SF IL18659.61 :6"9, 18169.29.1111111M, 17374.16 3376.57 MinPts NEEEKE MK= 17594.30 47.28 18986.81 3355.06 MinPts 18250.09 17862.88 17669.76 19029.11 3354.79 MinPt-0-SF 19059.06 18653.50 18451.22 47.11 19438.28 3350.95 TD 19015.79 18682.49 18516.32 57.22 17521.52 3375.54 MinPts 19277 81 18925 51 18749 85 54.8 18018.83 3372.20 MinPts 18663.94 18336.67 18173.52 57.2 17375.96 3376.56 MinPts 19277.80 18940.57 18772.45 57 33 17615.34 3374.88 MinPts 1 19020.141 18686.761 18520 561 57.22 17523.32 3375.53 MinPis 19282.221 18929.921 18754 2711 54.881 18018.51 3372.20 MinPts 18668 281 18340.93 18177.7511 57.201 17377.76 3376.55 MinPts 19282 241 18945.00 18776 8811 57.34 17615.55 3374.88 MinPts 19024 501 18691 041 18524 8011 57.22 17525.12 3375.52 MinPts 19286 631 18934.341 18758 691 54.90 18018.20 3372.21 MinPts 18672 621 18345 191 1.8181 970 57,20 17379.56 3376.53 MinPts 19286 691 18949 441 18781 3011 57.3 17615.75 3374.88 MinPts 19028.851 18695 311 18529 040 57.22 17526.92 3375.50 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 21 of 24 Offset Trajectory Se•aratlon Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct Ift EOU ft Dev.IftL Fact. MD(ft) [TVD(ft) Alert I Minor I Major 19291... 18938.76 18763.11 54.91 18017.88 3372.21 MinPts 18676.'• 18349.46 18186.20' 57.20 17381.35 3376.52 MinPts 19291.1. 18953.8: 18785.74 misim 17615.96 3374.88 MinPts • 19033. . 18899.5' 1853327 57.22 17528.71 3375.49 MinPts 19295.46 18943.1' 18767.54 54.92 18017.58 3372.22 MinPts 18681.3. 18353.7. 1819043=SE 17383.15 3376.51 MinPts 19295.6. 18958.3. 18790 18 mop 17616.16 3374.88 MinPts 19037. 18703.86 18537.51 57.22 17530.51 3375.48 MinPts 19299.8; 18947.6 18771 97 54.94 18017.27 3372.22 MinPts 18685.6 18357.99 18194.65 57.20 17384.95 3376.50 MinPts 19300..• 18962.77 18794.62 57.39 17616.37 3374.88 MinPts 19041.9. 18708.1• 18541.75 57.22 17532.31 3375.46 MinPts 19304.31 18952.05 18776.41 54.95 18016.97 3372.23 MinPts 18689.9 18362.25 18198.88 57.20 17386.74 3376.48 MinPts 19304.5. 18967.22 18799.07 574 17616.57 3374.88 MinPts 18975.91 18657.91 18499 40 59 85 17101.24 3378.34 MinPts 19308.75' 18956.49 18780 85 54.971 18016.67 3372.23 MinPts 18972.3. 18639.7'' 18473.951 57.221 17503.55 3375.67 MinPts 19308." 18971.68 18803.521 57411 17616.76 3374.87 MinPts 19818.3 19486.47 19291.011 56.471 18001.96 3372,46 MinPts 19050.6. 18716,69 18550.23 57.22 17535.90 3375.44 MinPts 19313.1: 18960.93 18785 30 54 98 18016.38 3372.24 MinPts 19059.1. 18744.56 18587.79 60.78 17000.20 3378.50 MinPts 20166.21 19848.57 19690.24 63.68 17080.11 3378.39 MinPts 19313.46' 18976.14 18807.97 57.4. 17616.96 3374.87 MinPts 19054.9 18720.97 18554.47 572 17537.70 3375.43 MinPts 19317.6. 18965.38 18789.75 54.99 18016.08 3372.24 MinPts 19063.5. 18748.90 18592.09 60 78 17001.88 3378.50 MinPts 19317.941 18980 601 18812 4311 57.431 17617.15 3374.87 MinPts 19059.3.! 18725.241 18558.711 57.22 17539.50 3375.41 MinPts 19322.0 18969.831 18794.211 55.011 18015.79 3372.25 MinPts 19067.9. 18753.23 18596.39 60.78 17003.56 3378.50 MinPts 19322.4. 18985.07 18816.90 57. 17617.34 3374.87 MinPts • 19063.6 18729.5.. 18562.95 57.22 17541.29 3375.40 MlnPts 19326,5., 18974.29 18798.67 55.02 18015.51 3372.25 MlnPts 19072.3.1 18757.56 18600.69 60.78 17005.25 3378.49 MlnPts 19326.9. 18989.5 18821.36 57.45 17617.53 3374.87 MinPts 19068,01 18733.;. 18567.18 57.22 17543.09 3375.39 MlnPts 19330.9 18978.7 18803.13 55.03 18015.22 3372.28 MinPts 20685.8' 20386.851 20237.85 69.41 16566.22 3380.24 MinPts 19076.7. 18761.90 18604.99 60.79 17006.93 3378.49 MinPts 19331 3,. 18994 021 18825 841 57.471 17617.72 3374.87 MinPts 19072.36 18738 07 1857142 57.22) 17544.89 3375.38 MinPts 19335.4 18983 22 18807.60 18014.94 3372.26 MinPts 19081.1. 18766.23 18609.28 17008.61 3378.49 MinPts 18998.51 18830 31 17617,91 3374.87 MinPts 19076.71 18742.35 18575.661 57.22 17546.68 3375.36 MinPts 18987.68 18812 07 55.06 18014.66 3372.26 MinPts 19085. . 18770.56 18613.5811 60.791 17010.29 3378,49 MinPts 19340.3 19002.99 18834 79 57.491 17618.09 3374.87 MinPts 19081.06 18746.63 18579.901 57.22 17548.48 3375.35 MinPts 19344.36' 18992.16 18816.5511 55.071 18014.39 3372.27 MinPts 19087.48 18772.51 18615.5211 60.791 17011.05 3378,49 MinPts ' 19007.48 18839.2811 57.501 17618.27 3374.86 MinPIs 19083.0. 18748.55 18581.81 57.22 17549.29 3375.35 MinPts 19348.8 18996.6 18821.93 55.091 18014.11 3372.27 MinPts 19089.9. 18774. 18617.88 60.7.'1 17011.98 3378.48 MinPts 19349.3: 19011.9 18843.76 57.51 17618.45 3374.86 MinPts 19085.41 18750.91 18584 14 57.22 17550.28 3375.34 MinPts 9353 31 19001.1 18825 511 55.101 18013.85 3372.28 MinPts 19094.31 18779.23 18622.181 60.791 17013.66 3378.48 MinPts 19353.88 19016 471 18848.2611 57.521 17618.63 3374.86 MinPts 19089.7711 18588 31 57.22 17552.08 3375.33 MinPts 19357.79 9005 601 18830 0011 55.121 18013.58 3372.28 MinPts 19098.71 18782561 18626.4811 60.791 17015.34 3378.48 MinPts 19358.3' 19020.97 18852.75 57.54 17618.80 3374.86 MinPts 19094.1. 18759.••' 18592.62 57.22 17553.87 3375.31 MinPts 19362.2 19010.0' 18834.49 55.13 18013.32 3372.29 MinPts 19103.11 18787.90 18630.78 60.79 17017.02 3378.48 MinPts 19362 911 19025481 18857.2511 57.551 17618.97 3374.86 MinPts 19098 47 •111111111. ]I 18596 861 57 22 17555.67 3375.30 MinPts 19366 76 19014 58 18838.99 55 14 18013.08 3372.29 MinPts 19107 51 18792 23 18635.08 60 79 17018.71 3378.47 MinPts 19367.421 19029.98 18861 75 57.56 17619.14 3374.86 MinPts 19102.83 18768.02 18601.10 57.22 17557.47 3375.29 MinPts 19371 2511 19019 081 18843 491 55 16 18012.80 3372.29 MinPts 19111.9111 18796.571 18639.381 60.7.1 17020.39 3378.47 MinPts 19371 9511 19034 491 18866.261 57.5 17619.31 3374.86 MinPts 19107 1811187- 91 18605.341 57.22 17559.26 3375.28 MinPts 15375.7511 19023.581 18847.991 55.171 18012.54 3372.30 MinPts 1'-1116.311 18800.90 18643.681 60.791 17022.07 3378.47 MinPts 15376.471 19039.01 18870.771 57.581 17619.48 3374,86 MinPts ®ED= 18609.591 57.22 17561.06 3375.26 MinPts 19380.2' 19028.09 18852.501 55.181 18012.29 3372.30 MIME 8805 23 18647.991 60.791 17023.75 3378.47 MinPts r., 19043.53 18875.291 57.601 17619.64 3374.86 MinPts 18780.85 18613 831 57 22 17582.88 3375.25 MinPts .131a32. 19032 59 18857.0111 55 201 18012.04 3372.31 MinPts mingEE 18809.57 1865229 60 80 17025.44 3378.46 MinPts ECM 19048.05 18879.80 57.611 17819.81 3374.85 MinPts ® 18785.13 1861807 57.22 17564.85 3375.24 MinPts 19389.25 19037.11 18861.53 55.211 18011.80 3372.31 MinPts MEE18813 90 18656591 60 801 17027.12 3378,46 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 22 of 24 Offset Trajectory Se•aration Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft EOU(ft Dev.(ft) Fact. MD(ft) I TVD(ft) Alert i Minor r Major 19390.06 19052.58 18884.33.. 57.621 17619.97 3374.85 MinPts 19124.59 18789.411 18622.31'. 57.22 17566.45 3375.23 MinPts 19393.76 19041.62 18866.04 55.2311 18011.56 3372.31 MinPts 19133.93 18818.24 18660.89 60.80 17028.80 3378.46 MinPts 19394.60 19057.11 18888.85 57.63 17820.13 3374.85 MinPts 19128.95 18793.69 18626 551 57.22 17568.25 3375.21 MinPts 19398.28! 19046.1• 18870.56' 55.24 18011.32 3372.32 MinPts 19138.3 18822.57 18665.19 60.80 17030.48 3378.46 MinPts 19399.1. 19061.6. 18893.38 57.64 17620.28 3374.85 MinPts 19133. $ 18797.97 18630.7• 57.22 17570.05 3375.20 MinPls 19402.7' 19050.66 18875.•• 55.25 18011.08 3372.32 MinPts 19142.73 18826.91 18669.4' 60.80 17032.17 3378.45 MinPts 19403.69'. 19066 17 18897.91 57.66 17620.44 3374.85 MinPts 19137.651 18802.25 18635.$ 57.22 17571.84 3375.19 MinPts 19407.31 19055.19 18879.6. 55.27° 18010.85 3372.32 MinPts 19147.1 18831.25 18673.7$ 60.80 17033.85 3378.45 MlnPts 19408.2 19070.71 18902.•• 57.67 17620.59 3374.85 MinPts 19142.01 18806.52 18639.27 57.22 17573.64 3375.18 MinPts '�'t! 19059.72 18884.15 MIMI 18010.62 3372.33 MinPts 061E; 18835.58 18678.09 60.80 17035.53 3378.45 MinPts NEMO19075.26 18906.98 57.68 17620.74 3374.85 MinPts 19146.36 18810.80 18643.52 57.22 17575.44 3375.16 MinPts MIIMI19064.25 18888.69 55.29 18010.39 3372.33 MinPts 19155.', 18839.92 18682 40 60.80 17037.21 3378.45 MinPts 19417. - 19079.8• 18911 52 57.69 17620.89 3374.85 MinPts 19150.7. 18815.0:1 18647.76 57.22 17577.23 3375.15 MinPts 19420.$$ 19068 7•1 18893.22 55.31 18010.16 3372.33 MinPts 19160. ' 18844.2 18686 70 60.80 17038.90 3378.45 MinPts 19421.$$ 19084. 18916.07 57.70 17621.04 3374.85 MinPts 19155.0 18819.36 18652 00 57.22 17579.03 3375.14 MinPts -19425.43 19073.33 18897.77 55.3 18009.94 3372.34 Min%s 19164.75 18848.59 8691 00 60.8 17040.58 3378.44 MinPts 19426.46 19088.90 18920.62 57.721 17621.19 3374.85 MinPts 19159.43 18823.6• 18656.2• 57.22 17580.83 3375.12 MinPts 19429.97 19077.87 18902.31 55.33 18009.72 3372.34 MinPts 19169.15 18852.92 18695.30 60.80 17042.26 3378.44 MinPts 19431.02 19093.46. 18925.17 57 73 17621.34 3374.85 MinPts 19163.78 18827.9. 18660.49 5722 17582.63 3375.11 MinPts 19434.51 19082.4. 18906.86 55.35 18009.51 3372.34 MinPts 19173. : 18857.26 18699.60 60 81 17043.94 3378.44 MinPts 19435. 0 19098.01. 18929.72 57.74 17621.48 3374.84 MinPts 19168.1, 18832.24: 18664.73 57.22 17584.42 3375.10 MinPts . 19439.4: 19086.96 18911.41+ 55.36 18009.30 3372.35 MinPts 19177.96 18861.64 18703.91 60.81 17045.63 3378.44 MinPts 19440.1 19102.5 18934.28' 57.75 17621.82 3374.84 MinPts 19172.4' 18836.48 18668.97 57.22 17586.22 3375.09 MinPts 19443.64 19091.521 55.38 18009.09 3372.35 MinPts 19182.3 18865.93 18708.21 60.81 17047,31 3378.43 MinPts 19444.7 19107.1' 18938.8'• 57.76 17621.76 3374.84 MinPts 19176.8 18840.76' 18673.21 57.22 17588.02 3375.07 MinPts 19448.1 19096.07 18920.5. 55.39 18008.88 3372.35 MinPts 19186.7 18870.27 18712.51 60.81 17048.99 3378.43 MinPts 19449.30 19111.70 18943.40 57.78 17621.90 3374.84 MinPts 19181.24, 18845.0' 18677.46' 57.22 17589.81 3375.06 MinPts 19452.71 19100.6 18925.0: 55.40 18008.68 3372.36 MinPts 20779.00 20411.2. 20227.8_ 56.65 18455.24 3360.08 MinPts 19191.17, 18874.61 18716.82 60.81 17050.67 3378.43 MinPts 19453.87 19116.271 18947.97. 57.79 17622.03 3374.84 MinPts 19185. : 18849.3 18681.701 57.22 17591.61 3375.05 MinPts 19457.26 19105.19 18929 651 55.4 18008.48 3372.36 MinPts19195.58 18878 94 18721.1 60.81 17052.36 3378.43 MinPts 19458.45 19120.85 18952.5' 57.80 17622.18 3374.84 MinPts 19189.91 18853.61 18685., 57.22 17593.41 3375.04 MinPts 19461.82 19109.76 18934.21 55.43 18008.28 3372.36 MinPts _19199.9:' 18883.28 18725 42 60 811 17054.04 3378.42 MinPts 19483.0'' 19125.42 18957.11 57.81 17622.30 3374.84 MinPts 19194.27 18857.8• 18690.19 57.23 17595.20 3375.02 MinPts 19466.3919114.3.. 18938.7: 55.44 18008.08 3372.37 MinPts 19204.39 18887.6. 18729.7 i 60.81 17055.72 3378.42 MinPts 19467.6219130.04 18961.6: 57.83 17622.42 3374.84 MinPts 19198.63 18862.1 18694.' 57.23 17597.00 3375.01 MinPts 19470.95• 19118.8• 18943.36 55.481 18007.89 3372.37 MinPts 19205.2• 18888.46' 18730.56 60.811 17056.05 3378.42 MinPts 19472.21 19134.58 18966.26 57.84 17622.55 3374.84 MinPts 19199.4 18863.00 18695.25' 57.23 17597.35 3375.01 MinPts 19475 52 19123.47 18947.93 55.47 18007.70 3372.37 MinPts 19208.80 18891.96 18734.03 60.81 17057.40 3378.42 MinPts 19476.80 19139.16 18970.84 57.85 17622.67 3374.84 MinPts 19202.98 18866.4 18698.68 57.23 17598.79 3375.00 MinPts 19480.09 19128.04 18952.51 55.4$ 18007.52 3372.37 MinPt-0-SF IMMIESI15896.311 60.811 17059.06 3378.42 MinPts 19481 39 19143.75 18975.42 57 86 17622.80 3374.84 MinPts 19207.3 18870.74 18702.93 57.23 17600.57 3374.99 MinPts 19484.66 1913262 18957.09 55.5$• 18007.33 3372.38 MinPt-O-SF _ 19217.6. 18900.66 18742.66 60.8. 17060.71 3378.41 MinPts 19485.': 19148. ' 18980.00 57.88 17622.92 3374.84 MinPts 19211.7. 18875.4,1 18707.19 57.23 17602.34 3374.97 MinPts 19489.24 19137.20 18961.67' 55.511 18007.16 3372.38 MinPt-O-SF Ir ! 20859.94 20491.94 20308.36 56.8`211 18468.97 3359.69 MinPts Nikeilchuq 3PB3(Def Survey) Pass 16546.301 18544.3 I 18513.491 9435.58 51.00 51.00 MinPts 1 18547.071 18542.945 4469.09 368.28 388.26 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 23 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft), Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 18547.071 18542.91 18514.26 4450.91 375.56 375.54 MinPt-O-EOU 18547.33 18542.96 18514.52 4243.04 412.33 412.25 MinPt-O-EOU 1.18372.81 1832408 18300.61 391.39 3098.51 2258.06 MinPt-CtCt 18372.82 18324.071 18300.59 391.20 3100.30 2258.33 MinPt-O-EOU 1 18370.20 18321.20 18297.60 389.15 3123.12 2281.58 MinPt-CtCt 18370.20 18321.20 18297.59 389.13 3123.41 2261.62 MinP1-O-EOU 18370.20 18321.20 18297.59 389.10 3123.69 2261.66 MinPt-O-ADP 18897 35 18841.86 18814.99 351.661 3712.62 2339.07 MinPt-O-SF 18947.43 18891.95 18865.08 352.62 3719.10 2339.92 TD 18948.82 18893. •EMIEN.MBE 3719.10 2339.92 MinPts Nikailchuq 3PB2(Def Survey) Pass 'u y 18544.3 IR= 9435.58 51.00 51.00 MinPts 18547.07 18542.9. 1851426 4469.09 368.28 368.26 MinPts 18547.0 18542.91 18514.26 4450.91 375.56 375.54 MinPt-0-EOU 18547.3 18542.96 1851452 4243.04 412.33 412.25 MinPt-0-EOU 1 18372.81 18324.08 18300.61 391.39 3098.51 2258.06 MinPt-CtCt 18372.8 18324.071 18300.59 391.20 3100.30 2258.33 MinPt-0-EOU 1 1837020 18321.20 18297.60 389.15 3123.12 2281.58 MinPt-CtCt 18370.20 18321.20 18297.59 389.13 3123.41 2261.62 MinPt-O-EOU 18370.20 18321.20 18297.59 389.10 3123.69 2261.66 MinPt-O-ADP 18991.05 18935.11 18908.0 350.4 3763.98 2345.82 MinPt-O-SF 18993.45 18937.50 1891041 350.49 3764.89 2345.94 MinPt-O-SF 19040.37 18984.42 18957.33 351.36 3772.88 2346.99 TD 1 19041.561 18985.621 18958.521 351.401 3772.87 2346.99 MinPts Nikellchuq 3PB1(Def Survey) Paw WIDE 18544.3 Ma= 9435.58 51.00 51.00 MinPts 18547.0 18542.9. 18514.26 4469.09 368.28 368.26 MinPts 18547.0 18542.91 1851426 4450.91 375.56 375.54 MinPt-O-EOU 18547.3 18542.96 18514.52 4243.04 412.33 412.25 MinPt-O-EOU 1 18372.81 18324.08 18300.61 391.39 3098.51 2258.06 MinPt-CtCt 18372.82 18324.071 18300.59 391.20 3100.30 2258.33 MinPt-O-EOU 1 18370.20 18321.20 18297.60 389.15 3123.12 2261.58 MInPt-CtCt 18370.20 18321.20 18297.59 389.13 3123.41 2261.62 MinPt-O-EOU 18370.20 18321.20 18297.59 389.10 3123.69 2261.66 MinPt-O-ADP 18991.05 18935.11 18908.02 350.49 3763.98 2345.82 MinPt-O-SF 18993.45 18937.50 18910.41 350.49 3764.89 2345.94 MinPt-0SF 19040.37 18984.42 18957.33 351.36 3772.88 2346.99 TD 1 19041.561 18985.621 18958.521 351.41 3772.87 2346.99 MinPts Nikailchuq 3(Def Survey) Peas 18546.3 18544.33 18513.4 9435.58 51.00 51.00 MinPts 18547.07 18542.9 18514.26 4469,09 368.28 36826 MinPts 18547.07 18542.91 18514.26 4450,91 375.56 375.54 MinPt-O-EOU 18547.33 18542.96 18514.52 4243.04 412.33 412.25 MinPt-O{OU I 18372.81 18324.08 18300.61 391.39 3098.51 2258.06 MinPt-CtCt 18372.82 18324.071 18300.59 391.20 3100.30 2258.33 MinPt-O-EOU I 18370.20 18321.20 18297.60 389.15 3123.12 2261.58 MinPt-CtCt 18370.20 18321.20 18297.59 389.13 3123.41 2281.62 MinPt-O-EOU 18370.20 18321.20 18297.59 389.10 3123.69 2261.66 MinPt-O-ADP 18897.35 18841.86 18814.99 351.661 3712.62 2339.07 MinPt-0SF 18947.43 18891.95 18865.09 352.62 3719.10 2339.92 TD 19686.58 19631.7 196052 371.02 2996.56 2239.36 MinPt-O-ADP 19686.52 19631.76 1960525 371.40 2997.98 2239.67 MinPt-O-EOU 1_19686.46 19631.81 1960537 372.18 3000.83 2240.28 MinPt-CtCt 19680.52 19627.161 19601371 381.42 3039.27 2248.00 MinPts 19680.50 19627.17 19601.38 381.57 3039.98 2248.14 MIOPI-CtCt 18948.82 18893.341 18866.47 352.661 3719.10 2339.92 MinPts Nikailchuq 4(Def Survey) Pass 18587.Or 18585.1 MIME 9456.73 51.00 51.00 MinPts 155876• .1.'• -' 18554.83 6519.21 165.92 165,92 MinPt-O-EOU 18588.4 18584.1 ..11=2. 4318.14 408.88 408.80 MinPts 18588.7• --.'1 18555.93 3824.10 454.17 453.95 MinPt-O-EOU 18590.0.Ea= 18557.19 3150.41 515.55 514.92 MinPt-O-EOU 18366.48 18343.69 404.04 3000.64 2240.24 MinPt-CtCt 18413.86 EMU 18343.68 403.89 3002.11 2240.55 MinPt-O-EOU 18413.86 18366.47 18343.68 403.85 3002.48 2240.63 MinPt-O-ADP 20988.92 2088032 20826.90 MEM 6043.44 2845.41 MinPt-O-SF Nikailchuq 1(Def Survey) Pass 1 18490.17 1844445 1842247 420.62 2894.03 221391 MinPt-CtCt 18490.17 18444.44 18422.45 420.47 2895.05 2214.19 MinPt-O-EOU 18490.19 1844444 1842245420.32 2896.06 2214.48 MinPt-O-ADP 24564.17 24477.67 24435.29 289.851 5389.06 2559.41 MinPt-0SF Nikaitchuq 2(Def Survey) Pass 19150.63 19146.87 19117.82 5096.17 295.00 295.00 MinPts 19150.63 19146.85 19117.82 5073.26 29941 299.40 MinPt-O-EOU 19150,99 19147.19 19118.1: 5036.6. 341.21 34120 MinPt-0SF 19153.37 19149.45 19120.56 4890.7. 386.63 386.60 MinPt-OSF 19811.50 19789.05 19778.6.NEM 837.70 827.27 MinPt-OSF 20350.95 20319.30 20304.••Mr= 1000.42 977.15 MinPt-OSF 20905.37 20872.08 20856.3- 666.2• 1181.07 1117.73 MinPt-O-SF 21194.55 21160.92 21145.0 668.3. 1242.97 1186.06 MinPt-O-SF 21428.07 21394.09 21378.06 ? 1304.92 1236.07 M1nP1-OSF 22004.05 21969.04 21952.4•=ME 1446.24 1344.36 MinP1-0SF 24790.92 24744.99 24722.98=MED 2388.87 1996.06 MinPt-O-SF 24877.87 24831.80 24809.7.MEM 2400.89 2002.93 Min%-0SF 24930.61 2488444 24862.31 MEM 2408.07 2006.99 MinPt-0SF Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 24 of 24 Schlumberger TRAVELING CYLINDER PLOT 1 Client: ENI 1 NoGo Region EOU's based on: Well: 0120-07 Oriented EOU Dimension N Field: Nikait chug Structure: Oliktok Point NoGo Region Anti-Collision rul: 411 w A 411 Date: September 27,2011 used:Minor Risk-Separation —"mir Allimb.— Factor 1r4 0 to 900'md North OP23-WW02 Fails 350 0 10 340 Appr" 20 330 Ilf r 60 i 30 320 ... 40 , 310 #21.---4-...v., 100-• 4' \ ',' 6.0 300 , - , •,,,, 6%;II,P•11- .V41#4lik N4i* '1,11133-6/33(R) 290 . iiiilLs' Aillk\•_ , 'i, illide(fil j,ti 1,,iiik01211.,i1g,\.';010. ..... ,or p5s "' - 1 i 'P AYI l'ArfliiiPrirliliV\ .111P4r. ' VOrieri‘ ' i"tlri, A 4 Aitopoof;,,tirrkia-w.%!...\':-,,,A 280 t'4.6;-4..-i_=l41e1.4.0.W-.4. 4. i1 1;4 W.' •4.40- ao ,ftt, \y kik marik im!ini • 1,1ii.I. ', im v •. ••; ' ------- -,..._ _ " 'NA0,814tItitalIVVVVIptik •latil , 4 , 270 .- Ifr , rOM•=, ...,... \ , i ... ,. ..1 lzaillitgAL AA.\\:4,471.:7,..-t214... it,Tts.4 .i.,,i,:lik,•14tr..1/40.2f:liel'n ;1 \ \0\111 lir ' Al 14 • . '-----7' i 14MAIIiiiiKs7:4441:** ,--pi-i) 100 V ( ,,,, itko 34.4\ *imil_Iviiilli--- 250 f /4 ,! \1111111111111111 ,411k 414P4 02P B 1 240 \ 4V V-Itttailf,A41110 If k • N\,0*-- 20 ilq!likkl :-.....000°.." . 14411L O 1711117'9b112W OP23-WW02 230 A**„„munir _,.. kilibloisops rr130 ,...- NIIIIritsw-- 220 00461(143) 210 201111111111er 160 lan •-- 170 • Well Ticks Type: MD on 0120-07(P14) _ Calculation Method: Normal Plane Ring Interval: 10.00 ft Azimuth Interval: 10.00 deg Scale: 1 INCH=20.00 ft 1 Schlumberger TRAVELING CYLINDER PLOT Client: EN! NoGo Region EOU's based on: Well: 0120-07 Oriented EOU Dimension N Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anti-Collision rule Date: September 27,2011 used:Minor Risk-Separation --moir Factor 0 to 900'md North OP23-WW02 exeption 350 0 10 340 r 20 330 60 ' 30 111 Air":4, ,Zik, 40 ...-- ,.• ------ AmP Am Vta......./.01010 ....00/40.--Ani ii, ofamm.-.•74;', 4 zA15-3-0:in,t., 310 320 1 ir ,; 4-1444±;;;4:41r..41111;ttilir 290 "3 44#1:411k 'Ii if fililifiriklif,1itirtiti'':‘‘\ - ( $, t4/1 i itl 4 PRO%glifricjit V''. 280 *it:11,t"'"2.---'-' 1'-IrNWP'eo•-litS1 F, i , .''‘.-11,1,::.„% 80 . *04041.41'61 :0‘10$'S ifglik 0 4 64 40001111111ftri N,k\i'ilpa.V.4.'0 t, A ,A' iiiffAt 270 Arff . 40111r*AA .‘N‘VNLIfi,AAI'4% q4V/ Of 9° o g •• , - N IIW ii" . 111, ftr,,Mitira -_vddii.- if illftli•mit v 41111111.W.W.'41 ' Of 1 p 410 V Vallomsyi All& t 250 . os / ii1PV '\Willito:41 ''') -14, OP17-02PB1 ark. 240 V, ,,:,10;,/'1 If Nfloillgair20 230 OP23-VWV02 410111 1 "•%._--1.1,14. 130 2,0,., ...„,150 200 anal 160 in ibn Well Ticks Type: MD on 0120-07(P14) Calculation Method: Normal Plane Ring Interval: 10.00 ft 1 Azimuth Interval: 10.00 deg Scale: 1 INCH=20.00 ft Schlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: 0I20-07 Oriented EOU Dimension N Field: Nikaitchuq Structure: Oliktok Point oGo Region Anti-Collision rul: A ' Date: September 27,2011 used:Minor Risk-Separation Factor �4 900'to 13-3/8" North 350 0 10 340 ��-II- .• 20 330 \\\\`,;/:: , 30 Vr. i•' �a.�- cr� 3201101 � � � �sSR\�. 40 !O•, ,011 tel�voll ,P.,•• 13-03(P6) 310 0. lop ,/::/i:�: �� -, !...1.......,,_-...=,.-.,-.::�� �� �� 50 300 iI(/ V4-alltew"/Aderoh o:r�; �\ ���%� ��-1,'� 60 290 ::?Pkiiiillb. I, 1, 01 -S4 PS t s,.. illiier*Npa ;,I 00..,„..„441% 4 280 araparif"/111040111L. \,\,,,, portz-i,,,i,.-:,--,,,,,- i4j i 80 iriitykasP14-S3 o A 260 0� 4 �r10) (IP ., 1, 100 o Off! f:. e 9p2 O� Z.(eirril%k 250 �� * 1 o ,.._ „...„..44.7110 ..„..: �� ��, �,1�i�� 1 ., � ape ' '•,„_i K.= 4JP23-WW02 240 ,‘►•4�� �R,4 ♦ (itif;,:f:Orri°6-03 le. 230 /'�. ��� , 11. ,01, OP17-02PB1 0 220 441111110"111,0,* • 140 ii►.� �210 ,v =1-- 200 ,�� Alliti 160 190 180 01241e(P9) Well Ticks Type: MD on 0120-07(P14) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%50.00 ft 1 Schlumberger TRAVELING CYLINDFR PLOT Client: ENI NoGo Region EOU's based on: Well: 0120-07 Oriented EOU Dimension Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anti-Collision rule . = Date: September 27,2011 used:Minor Risk-Separation Factor *4 13-3/8"to 9-5/8" North 350 0 ‘,,9..10 340 Nif.W. i. 330 30 N)NnAt ,e11110 320 •/ l� g,\1 `i` 40 1111111111111P4 50 310 el* , L�,`fit�� �, 1‘NOW 41144444 4, 111.,k 300840" NorthIIPf4trp,A„„ 60 Ilirlia \ NAIllopp„ 290 .kil 120 \40#.4.000-?, ` 70 100 ` 1 / " ,,,,,, 280 60 ��yrillirial 80 1iiiht1ifY! 40 \ likiF011011 .....17: -.;270 0‘; oti • \`I17 ! 90 11111 II260 •' , fli $ Ø44i __ 4 o� mac' •♦101, � ��\\\ 250 0� c° 110'.1 7:��.4►�f!C- _\-110 0 ,--, lart i ; : __.__ __- 240 c. ` � / / _— 120 lkir.. / % , __ 230 1140 / ••47... ----__-n--_,:-- 130 * 4ft - 1 :411'- - --- -;- --' / / .i� 16-03 220 / i ,/ ii 1�B 21 / ....:. . ./ �5 200 i�l,',���'lI//11I////ia- 160 1901Rn 170 Well Ticks Type: _ MD on 0120-07(P14) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=100.00 ft Schlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: 0120-07 Oriented EOU Dimension N Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anti-Collision rule Date: September 27,2011 used:Minor Risk-Separation --"Iiir.ilir Factor 9-5/8"to TD North 350 0 10 340 320 20 330 ! 300 aw`30 Wi 260 320 260 40 240 ' 310 iso, 220 ` 50 200 4tIkt* ,• 180 Sit 300 , , 60 • • 161 , i It 4140 '0 , 290 *WW1♦. 120 ®• 70 .. - 100 �, 44 • 80 ; ♦.' 280 if. ♦ $ 60 f ♦ 80 101111111 �111111l a `` `20 ••• 11111 1 270 i■� lit`�44111111111111 r■//, 90 260III"Ilittileirs r � ,Oo 1 OS A4 limo,t '1® ♦ W441/1116: �t!n �1l 250 t. 40®®•ira■•• os.„,, Alp ,otiti. • t 1,0 240 \*11,h • o� w, s * 4k ♦ � �, 120 23044i ••ØØ,Ø `rar► 220 � �� O'1111 140 210 111111MIL � 200 1111.111111111160 190 iRn 170 Well Ticks Type: _MD on 0120-07(P14) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=100.00 ft ,-- N m ,— CO 0 c0 0 m CL d M N CL 4 m al p0 M d N M COM d p O O O' p' V •-•O . 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O ..O rr I 00 Y m N • .Ai 'III 2 ,g q 7 •pale it tr z 3 • •0 esf • CI'L V ,Q 41 6/Qlj r£ • • lk„ V ,At At .. 511,1 •O� O/1' `I6Ft ••O^ p m //sF • O O^ytg,, •s s r10 5 01N— O . . �£ ��� ! • o • aO /fit N •Ql�e �•pOr cs, �G rf 0 o LL 0 ^'F 8/r 9 O :,,/,+26.2£F 1 r _0 c '44 p8b 4-i°8£F • 8/£ CL F • (14 c4te • f '£ o .'•fin ' • _�C�4,_ O :it.. CW o Vi % o o sr r-- a E » • a'1.eo •r �ff • Nd 6o d. glegff O 6), d O "3Oil*� Q.` to O ire, O O _ O g co co1 O 1— O O O o N_ O «< N (34)000Z:(u!)L = 9IBOS S >>> MINloner 0120-07 (P14) Anti-Collision Summary Report Analysis Date-24hr Time: September 28,2011-14:51 Analysis Method: Normal Plane Client: ENI Reference Trajectory: 0120-07(P14)(Def Plan) Field: Nikaitchuq Depth Interval: Every 5.00 Measured Depth(ft) Structure: Oliktok Point Rule Set: D&M AntiCollision Standard S002 v5.1 Slot: OP20 Min Pts: All local minima indicated. Well: 0120-07 Borehole: 0120-07 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Global within 60448.78 ft Selection filters: Definitive Surveys-Definitive Plans-Definitive surveys exclude definitive plans -All Non-Def Surveys when no Def-Survey is set in a borehole-All Non-Def Plans when no Def-Plan is set in a borehole Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major OP23•W W02(Def Survey) Fail Major 23.96 22.74 4.57 18.58 0.00 0.00 CtCt<=15m<15.00 Enter Alert 22.13 19.73 2.7•ME.' 344.37 344.36 MinPt-O-SF 19.24 16.04 -0.15 5.62 439.98 439.82 SfcRul<5.91 Enter Major 16.57 11.22 -282 2.87 524.71 52400 MinPts 16.97 10.82 2 42 2.56 549.40 548.41 MinPt-O-EOU 17.67 11.10 -1.73 Elgj 56415 562.97 MinPt-O-SF 19.15 12.19 -0.24 2.58 583.75 582.28 SfcRul>5.91 Exit Meijer 48.33 40.41 28.93 5.95 731.96 726.61 CtCt<=15m>15.00 Exit Alert 817.52 804.20 798.1 eel 1920.10 1684.42 MinPt-O-SF 1209.52 1187.38 1176.9.eeee 0 2248.09 1910.09 MinPt-0SF 9631.41 9593.13 9574.48 258.18 3452.83 2304.93 TD OP21-W W01(P3)(Def Plan) Warning Alert 7.95 6.73 1.35 5.50 0.00 0.00 CtCt<=15m<15.00 Enter Alert 7.66 4.72 1.05 2.19 345.09 345.08 MinPts 7.77 4.63 1.17 2.09 370.09 370.06 MinPt-O-EOU 7.93 469 1.33 NEMO 380.07 380.04 MinPt-O-SF 8.85 5.25 2.2 eeeet 404.97 404.90 MinPt-O-SF 48.75 41.82 38.96 8.33 597.60 595.89 CtCt<=15m>15.00 Exit Alert 1833.87 1814.18 1804.• IIMMEI 2160.13 1851.37 MinPt-O-SF 9059.57 9027.76 9012.35 293.89 2772.02 2175.10 TD OP22-W W03(P1)(Def Plan) Warning Alert 15.91 14.67 2.93 11.83 0.00 0.00 CtCt<=15m<15.00 Enter Alert 1191 996 0.94 3.20 435.44 435.30 MinPts 14.07 9.84 1.10 3.04 450.38 450.17 MinPt-O-EOU 14.74 10.16 1.77 eel 470.22 469.92 MinPt-0-SF 48.75 40.69 35.78 5.89 643.37 640.72 CtCt<=15m>15.00 Exit Alert 1667.04 1643.65 1632.58 1336 2470.33 2041.06 MinPt-O-SF 9218.27 9155.89 9125.19 150.14 4885.42 2493.21 TD ' 15.911 13.251 2.931 5.531 250.00 250.00 CtCt<=15m<15.00 Enter Alert 0124-08(P9)(Def Plan) Warning Alert 31.87 30.65 6.13 25.04 0.00 0.00 CtCt<=15m<15.00 Enter Alert MEM 24.831 3.97 5.83 512.35 511.75 MinPts 35.52 18.30 9.781 1.991 743.28 737.49 MinP1-0SF 38.21 17.92 8.38 1.94 788.18 780.40 MinPt-O-EOU 39. 17.92 7.88 1.89 803.12 794.60 MinPt-O-EOU 48.87 19.65 6.661 1.761 897.46 883.09 MinPte 153.27 121.53 10628 4.98 1582.93 1443.86 OSF>5.00 Exit Alert 325.27 278.92 256.3'Nimgc 2502.81 2057.99 MinPt-0SF 383.71 327.09 299.26 M.n 2971.09 2233.65 MinPt-0SF 598.37 523.94 487.2. 8.1' 5355.08 2554.94 MinPt-O-SF 570.13 503.671 470.9 8.69 5982.93 2637.46 MinPt-O-ADP 567.7 503.271 471.40 8.91 6095.75 2652.29 MinPt-0-EOU 565.71 505.19 475.42 9.49 6341.00 2684.52 MinPt-CtCt 914.59 752.72 672.2 aZICE 8705.69 2995.32 MinPt-OSF 3357.24 3063.54 2917.1 a MEM 12515.75 3414.26 MinPt-0SF 31.87 29.24 6.13 11.63 250.00 250.00 CtCt<=15m<15.00 Exit Alert 3293.05 2994.13 2845.16 Man 13321.33 3402.66 MinPt-O-SF 3329.46 3027.58 2877.1'MOM 13578.30 3391.25 MinPt-0SF =ME e4.P.1V0 2877.31 11.08 13764.09 3391.14 MinPts 2949.49 2541.21 2337.56 7.24 16837.24 3378.73 TD MOE 3061.11 2914.79 11.46 1251143 3414.28 MinPt-CtCt 0P18-09PB1(Def Survey) Warning Alen 24.04 22.82 4.57 18.64 0.00 0.00 CtCt<=15m<15.00 Enter Alert 1 19.78® 7.19 338.06 338.06 MinPts 22.891 3.42 6.80 367.88 367.86 MinPt-O-EOU 26.3.1 6.85 4.65 512.08 511.49 MinPt-O-EOU 31.1.® 11.62 3.05 636.55 634.07 MinPt-0-EOU 34.8.MM. 15.3.1111ME 706.32 701.89 MinPts 50.53 24.7,MOM 2.01 895.61 881.37 MinPt-O-ADP 51.06 2492 12.46=K6'3 900.58 885.98 MinPt-0SF 142.58 109.56 93.72 446 1335.83 1260.47 TD OP18-08P82(Def Survey) Warning Alert 24.04 22.82 457 18.64 0.00 0.00 CtCt<=15m<15.00 Enter Alert 22.78 19.78 3.31 7.19 338.06 338.06 MinPts 22.89 19.70 3.42 6.80 367.88 367.86 MinPt-O-EOU 26.3= 6.85 4.65 512.08 511.49 MinPt-O-EOU 31.10 21.31 11.62 3.05 636.55 634.07 MinPt-O-EOU Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 1 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dee.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 34.82 21.67 15.35 2551 706.32 701.89 MinPts 50.53 24.74 12.46 2.01 895.61 881.37 MinPt-O-ADP 51.06 24.92 12 46 2 001 900.58 885.98 MinPt-0-5F 163.04 129.43 113.23 5 00 1719.41 1542.07 OSF>5.00 Exit Alert 172.51 137.02 119.88 5 00 1868.78 1848.25 OSF<5.00 Enter Alert 190.42 149.45 129.57111111111101751 2195.12 1675.17 MinPt-O-SF 191.33 150.18 130.19' 2206.82 1883.00 MinPt-O-SF 227.50 181.01 158.38 5.00 2511.76 2062.55 OSF>5.00 Exit Alert 691.27 594.85 547.1- E 4713.58 2470.83 MinPt-O-SF 1256.18 1083.42 997.53 MEM 7698.90 2862.99 MinP1-0-SF 1543.01 1327.12 121967. 9328.53 3077.18 MinPt-O-SF 1610.59 1384.76 1272.331® 9702.43 3128.32 MinPt-O-SF 1754.51 1508.47 1385 94 8 10458.81 322573 MinPt-O-SF 1949.84 1677.32 1541.56® 11449.52 3355.94 MinPt-0-5F 2196.68 1901.79 1754.84® 12510.01 3414.29 MinPt-O-SF 2221.72 1920.49 1770.37® 13106.43 3410.13 MinPt-0SF 2221.10 1920.2 wiguEz 7.40 13231.19 3406.73 MinPt-O-ADP 2195. 13577.01 3391.26 MinPts 1808.47 1445.76 1264.89 5.00 15592.63 339481 OSF<5.00 Enter Alen 1806.7' 1441.70 1259.64 4.96 15653.54 3394.62 MinPt-CtCt 1807.7x lEjMEEI 1257.66 4.94 15708.52 339454 MinPt-0-EOU 1808.95 1440.r r MIME 4.93 15733.48 339450 MinPt-O-ADP 1843.6 614*.0I 1257.01 4.72 16355.26 3386.42 MinPt-O-EOU 1844.84 1452.46'ME yy 4.71 16380.17 3385.69 MinPt-O-ADP 1866.73 1466 98 1267.6t 16576.28 3379.97 MinPt-O-SF 1974.22 1535 55MMAZI, 4.51 17616.97 3374.87 MinPt-O-ADP 1984.07 1540 65 1319 43173 17723.00 3374.27 MinPt-O-SF OP18-08(Def Survey) Warning Alen 24.04 2282 4.57 18.64 0.00 0.00 CICt<=15m<15.00 Enter Alert ® 19.78 EMEED 7.19 338.06 338.06 MinPts 22.89®' 3.42 6.80 367.88 367.86 MinPt-0-EOU 26.32IMEE 6.85 4.65 512.08 511.49 Min%-O-EOU 31.1 r'® 11.62 3.05 636.55 634.07 MinPt-O-EOU 34.8.i® 15. 706.32 701.89 MinPta 50.53 24 74nomm 2.01 895.61 881.37 MinPt-O-ADP 51.06 24.92 12.46=IBM 900.58 885.98 MinPt-O-SF 163.04 129.43 11323 5.00 1719.41 1542.07 OSF>5.00 Exit Alert • 172.51 137.02 119.88 5.00 1868.78 1648.25 OSF<5.00 Enter Alen 190.42 149.45 129.5 MEE 2195.12 1875.17 MinPt-O-SF 191.33 150.16 130.1.i0 2206.82 1883.00 MinPt-0.5F 227.50 181.01 158.38 5.00 2511.76 2062.55 OSF>5.00 Exit Alert 691.27 594.84 547.1.j® 4713.58 2470.63 MinPt-O-SF 1256.18 1083.40 997. r® 7698.90 2862.99 MinP1-0SF 1543.01 1327.10 1219.6 j 9 9328.53 3077.18 MInPt-O-SF 1610.59 1384.73 1272. r UMW 9702.43 3126.32 MinPt-OSF 1754.51 1508.44 1385.1 r 0 10458.81 3225.73 MinPt-OSF 1949.84 1677.29 1541.51 MEC1II 11449.52 3355.94 MinPt-OSF 2196.68 1901.76 1754.7`r® 12510.01 3414.29 MinPt-0SF 2221.72 1920.48 1770.3. 13106.43 3410.13 MinPt-O-SF 2221.10 1920.1'MUM. 7 40 13231.19 3406.73 MinPt-O-ADP 2195.0 1891.8•ME .IIMEO 13577.01 3391.26 MinPa 1808.73 1446.17 1265.38 500 15588.45 3394.85 OSF<5.00 Enter Alen I 1806.79 1441.66 1259.58 4.96 15653.54 3394.62 MinPt-CtCt . 1807.79 1440.67 1257.60 4.93 15708.52 3394.54 MinPt-O-EOU 1808.95 1440.92 1257.34 493 15733.48 3394.50 MinPt-O-ADP 1843.671 1452.20 1256.95 4.72 16355.26 3386.42 MinPt-O-EOU 1844.84 1452.42 1256.7 4.71 16380.17 3385.69 MinPt-0-ADP 1866.40 1463.47 1262.4 4.64 16678.67 3378.96 MinPt-0-ADP I 1994.8 1536.91 1308.44 4.36 1821571 3367.11 MinPt-CtCt 1996. r MEMO 1304.73 4.33 18300.55 336462 MinPt-0-EOU 1998.69 1535.''Mr r9' 4.32 18340.47 3363.45 MinPt-0-ADP ' 2008.51 1540.33 1306.7 '1. 18455.26 3360.08 MinPt-O-SF MEM MEM MIME EMIE 19438.28 3350.95 MinPts OP17-02PB1(Def Survey) Wanting Alert 3205 30.82 6.18 25.18 395 3.95 CtCt<_15m<15.00 Enter Alert 31.04 28.21 5.18 10.53 288.61 288.60 MinPts 31.18 28.11 5.31 9.75 313.39 313.39 MinPt-O-EOU 41.72 36.24 15.86 474.40 474.08 MinPt-O-SF 49.07 42.73 23.21 7.54 527.15 526.41 CtCt<=15m>15.00 Exit Alert 51.35 44.73 25.49 7.5 541.45 540.56 MinPt-0SF 85.33 75.21 59.4 8.31 712.32 707.68 MinP1-0SF 362.82 344.97 336.75` 20 48 1478.77 1368.16 MinPt-OSF 648.42 630.83 622.56 36.79 2320.25 1955.43 MinPt-0SF 662.32 645.26 636.45` 38.76 2762.09 2171.54 MinPt-O-SF • 628.91 611.95 603.04 37.03` 3038.13 2247.79 MinPt-O-SF I 627.71 610.841 601.87 37.08 3085.60 2256.06 MinPt-0-EOU 627.7 610.'0""11 601.87 37.09 3089.15 2256.62 MinPts 631.24 613.70 605 38 35.9 3237.44 2276.62 MinPt-O-SF 1225.72 1095.98 1031.60 9.51 7319.54 2813.13 MinPt-O-SF 4511.66 420974 4059.22 14.99 14128.61 3390.56 MinPt-0-ADP IEME 3451.49 3230.59 8.81 17896.00 3373.30 MinPt-CtCt 3720.85 3245.34 3008.08 7.84 18919.91 3355.48 TD 3889.65 3443.61 3221.0 � 18049.96 3371.62 MinPt-O-SF 0113-03(P6)(Def Plan) Warning Alen 1 64.06 61.66 60.96 44.65 250.00 250.00 MinPt-CtCt 64.10 61.57 60.79 40.67 279.67 279.67 MinPt-0-EOU 64.12 61.57 60.791 40.30 284.61 284.61 MinPt•O-ADP 128.80 10224 89.45 5.00 984.71 962.99 08F<5.00 Enter Alen 131.65 104.44 91.33 998.91 975.80 OSF>5.00 Exit Alert 5837.00 5570.36 5437. ' 11447.74 3355.71 MinPt-0SF 6109.90 5830.73 5691 6.131115 12100.01 3407.80 MinP1-0-SF Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 2 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor AMR Status , Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 6173.71 5891.55 5750.96 21.95 12325.01 3415.22 MinPt-O-SF 5650.01 5267.37 5076.49 14.80 17001.29 3378.50 MinPt-CtCt 608624 579416 564861 20.90 13340.83 3401.61 MinPt-O-SF I6086.14 5794.061 5648.51 20.90 13358.19 3400.60 MinPts 5512.62 5094.77 4886.35 1322 18111.07 3370.16 MinPt-O-SF 5445.19 5014.63 4799.84 12.67 18474.86 3359.53 MInPt-OSF 5259.01 4793.92 4561.87 11.33 19438.28 3350.95 TD 6244.531 5960.671 5819.231 22.071 12624.09 3413.73 MinPts 0115-04(P5)(Det Plan) Warning Alert 48.02 46.80 15.21 38.23 0.00 0.00 CtCt<=15m<15.00 Enter Alert 48.02 45.38 15.21 17.74 250.00 250.00 MinPts 48.10 45.29 1529 16.68 279.75 279.75 MinPt-O-EOU 49.14 48.01 16.33 15.29 363.83 363.81 CtCt<=15m>15.00 Exit Alert 97.90 77.34 65.09 4.70 869.33 856.91 OSF<5.00 Enter Alert 101.86 79.66 69...NEM 89283 878.79 MinPt-O-SF 191.70 142.64 118.72 NEM 1290.36 1224.45 MinPt-O-SF 248.97 196.34 171.63 4.97 1465.28 1358.31 OSF>5.00 Exit Alen 8832.21 8361.87 8227.2.MEM 11513.83 3363.80 MinPt-O-SF 48.02 45.38 15.21 17.74 250.00 250.00 CtCt<=15m<15.00 Exit Alen 8725.13 8424.20 8274.2 29.0 13585.05 3391.24 MInP1-0-SF 8723.73 8423.020 8273.16 29.10 13820.28 3391.19 MinPt-O-ADP 8723 6 8423 01 8273.17 29.11 13623.79 3391.19 MinPt-O-EOU 1 8723.6 8423.07 8273.30 29.12 13634.34 3391.18 MinPt-CtCt 8723.11 8425.50 8277.1•MEM 13365.69 3400.15 MinPt-0SF MMgEl 8096.63 789308 20.89 16923.61 3378.61 MinPt-CtCt 8502.75 8087.67 7880.61 MEM 17143.14 3378.18 MinPt-O-SF 8436.18 7987.25 7763.2.MIEM 18023.28 3372.12 MinPt-0SF 8348.63 7862.54 7619.98 1721 19088.94 3354.24 TD 9030.r,jjlt M ifIE 12823.68 3413.73 MinPts 0P16-03(Def Survey) Warning Alert 40.03 38.81 7.76 31.71 0.00 0.00 CtCt<=15m<15.00 Enter Alert 40.03 38.52 7.76 25.60 114.11 114.11 MinPts 40.33 37.73 8.05 15.09 278.91 278.91 MinPt-O-EOU 45.35 41.84 13.0:ming 447.87 447.48 MinPt-O-SF 48.87 45.09 16.60 12.60 494.90 494.44 CtCt<=15m>15.00 Exit Alert 76.76 68.98 44.4•Ial 758.16 751.75 MinPt-O-SF 167.53 153.36 135.26 inFE 1389.29 1301.74 MinPt-O-SF 340.37 315.87 304.2.(jib 2204.23 1881.28 MinPt-0SF 395.78 368.98 356.11 MEM 2581.02 2096.34 MinP1-0SF (1B 411.63 393.79 1253 3431.11 2302.07 MinPt-CtCt =ma 397.47 372.88 908 4094.89 2389.31 MinPt-CtCt ZEE 39280 36606 8.34 4294.61 2415.56 MinPt-CtCt =OM 360.39 323.36 5.87 5349.05 2554.15 MinPt-CtCt 437.90 349.50 305.79 5.00 5868.39 2622.41 OSF<5.00 Enter Alert 341.33 294.90 4.68 6113.31 2854.60 MinPt-CtCt mow 334.47 284.46 4.34 6433.20 2898.64 MinPl-CtCt 442.0 .1111113117 276.09 4.01 6727.55 2735.33 MinPt-O-EOU =105E. 284.54 213.93 3.02 8011.21 2904.04 MinPt-CtCt 269.21 188.91 2.68 8665.75 2990.07 MinPt-CtCt 321.20 167.62 91.3. SIIE 9719.09 3128.51 MinPt-O-SF 303.13 159.8 88.6 2.12 9798.32 3138.92 MinPt-O-ADP 283.71 NEM 93.07 2.24 9885.10 3150.33 MinPt-O-EOU mem 170.39 131.70 3.20 10132.81 3182.89 MinPt-CtCt 289.! =-E 74.27 2.02 10334.42 3209.38 MinPt-O-EOU 314.10 150.3. 68.8r 1.92 10389.36 3216.60 MinPt-0-ADP 340.21 160.96 71.83 11E1 10439.74 3223.23 MinPt-O-SF 1417.83 1133.31 991.64 5.00 12182.08 3412.90 OSF>5.00 Exit Alen 1477.16 1180.76 1033.05 5.00 13752.69 3391.14 OSF<5.00 Enter Alen 906.7 518.04 324.17 2.34 16414.95 3384.68 MinPt-CtCt 910.81 516.211 319.40 2.31 16564.93 3380.28 MinPt-O-EOU 916.20 517.4 318.61 2.30 16693.75 3378.94 MinPt-O-ADP 922.68 520.52 319.9 2.3 16780.62 3378.82 MinPt-O-SF 1137.14 689.30 465.8 2. 17939.58 3373.05 MinPt-O-SF 1150.0, 689 2, 459.32 2.50 18392.70 3361.91 MinPt-O-EOU 1153.51 690.0 (a5!Emu 18452.51 3360.16 MinPts 1158.6 693.96 462.11 2.50 18612.64 3357.45 MinPt-0-EOU 1161.68 694.5 maw 2.49 18867.35 3357.10 MinPt-O-ADP 1174.94 700.78 464.1•EMU 18828.75 3356.07 MinPt-O-SF OP14-S3(Def Survey) Pass 55.86 53.58 23.05 23.91 243.97 243.97 MinPts 55.88 53.52 23.07 23.18 283.83 263.83 MinPt-O-EOU 56.02 53.61 23.21 22.76 293.54 293.54 MinPt-0SF 56.23 53.81 23.42 22.71 318.30 31829 MinPt-O-SF 118.30 100.36 85.49 6.53 900.71 886.09 MinPt-O-SF 10037.51 9755.80 9615.44 35.75 12916.30 3411.90 MinPt-O-SF 9940.16 9663.971 9526.36 36.11 13196.01 3407.96 MinPt-0-ADP 9940.02 9663.9'"11 9526.39 36.13 13201.10 3407.79 MinPt-O-EOU 1 9939.95 9664.02 9526.54 36.15 13207.88 3407.57 MinPt-CtCt 9981.29 9707.301 9570.801 36.561 13595.42 3391.22 MinPts 1 9795.41 9464.49 9299.53 29.69 15534.61 3395.51 MinPt-CtCt 9769.41 9396.871 9211.09 28.29 16617.72 3379.21 MinPt-O-EOU 9748.28 9365.25 9174.22 25.51 16886.84 3378.66 MinPt-CtCt 9617.13 9194.44 8983.58 2280 17890.06 3373.33 MinPt-CtCt 9521.57 9058 94 8828.11 20.62 19134.39 3353.81 TD 9976.71 9702.21 9565.45 36.471 13580.61 3391.25 MinPt-0SF I9972.71' 9692.88 955347 35.76 14070.27 3391.14 MinPts 9606.8 9181.8 8969.76 22.651 17944.12 3373.03 MinPts OP12-01(Def Survey) Pass Ma .y MMICS MEE 70.92 2.62 2.62 MinPts MBE 84.81 MZEIE 31.29 277.17 277.17 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 3 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 87.77 84.58 54.96 27.12 331.35 331.34 MinPt-O-EOU 149.40 127.23 116 60111111113113,11 857.41 845.77 MinPt-O-SF 179.58 148.94 134.23 6.06 983.13 961.56 MinPt-O-SF 5386.14 5188.91 5090.79 MEC 9060.51 3041.95 MinPt-O-SF 6253.90 6027.99 5915 53 MEM, 10187.51 3190.07 MinPt-O-SF OP26-DSPO2(Def Survey) Pass 1111MIEM1111131OMi®j... 228.88 3.99 3.99 MinPts 203.33 181.16 170.52 1.1.311111i 870.40 857.91 MinPt-O-SF 187.67 162.18 150.00® 999.71 976.52 MinP1-OSF 186.36 161.52 149.66 7.81 1021.40 995.96 MinPt-O-ADP 185.67=11101 149.84 7.97 1038.81 1011.30 MinPt-O-EOU 185.06 162.11 151.19 8.42 1072.68 1041.39 MinP1-CtCt 185.17 162.95 152.36 1311 1089.54 1056.15 MinPt-O-SF 411.58 399.22 378.7 ® 1607.80 1461,85 MinPt-OSF 667.05 644.87 634.2 ® 1996.59 1738.01 MinPt-OSF 788.70 762.20 749.5.®i 2136.19 1834.88 MinPt-O-SF 5596.04 5554.09 553360 136.56 3792.24 2349.54 TD OP10-09(Def Survey) Pass 104.01 102.82 71.231 84.00 0,00 0.00 MinPts 104.44 102.35 71.63 49.36 199.07 199.07 MinPt-0-EOU 186.09 163.90 153.28I�. 1, 822.39 812.83 MinPt-O-SF 237.63 205.78 190.47® 958.34 939.05 MinPt-O-SF 2622.74 2547.73 2510.7211111118ES 3966.11 2372.39 MinPt-O-SF 3718.66 3610.54 3556 97 :12 5416.48 2563.01 MInPt-OSF 4151.57 4031.48 3971.93[min 5924.09 2629.73 MinPt-O-SF • 7380.87 7119.68 6989.58'm1HT1 11451.78 3356.24 MinP1-0SF 7555.96 7266.•-mzEgo 26.23 13609.91 3391.20 MinPt-O-ADP 7555.9.mom7122.96 26.23 13612.09 3391.20 MinPt-O-EOU ' mgarl 7286.97 7123.00 26.24 13814.26 3391.20 MinPt-CtCt 7257.34 7110.98 25.79 13954.14 3391.14 MinPt-CtCt • 7552...MUM 7109.00 25.59 14044.09 3391.14 MinPt-O-EOU 7555.7•�". 7103.86 25.13 14268.50 3387.95 MinPt-O-EOU 7556.79 7254.36=.r 25.06 14298.48 3387.39 MinPt-O-ADP 6815.46 6615.56 18.05 1695747 3378.56 MinPt-CtCt 7564.00 7277.27 7134.4. 13308.83 3403.30 MinPt-O-SF 7554.17 7267.9.MEM 26.48 13379.07 3399.34 MinPt-O-ADP 6787.56 6293.61 6047.13 13.77 19438.28 3350.95 TD 7867.6.MEM=ME filM 12622.39 3413.74 MinPts 0106-05 MWD-Standard(Non-Det Survey) Pass 141.32 110.96 58.21 224.07 224.07 MinPts 143.7 141.0' 110.•: 51.94 253.92 253.92 MinPts 143.87 140.90 111.06 48.05 278.24 278.24 MinPt-O-EOU 22404 209.71 191.23® 721.98 717.00 MInPt-OSF 2149.42 2130.85 2116.61 115.72 1278.38 121483 TD 470529 4665.39 4646....maim 1189.04 1141.34 MinPt-O-SF 4625.28 4586.03 4567.0-=90144. 1190.44 1142.51 MinPt-OSF 4527.58 4489.13 4470.5.maga 1192.27 1144.04 MinPt-O-SF ' 4015.35 3980.28 3963. =NE1204.42 1154.19 MinPt-O-SF 3830.96 3797.19 3780...marls 1211.00 1159.68 MinPt-O-SF 3608.99 3577.08 3561.7'=E1€' 1219.26 1168.53 MinPt-O-SF 3419.02 3388.74 3374.21 mum 1226.64 1172.62 MinPt-O-SF 3224.84 3196.38 3182.7:= 1234.81 . 1179.36 MinPt-0SF 2713.48 2691.23 2680.6.=En 1258.58 1198.80 MinPt-O-SF 2608.18 2586.98 2575.3 mom 1262.87 1202.28 MinPt-O-SF 4840.30 4799.24 4779. =INC 1188.49 1140.88 MinPt-O-SF 4892.77 4851.27 4831.1 =En 1189.01 1141.31 MinPt-O-SF 5215.33 5170.06 5148..' 11840 1201.78 1152.00 MinPt-O-SF 5635.20 5581.89 5555.•' 1.0 1245.58 1188.20 MinPt-O-SF • 5888.96 5830.80 5802.3 103.40 1276.41 1213.24 MinPt-0SF 0106-05 current(Non-Def Survey) Pass =11=1 141 32 110 96 5821 224.07 224.07 MinPts 143.7 '. 141.03 110 961 51.94 253.92 253.92 MinPts 143.87 14090 111.06 48.05 278.24 278.24 MinPt-0-EOU •• 224.04 209.71 191.23® 721.98 717.00 MinPt-OSF 1743.66 1726.26 1710.• �" '1 1263.59 1202.87 MinPt-O-SF 2149.03 2131.11 2116.22 119.86 1278.15 1214.65 TD 3174.80 3150.86 3139.42 138.74 1236.02 1180.35 MinPt-O-SF 2949.48 2927.28 2916.68 132.81 1246.85 1189.23 MinPt-OSF 5209.01 5173.61 5156.45 151.70 1200.39 1150.83 MinP1-0SF 5626.22 5586.36 5566.97 145.03 1244.03 1186.93 MinPt-O-SF 5759.20 5718.20 5698.23 144.18 1282.23 1201.76 MinPt-O-SF 5875.85 5834.18 5813.88 144.69 127485 121198 MinPt-0-SF OP08-04(Def Survey) Pass 120.02 118.79 87.211 97 05 0 00 0 00 MinPts 120.331 118.14 87.52 54 60 183.90 183.90 MinPt-O-EOU 236.92 215.15 204.11® 845.00 834.12 MinPt-0SF ' 248.27 225.49 214.71® 873.25 880.57 MinPt-O-SF 6713.88 6593.24 6533.41® 6183.77 2663.86 MinP1-0SF OP08-04PB1(Def Survey) Pass ' 120.02 118.79 87.211 97 05 0.00 0.00 MinPts 120.33 118.14 87.52 54.60 183.90 183.90 MinPt-0-EOU 236.92 215.15 204.11®. 845.00 834.12 MInPt-OSF 248.27 225.49 214.71 3123 873.25 860.57 MinPt-O-SF 6038.04 5971.27 5938 38® 3924.31 2366.89 MinPt-0SF 0106-05(P9c)(Def Plan) Pass Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 4 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 144.03 142.81 11122 116.68 000 0.00 Surface 144.03 141.40 111.22 54.26 249.11 249.11 MinPt, 144.10 141.30 111.30 50.88 278.39 278.39 MinPt-O-EOU 240.18 22678 207.37 17.83 79133 78340 MinPt-OSF 613.67 599.98 580.86 44.73 1086.04 1053.09 MinPt-O-SF 4454.91 4432.70 4422.10 200.54 1194.19 1145.65 MinPt-O-SF 4370.75 4349.01 4337.94 201.00 1195.56 1146.80 MinPt-0-SF 5880.51 5838.36 5817.81 143.10 1274.70 1211.86 MinPt-O-SF 6310.71 6264.65 6242.11 139.97 1331.17 1256.82 MinPt-0-SF 6970.79 6917.56 6891.44 133.42 1418.62 1323.86 MinPt-0-SF 7262.22 7204.92 7176.76 128.92 1479.36 1368.59 MinPt-0-SF 7853.93 7787.39 775462 119.80 1756.10 1568.28 MinPt-0-SF 7931.42 7884.68 783181 125.61 1789.71 1592.22 MinPt-0-SF 7977.79 7910.67 7877.60\ 120,61 1809.52 1606.29 MinPt-OSF 8118.80 8049.83 8015.83 _119.40 1869.11 1648.48 MinPt-0-SF 8512.42 8440.75 8405.40 12041 1992.77 1735.34 MinPt-O-SF 9132.13 9055.93 9018.32 121.40 2161.33 1852.20 MinPt-O-SF 11319.10 11230.36 11186 49 128.98 2335.85 1964.88 TD 0107-04(Def Survey) Pass 1 128.04 126.81 95231 103.61 3.88 3 88 MinPts 128.22`1 125.71 9541 50.68 263.57 263.57 MinPt-0-EOU 128.37 125.82 95.56 MUM 292.92 292.92 M1nPt-0SF 128.56 126.01 95.7 49.8 312.48 312.47 MinPt-0-SF 245.31 232.41 212.50111111111111 828.23 818.34 MinPlASF 2293.21 2271.01 2260.4.man 1974.93 1722.87 MinP1-0SF 3359.17 3325.46 3309.1 wpm 2271.36 1925.00 MinPt-0-SF 9778.00 9726.61 9701.41 193.98 2988.40 223303 TD OP05-06PB2(Def Survey) Pass 151.79 149.91 118.98 79.86 153.94 153.94 MinPts 151.86 149.86 11905 75.29 173.94 173.94 MinPt-0-EOU 252.98 242.07 220.17 ME 747.71 741.74 M1nPt-0SF 6243.27 6221.06 6210.46 MEM 1065.86 1035.40 MinPt-0-SF 9363.81 9282.18 9241.6 =ME 1424.33 1328.13 MinPt-0-SF 11204.51 11110.66 11064.2 NEM 1821.75 1614.97 MinPt-0-SF 11256.95 11162.71 11116.11 12076 1839.19 1627.32 TO OP05-06PB1(Def Survey) Pass 151.79 149.91 118.98 79.86 153.94 153.94 MinPts 15186 149.86 119.05 75.29 173.94 173.94 MinPt-0-EOU 252.98 242.07 220.17 MSEIE 747.71 741.74 MinPt-0SF 1758.37 1744.75 1725.56 129.00 1331.09 1256.75 TD I 1763.3511 1749.73 1730.54 129.311 1331.08 1256.75 MinPts OP05-06(Def Survey) Pass 151.79 14991 118.98 79.86 153.94 153.94 MinPts 151.86 149.86 11905 75.29 173.94 173.94 MInPt-0-E0U 25298 242.07 220.17®" 747.71 741.74 MinPt-O-SF 6243.27 6221.06 6210.46 iii 1065.86 1035.40 MinPt-O-SF 9363.81 9282.17 92418 M;, 1424.33 1328.13 MinPt-0-SF 12608.32 12506.98 12456.80 125.62 2144.40 1840.54 TD OP09-S1(Def Survey) Pap 1 12206.301 11761.73 1153993 27.521 18904.39 3355.58 MinPts 12079.81 11610.43 1137623 25.79 19438.28 3350.95 TD 112.57 109.65 79 76 38.23 283.14 283.14 MinP1-0-E0U 290.05 26787 25724 13.02 957.21 938.02 MinPt-O-SF 320.07 295.28 283.5 13.5 1001.88 978.45 MinP1-0SF 371.03 342.33 328.5 13. 1071.71 1040.54 M1nPt-OSF 12343.91 12076.501 1194329 46.33 13465.91 339419 MinPt-0-ADP 12346.17 12077.88 11944.22 46.181 13579.43 3391.25 MinP1-0SF I 12312.971 12025.53 11882.30 42.98 14581.40 338246 MinPt-CtCt 12313.6111 12024.9 11881.03 42.79 14614.70 3382.56 MinPt-0-EOU 12314.50 12025.09 11880.1q 42.69 14632.62 3382.76 MinPt-O-ADP MEM 11947.79 11787.51 38.27 15463.48 3396.39 MinPt-CtCt 122746. 11940.06 1177327 36.80 15806.72 339438 MinPt-O-EOU 12276.92 11940. .MUM 36.60 15856.65 3394.30 MinPt-O-ADP 12519.52 12243.45 12105.9.mm 12987.15 3411.51 MinPt-0-SF 12343.91 12077.. MIZEIES 46.49 13342.51 3401.50 MinPt-O-ADP 12343.: Man 11944.69 46.50 13344.24 3401.40 MinPt-0-EOU .'.' 1207747 11944.79 46.52 1334764 3401.21 MinPt-CICt 0111-01PB1(Def Survey) Paw 95.87 94.17 63.07 55.64 138.95 138.95 MinPts 9623 93.91 63.42 41.04 253.88 253.88 MinPt-O-EOU 96.38 9402 63.5 mogE 283.38 28338 MinPt-0-SF 220.06 197.90 187.2 Emil 977.37 956.34 MinPt-OSF 313.61 277.13 259.50 1195.76 1146.97 MinPt-0-SF 4326.49 4254.33 4218.75 60.78 4140.63 239533 TD OI11-01(Def Survey) Pass 95.87 94.17 63.07 55.64 138.95 138.95 MinPts 96 23 93.91 6342 41.04 253.88 253.88 MinPt-O-EOU 96.38 94.02 63.5 ®1 283.38 283.38 MinPt-O-SF 220.06 197.90 187.2 _____p 97737 956.34 MinPt-0-SF 313.61 277.13 259.50.MEg 1195.76 1146.97 MinPt-0-SF 5770.98 5630.96 5581..•MEMO 731665 2812.75 MinPt-O-SF OPO4-07(Def Survey) Pass, 15926 156.80 126.46 64.14 258.60 258.60 MinPts 159.29 156.78 126.48 63.11 270.65 270.65 MinPt-0-EOU 159.38 156.86 126.5: 11E 287.78 287.77 MinPt-O-SF 159.61 157.09 1268. 62.86 307.23 307.22 MinPt-OSF Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 5 of 24 I Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert 1 Minor I Major 296.39 277.98 263.58 16.03 902.80 888.03 MInPt-O-SF 8258.23 8202.20 8174.68 150.02 3406.27 2298.81 MInPt-O-SF 8746.77 8687.79 8858.80 150.81 3581.03 2321.78 MInPt-O-SF 10226.51 10161.63 10129.69 160.05 3918.44 2366.12 TD OPO4-07PB1.(Def Survey) Pass 159.26 156.80 126.46 6414 258.60 258.60 MinPts 159.29 156.78 126.48 6311 270.65 270.65 MinPt-O-EOU 159.38 156.86 126.5: 287.78 287.77 MinPt-O-SF 159.61 157.09 126.8. 62.86 307.23 307.22 MinPt-O-SF 296.39 277.98 263.58 Man 902.80 888.03 MinPt-O-SF 8694.66 8636.50 8607.91 152.05 3531.37 2315.25 TD . Oliktok Point I-2PB1(Def Survey) Peas 176.54 175.46 143.73 162.75 0.00 0.00 Surface 176.54 175.46 143.7 162.75 40.00 40.00 MinPts 174.88 172.13 142.07 63.30 369.01 368.99 MinPts 174.90 172.09 142.09 81.88 382.98 382.94 MinPt-O-EOU 175.10. 172.14 142.29 58.75 406.27 406.20 MinPt-0-EOU 187.35 173.16 154.54 13.13 779.54 772.17 MinPt-O-EOU 188.90 173.23 156.09 11.99 807.57 798.81 MinPt-O-EOU I 196.76 174.84 163.9 lil 924.17 907.76 MinPt-O-SF 202.58 177.80 165.r• 1.X1 1003.31 979.76 MinPt-O-SF 219.23 192.18 179.1• 8 40 1310.57 1240.56 MinPt-OSF 323.50 281.32 260.77 111111 2219.70 1891.55 MinPt-O-SF 1966.77 1850.50 1792.85 17.05 6171.41 2662.23 TD • I Oliktok Point 1-2(Det Survey) Pass 176.54 175.46 143.73 162.75 0.00 0.00 Surface 176. 175.46 143.7 162.75 40.00 40.00 MinPts • 174.88 172.13 142.07 63.30 369.01 368.99 MinPts 174.90 172.09 142.09 81.88 382.98 382.94 MinPt-O-EOU 175.10. 172.14 142.29 58.75 406.27 406.20 MinP1-0-EOU . 187. 173.16 154.54 13.13 779.54 772.17 MinPt-O-EOU 188.90 173.23 156.09 11.99 807.57 798.81 MinPI-0-EOU 196.76 174.64 163.• =co924.17 907.76 MinPt-O-SF 202.58 177.80 165.1 �.-r, 1003.31 97976 MinPt-O-SF 21923 192.18 179.11=BM 1310.57 1240.56 MinPt-O-SF 323.50 281.32 260.77111111111111111 2219.70 1891.55 MinPt-O-SF 2160.04 2020.91 1951. 6810.52 274623 MinPt-0SF 5127.90 4873.41 4746.66 20.22 11021.52 329969 TD Oliktok Point l-2PB2(Def Survey) Pass • 176.54 175.56 143.73 178.37 0.00 0.00 Surface 176.541 175.46 143.7 182.75 40.00 40.00 MinPts 174.88 172.18 142.07 64.42 369.01 368.99 MinPts 174.90 172.14 142.09 6294 382.98 38294 MinPt-0-EOU 175.10. 172.18 14229 59.65 40627 40620 MinPt-O-EOU 187. 173.17 154.54 13.14 779.54 772.17 MinPt-O-EOU 188.90 173.24 156.09 11.99 807.57 798.81 MinPI-0-EOU 196.76 174.64 163.9 :IM 924.17 907.76 MinPt-0SF 202.58 177.80 165.9 1111111.113M 1003.31 979.76 MinPt-OSF 219.23 19218 179.2. 7.1 " 1310.57 1240.56 MinPt-0SF . 323.50 281.33 260.78 liM 2219.70 1891.55 MinPt-OSF 2160.04 2020.91 1951.• jRCE 6810.52 274623 MinPt-OSF 3459.47 3267.71 3172.32 18.13 8629.32 2985.28 TD OP03-PO5PB1(Def Survey) Pass 167.94 166.64® 128.45 64.00 64.00 MinPts 168.05 165.8. 135.2• 74.89 244.00 244.00 MinPts 168.07 165.78 135.26 72.89 258.74 258.74 MinP1-0-EOU 168.33 165.99 135.5u® 292.73 292.73 MinPt-O-SF 327.29 310.77 294.48 ffzu 89975 885.21 MinPt-O-SF 4183.35 4157.75 4145. NEM 1585.39 1445.64 MinPt-O-SF 4670.05 4640.78 4626.7•=•, 1801.69 1600.73 MinPt-O-SF OP03-P05(Def Survey) Pass 167.94 166.64 135.13 128.45 64 00 64.00 MinPts 168.0 165.8 135.2 74.89 244.00 244.00 MinPts 168.07 165.78 135.26 72.89 258.74 258.74 MinP1-0-EOU 168.33 165.99 135.5.MFAIM 292.73 292.73 MinPt-OSF 327.29 310.77 294.48 899.75 885.21 MinPt-O-SF 4135.92 4110.87 4098.::111==IE 1564.17 1430.28 MinPt-OSF 5248.29 5212.97 5195.8.® 2042.54 1770.03 MinPt-0SF 5533.61 5496.64 5478.6 =Ego 2150.26 1844.58 MinPt-O-SF 9638 90 9586.10 9560.19 185.99 2565.54 2089.03 TD OP03-P05P82(Det Survey) Pees 167.94 166.64 13513 128.45 64.00 64.00 MinPts 168.0' 165.82 135.24 74.89 244.00 244.00 MinPts 168.07 165.78 135.26 72.89 258.74 258.74 MinPt-O-EOU 168.33 165.99 135.52 71.37 292.73 292.73 MinPt-O-SF 327.29 310.77 294.48 19 74 899.75 885.21 MinPt-O-SF 4135.92 4110.87 4098.881 172 451 1564.17 1430.28 MinPt-O-SF 5248.29 5212.97 5195 821 152 991 2042.54 1770.03 MinPt-O-SF 5533.61 5496.64 5478.671 153 901 2150.26 1844.58 MinPt-O-SF 7564.38 7518.26 749571 "6771 2359.81 1979.15 TD Oliktok Point 1-1A-106(P5)(Def Plan) Pass 184.58 183.47 151.77 164.60 0.00 0.00 Surface 183.47® 164.55 40.10 40.10 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 6 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) 1 TVD(ft) Alert 1 Minor 1 Major 184.68 183.36 151.87 138.95 84.20 84.20 MinPt-0-EOU 351.36 340.16 318.5 man 791.57 78383 MinPt-0SF 38248 37021 349.67 MEM 828.44 818.55 MinPt-0SF 2092.4 1.SLW10 2059.6 mum 1217.35 1164.94 MinPts 7247.45 7224.94 7214.6 man 1005.35 981.59 MinPt-0-SF 11760.06 11853.04 11600.48 min 1364.68 1282.88 MinPt-0-SF 13518.15 13398.20 13339.18 114.51 1623.11 1472.89 TD Oliktok Point I-1(Def Survey) Pass 184.58 183.47 15177 164.60 0.00 0.00 Surface 18458 18347 151.77 16455 40.10 40.10 MinPts 184.68 183.36 15187 138.95 84.20 84.20 MinPt-0-EOU 351.36 340.16 318,5 31.27 791.57 783.83 MinPt-O-SF 382.48 370.21 34987 31.08 828.44 818.55 MinPt-0SF 1942.49 1925.32 1909.68 113.10 1218.49 1165.89 TD 7211.21 7189.01 7178.4.=En 1038.87 1011.53 MinPt-0SF 7799.08 7770.96 7757.3.mom 1101.60 1066.65 MinPt-0SF SP36-W5(P2)(Def Plan) Pass 17880.1 MIME 5669.75 251.06 251.06 MinPts 17883.72 17880.43 17850.91.wEEEE. 278.83 278.83 MinPt-0SF 17883.97 17880.70 17851.16 mar& 301.04 301.04 MinPt-0SF 17883.61 1788238 17850.80 14610.29 0.00 0.00 Surface 10758.0 10539.45 10431.63 49.87 12562.86 341403 M1nPt-CtCt 7060.2 6718.11 6548.40 20.79 1769870 337441 MinPf-CtCt 621660 5809.911 5607.841 15.381 19438.28 3350.95 MinPts S135-W4(P2)(Def Plan) pap U 17882.541 17879.391 17849.7 5676.96 251.06 251.06 MinPts 17882.95 17879.65 17850.1 5431.9 278.86 278.88 MinPt-0SF 17883.20 17879.92 17850.3 5461.0 301.10 301.09 MinPt-0-SF 17882.83 17881.80 1785002 14609.65 0.00 0.00 Surface min 10785.65 10677 77 50.99 12566.17 3414.01 MinPt-CtCt 8303.8 7964.85 7796.43 24.65 17625.50 3374.82 MinPt-CtCt 7234.68 6828.181 6626.021 17.891 1943828 3350.95 MinPts SP33-W 3(P2)(Def Plan) Pap 1 17880.861 17877.711 17848.05 5686.87 251.06 251.06 MinPts 17881.30 17878.00 17848.49 5430.28 278.91 278.91 MinPt-0-SF 17881.51 17878.23 17848.70 5459.17 298.41 298.41 MinPt-0SF 15159.76 14898.77 14768.77 58.30 15583.39 3394.91 MinP1-0SF 17881.18 17879.95 17848.37 14606.30 0.00 0.00 Surface 10879.1' 10659.45 10551.16 50.21 12567.05 3414.01 MinPt-CtCt 8733.10 8394.49 8226.23 25.94 17617.45 337487 MinPt-CtCt 8171.79 7765.08 7562.60 20.18 19438.28 3350.95 TD S132-W2(P2)(Def Plan) Pep I17880.031 17876.891 17847.23 5684.33 251.06 251.06 MinPts 17880.48 17877.19 17847.67 5429.44 278.94 278.94 MinPt-0-SF 17880.69 17877.41 17847.88 5458.11 298.46 298.46 MinPt-0-SF 1523251 14971.73 14841.83 58.63 15583.26 3394.92 MinPt-0-SF 17880.36 17879.14 17847.55 14607.64 0.00 0.00 Surface 11060.19 10839.12 10730.14 50.73 12566.76 3414.01 MinPt-CtCt 945499 9047.19 8843.91 23.25 19438.28 3350.95 TD Kigun 1(Def Survey) Pass 17129.85 17127.13 17097. 6302.26 182.14 182.14 MinPts 17130.00 17127.01 17097.19 5738.50 197.17 197.17 MinPt-0-EDU I17130.09 17126.55 17097.281 4840.41 278.48 276.46 MinPts 17130.09 17126.54 1709729 4823.12 278.41 278.41 MinPt-0-EDU 1 1068747 10287.18 10087.841 26.801 19438.28 3350.95 MinPts Kigun 1 P81(Det Survey) Pap • 17127.1 .MICIEW 6302.26 162.14 162.14 MinPts 17130.0•p1IME 17097.19 5738.50 197.17 197.17 MinPt-0-EDU jomommagme 4840.41 278.46 276.46 MInPte 17130.0r.MEI6SLE 17097.29 4823.12 278.41 278.41 MinPt-0-EOU 10687.47 10287.18 10087.84 26.80 19438.28 3350.95 MinPts Tuveeq ST 1(Def Survey) Pass 17129.85 17127.13 17097. 6302.26 162.14 162.14 MinPts 17130.00 17127.01 17097.19 5738.50 197.17 197.17 MinPt-0-EOU I 17130.09 17126.55 17097.281 4840.41 276.46 276.46 MinPts 17130.09 17126.54 17097.29 4823.12 278.41 278.41 MinPt-0-EDU 1 10687.47 10287.18 10087.841 26.801 19438.28 3350.95 MinPts SP3O-W 1(P2)(Def Plan) Pep 10978.71 10630.81 10457.47 31.66 17865.90 3373.47 MinPt-CtCt 17878.11 17874.82 17845.3,'rS 279.03 279.03 MinPt-O-SF 17878.32 17875.05 17845.5 Mal 298.61 298.61 MinPt-0-SF 15245.12 14983.90 14853.7.MIE 15584.04 3394.91 MinPt-0-SF 17877.99 17876.77 17845.19 14605.70 0.00 0.00 Surface 11509.6. 11196.96 11041.18 36.94 16953.75 3378.57 MinPt-CtCt NEM 11929.84 11821.61 56.12 12572.75 3413.98 MinPt-CtCt 10741.63 10336.31 10134.14 26.56 19438.28 3350.95 TD 12191.37 11972.01 11863.6 MEIER 12849.30 3413.60 MinPt-0SF ' 11016 8 10671.89 10500.01 3205 17798.44 3373.86 MinPt-CtCt 10981.44 10629.791 10454.541 31.331 17977.69 3372.76 MinPts 0129-S2(P2)(Def Plan) Pass 17877.28 17873.95 1784445 5400.71 265.06 265.06 MinPt-0-EOU 17877.2 17873.95 17844.44 5409.69 267.86 267.86 MinPts 17877.51 17874.23 17844.70 5453. 298.66 298.65 MinPt-0SF :a 15230.30 15138.09 83.59 10758.95 3265.18 MinPt-CtCt Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 7 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU_IftL Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 15419.961 15228.29 15132.99 80.90 11048.54 3303.24 MinPt-O-EOU 15428.04 15229.96 15131.461 78.31 11339.85 3341.53 MinPt-O-ADP 17877.18 17875.95 17844.37 14605.03 0.00 0.00 Surface 1 17874.3: :�" 1 6390.66 198.10 198.10 MinPts 14985.88 14669.07 14511.16 47.45 17079.49 3378.39 MinPt-CtCt 14986.65 14655.45 14490.34 45.38 17495.27 3375.72 MInPt-CtCt ' 10854.20 10492.29 10312.09 30.11 17858.24 3373.51 MinPt-CtCt 10855.28 10490.4 10308.8. 17943.12 3373.03 MinPts Mila:IMEE10549.3'Erzon.mozo 17080.79 3378.39 MinPts 11497.03 11248.87 11126.31 MEM. 12569.71 3414.00 MinPt-O-SF [110905.1+ 'C= "MM�"I 16560.61 3380.41 MinPts 11048.64 10778.80 10641.8 40.9' 13437.77 3395.77 MinPt-O-SF maw, 10788.0' 10628.1: 40.0 14063.57 3391.14 MinPts 15181.87 14943.27 14834. '®I 12827.92 3413.71 MinPt-O-SF ME= 14838.27 14690.69 5127 16550.50 3380.70 MinPt-CtCt 14615.09 14210.51 14008.71 36.21 19438.28 3350.95 TO 14669.01 010M151n 17081.24 3378.38 MinPts 14660.2. 14309.67 4134 90 MMEI 17943.49 3373.03 MinPts M. :1 14943.45 14834.85 69.80 12590.26 3413.89 MinPt-CICt 10488.98 10306.94 29.81 17969.76 3372.83 MInPt-CICt 10854.6: 10488.86 1030666 2979 17980.28 3372.73 MinPt-O-EOU 10854.82 10488.81 10306.63 29 78 17984.49 3372.68 MinPt-O-ADP 10885.94 10516.72 10332 64® 18128.24 3369.68 MinPt-O-SF 151 •®.: 10279 09�:.6 18449.56 3360.24 MinPts rte:•. „ 0509 5.1.111311:111111Mgm 18611.54 3357.45 MinPts 10899.68 10560.57 10391.7 17162.31 3378.06 MinPt-O-SF l 98 M 46.98 12497.01 3414.35 MinPts I MEM Nom wi2E. 46.68 12650.77 3413.59 MinPts 11113=E.1.31=mum 46.85 12505.29 3414.31 MinPts =ME�.;,4T 13389.71 3399.91 MinPts i 10906. 16643.62 3379.02 MinPts C 11048.61 10776.43 10641.31 40.88 13486.42 3393.26 MinPt-CtCt 11048.7•MEIMEEI 10640 32 40.76 13578.26 3391.25 MinPt-O-EOU 11048.77 10775.:'. 10640.32 40.75 13580.76 3391.25 MinPt-0-ADP 11066.16 10790.84 10653 60®i 13703.57 3391.14 MinPt-O-SF 11044,54 10766.81 10628.65 MOE 14119.18 3390.73 MinPt-O-SF 15118.06 11118GE 14559 18® 18734.10 3356.67 MinPts I SP27-N1(P3)(Def Plan) Paas 11739 33 11333.74 11131 45 29.01 19438.28 3350.95 TD 17875.64 17872.35 17842.8 111111"1 279.12 279.12 MinPt-O-SF 17875.86 17872.58 17843...:'' 298.75 298.75 MinPt-O-SF 15297.47 15036.41 14906. •mom15583.06 3394.92 MinPt-O-SF 17875.53 17874.30 17842.72 14803.68 0.00 0.00 Surface ME= 12129.94 11976.74 40.59 18811.88 3378.77 MInPt-CtCt 12795.12 12575.55 12466.94 58.94 12632.46 3413.69 MinPt-O-SF I 12064.971 11687.031 11498.55 3200 18809.48 3356.19 MinPts • 0125.142(P2)(Def Plan) Pass 12640.32 12231.96 12028.27 31.03 19438.28 3350.95 TD 17874.14 17870.84 17841.33 liffrog 279.18 279.18 MinPt-O-SF 17874.35 17871.07 17841 54 WEE 298.85 298.85 MinPt-O-SF • 14902.36 14655.32 14532.29 mom 15095.56 3400.70 MinPt-O-SF 15388.41 15107.80 14977.9:: 15584.10 3394.91 MinPt-O-SF 17874.02 17872.80 17841.21 14602.46 0.00 0.00 Surface .' WIDE 12610.18 12456.14 41.93 16799.73 3378.79 MinPt-C1Ct 12702.87 12347.88 12170.9 ®'I 17980.58 3372.72 MinPt-O-SF 13449.74 13227.59 13117.5 MIZE 12840.42 3413.65 MinPt-O-SF 13165.16 13067.38 88.32 11192.73 3322.19 MinPt-CtCt 13367.31 NEKIE 13063.72 66.47 11447.52 3355.68 MinP1-0-EOU 13367.41 13164.2 MOM 66.45 11451.10 3356.15 MinPt-O-ADP 13445.32 13223.26 13113.2.; 12648.49 3413.61 MinPt-O-SF 13430.24 13209.51 13100.0961.36 12723.20 3413.19 MinPt-O-ADP 13430.1 , 13100.10 61.38 12727.29 3413.17 MinPt-0-EOU 11111110111,XO!8 13209.56 13100.24 61.42 12735.49 3413.12 MInP1-CtCt 12838.63 12518.06 12358.26 40.17 17091.33 3378.37 MinPts I 12740.22112353.921 12161.26 33,06 1894746 3355.31 MinPts SP23-N3(P3)(Def Plan) Pea 14405.44 1429766 87.83 12596.95 3413.86 MinPt-CtCt 17871.23 17867.93 17838.4. 5419.61 279.29 279.29 MinPt-O-SF I 17871.44 17868.16 178386 IEME 299.05 299.04 MinPt-O-SF 15375.53 15114.60 14984.63 mug 15583.99 3394.91 MinPt-O-SF ! 17871.11 17869.88 17838.30 14600.08 0.00 0.00 Surface 13625.3 MEER sEzEEE 42.42 17227.45 3377.60 MinPts 13674.9 35.31 19029.57 3354.78 MinPts 1369164 13290.53 13090.47 34.22 19328.11 3351.99 MinPt-O-ADP 13699.84 13293.97 13091.53 33.83 19438.28 3350.95 TD 13463.14 13368.11 71.83 11009.74 3298.14 MinPt-CtCt 13655.4:MERE. 13367.48 71.59 11040.48 3302.18 MinPt-O-EOU 13655.84 13462.91 wow 71.49 11054.46 3304.02 MinPt-O-ADP 13821.65 13618.55 13517.9., 68.68 11522.33 3364.75 MinPt-O-SF 14367.56 14152.27 14045.451 12099.35 3407.75 MinPt-O-SF 13818.94 13603.78 13496.861 64.62 12956.76 3411.59 MinPt-O-SF 13806.61 witall�: E,! 64.67 12991.74 3411.31 MinPts 13806.61 13591.88 13485.15 6467 12992.84 3411.30 MinPt-CtCt 13248.43 13110.12 48.89 15988.62 3394.09 MinPt-CtCt ' 13527.25 MEM 13107.92 48.50 16051.73 3394.00 MinPt-O-EOU 13528 09 13247. 'MI= 48.39 16069.36 3393.95 MinPt-O-ADP 14619.5:=ME 1 12627.68 3413.71 MinPts SP24-SE1(P2)(Def Plan) Pass 1®. 3905 851 13750.401 45.73 16812.85 3378.77 MinPts 15094 59 14690.14 14488 41 37.41 19438.28 3350.95 TD Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 8 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft).EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 17871.94 17868.63 17839.13 5395.07 267.99 267.99 M1nP1-0-EOU I17871.94 17868.64 178391 5404.46 270.81 270.81 Min 17872.19/ 17868.91 17839.38Pte 5446.791 299.00 298.99 MinPt-O-SF I 15483.451 15305.95 15217.73 87.75 10372.95 3214.45 MinPt-CtCt 1546376/ 153056815217.17 87.47 10400.51 3218.07 MinPt-0-EOU 15484.16 15305.75 15217.081 87.31 10416.33 3220.15 MInPt-O-ADP 17871.86 17870.64 17839.05 14600.69 0.00 0.00 Surface • 17871.86 17869.06 17839.0 6386.25 198.10 198.10 MinPts 15350.35 14983.91 14801.1+mon 18586.34 3357.62 MinPt-O-SF 15305.87 1500822 14859.90 51.59 16600.40 3379.46 MinPt-0-EOU 15139.82 14789.16 14614.32 43.291 17957.15 3372.94 MinPts 1 14263.11 13884.10 13695.08 37.73 18755.27 3356.53 MinPts 14242.04 13912.45 13748.14 43.34 17334.21 3376.85 MinPts 14260.46 13903.20 1372506 40.02 18128.86 3369.66 MinPt-CtCt 14243.33 13921.11 13760.48 44.33 17118.31 3378.29 MinPt-CtCt 14353.83 14143.91 14039.9 68. 11448.72 3355.84 MinPt-OSF 15031.50 14819.23 14713.91 71. 11881.79 3392.58 MinPt-O-SF 15048.69 14836.19 14730.75 71.3 11898.55 3393.75 MinPt-0SF 15677.21 15464.1 15358.08 73.91 12976.07 3411.44 MinPt-O-ADP ' 15677.19 15464.1 15358.08 73.91 12976.74 3411.43 MinPt-O-EOU 15677.18 15464.13 15358.09 73.92 12978.07 3411.42 MinPt-CtCt _14025.15 13789.17 1367167 59.68 13369.97 3399.89 MinPts 14241.15 13911.73 13747.51 43.36 17329.48 3376.88 MinPta 14240.27 13911.02 13746.88 43.38 17324.75 3376.92 MinPla 1423940 13910.31 1374626 43.40 17320.01 3376.95 MinPt-CtCt 14263.79 13891.84 13706.36 38.451 18551.77 3358.00 MinPts 14238.53 13909.61 13745.64 43.42 17315.26 3376.98 MinPts 1423767 13908.92 13745.03 43.44 17310.51 3377.02 MinPts 14236.81 13908.23 13744.43 43.48 17305.76 3377.05 MinPts 14235.96 13907.55 13743.83 43.48 17301.00 3377.08 MinPts 14235.11 13906.87 13743.24 43.49 17296.24 3377.12 MinPta 14234.27 13906.19 13742.65 43.51 17291.47 3377.15 MinPta 14233.43 13905.53 13742.06 43.53 17286.70 3377.18 MinPts 14232.60 13904,86 13741.49 43.55 17281.92 3377.22 MinPts 14231.78 13904.21 13740.91 43.57 17277.14 3377.25 MinPts 14230.96 13903,56 13740.35 43.59 17272.35 3377.28 MinPts 14230.15 13902.91 13739.79 43.61 17267.56 3377.32 MinPts 14229.34 13902.27 13739.23 43.63 17282.77 3377.35 MinPts 14228.54 13901.64 13738.68 43.65 17257.97 3377.39 MinPts 14227.74 13901.01 13738.14 43.67 17253.17 3377.42 MinPts 14226.95 13900.39 13737.60 43.69 17248.36 3377.45 MinPta 14226.16 13899.77 13737.07 43.72 17243.55 3377.49 MinPts 14225.38 13899.16 13736.54 43.74 17238.74 3377.52 MinPts 14224.61 13898.55 13736.02 43.76 17233.92 337755 MinPts 14223.84 13897.95 13735.50 43.78 17229.10 3377.59 MinPts 14223.07 13897.36 13735.00 43.80 17224.27 3377.62 MinPts 14222.32 13896.77 13734.49 43.82 17219.44 3377.66MinPts 14221.56 13896.19 13733.99 43.84 17214.61 3377.69 MinPts 15291.22 14925.07 14742.49 41.871 18525.10 3358.42 MinPt-O-SF Sx34-N Sand(P2)(Def Plan) Pap 17882.01 17879..• 1. y 6008.65 251.06 251.06 MinPta 17882.0. 17879.0 17849.21 5974.53 259.41 259.41 MinPt-O-EOU mum 14090.08 13997.88 77.40 10746.46 3263.54 MinPt-CtCt 14276.04 14089.97 13997.64 77.30 10759.38 326524 MinPl-0-EOU 14276.24 14090... 13997.6. 77.25 10765.90 3266.09 MinPt-O-ADP 14518.47 14318.58 14219. • gill i 11451.14 3356.16 MinPt-OSF 15401.02 15186.85 150802 ffie 112100.93 3407.86 MinPt-0SF 17882.01 17880.79 1784920 14608.98 0.00 0.00 Surface 14565.79 14159,73 13957 19 35.96 19438.28 3350.95 TD 14459.99 14246.29 14139.94 67.971 13013.61 3411.13 MinPt-O-SF I14458.10 14244451 14138.12 67.98 13022.96 3411.05 MinPts 14211.36 13940.71 13805.88 52.70 15806.86 3394.38 MinPt-CtCt 14212.07 13940.02 13804.49 52.43 15847.03 3394.32 MinPt-O-EOU 14213.21 13940.25 13804.26 52.26 15873.25 3394.28 MinPt-0-ADP 15642.611 15425.16 15316.93 72.261 12622.70 3413.73 MinPts SP22-FN1(P2)(Def Plan) Pap 15103.63 14698.53 1449647 37.37 19438.28 3350.95 TD 17870 4 17867.1 17837.62 5391.37 268.02 268.02 MinPI-0-EOU 1 17870.4 17867.1 178376 5401.30 270.85 270.85 MinPta 1787068 17887.40 17837.8 5444.71 299.10 299.09 MinPt-OSF 15483.6 15306.18111 15218.01 87.79 10365.74 3213.50 MinPt-CtCt 154839 15305.91 15217.45 87.51 10393.51 3217.15 MinPt-O-EOU 15484.30 15306.0 15217.381 87.36 10407.85 3219.03 MinPt-0-ADP 17870.35 17869.12 17837.54 14599.45 0.00 0.00 Surface MEMEE 17867.5 ME= 6384.98 198.10 198.10 MinPts 15353.02 14985.85 14802.751 18583.37 3357.65 MinPt-0SF MEM MiE3112 14882-78 51 62 16576.27 3379.97 MinPts 15309.70 15011.2: 14862 56 51.47 16605.52 3379.37 MinPt-0-ADP MI=jjjj •20 •, 14766.07 48.181 17081.46 3378.38 MinPts NEE= 14798.73 14624.74 43 53 17893.90 3373.31 MinPt-CtCt 15148.62.11=11.1051111[01:9E 1 17957.82 3372.94 MinPts 15914.85 15695.49 15586.31 jj_____ 12622.97 3413.73 MinPt-O-SF 15893.92 15674.91 15565.91®i 12642.50 3413.63 MinPt-0SF 15681 58 15468.41 jjjj1mm 73.90 12982.00 3411.39 MinPt-O-ADP 15681.565,•: , 15362.32 73.91 12983.14 3411.38 MinPt-O-EOU 0 15468.42 15362.35 73.92 1298541 3411.36 MinPf-CtC1 jjjj mum mg= 40.50 18849.12 3355.94 MinPta S119-F N2(P2)(Def Plan) Pap 15258.83 1485369 14651.61 37.75 19438.28 3350.95 TD 1 17868 17864.7 17835.24 5385.37 268.08 268.08 MinPt-0-EOU r 17868. 17864.7 17835.23] 5396.21 270.91 270.91 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 9 of 24 • Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 17868.29 17865.01 1783548 5441.51 299.25 299.24 MinPt-0SF II- 15501.774 15325.85 15238.42 88.65 10292.31 3203.85 MinPt-CtCt 155019 15325.6 1523800 88.44 10312.27 3208.47 MinPt-O-EOU 15502.26 15325.7 15237.91 88.33 10322.55 3207.82 MinPt-O-ADP 17887.96 17866,74 17835.15 14597.50 0.00 0.00 Surface 1 17867.96 17865.160K= 6383.05 198.10 198.10 MinPts 15380.7.M=§1 1493324 51.67 16610.94 3379.29 MinPt-O-EOU • 15313.38 14961.76 14786.' 0 17986.84 3372.65 MinPt-O-SF 15865.90 15649.74 155421 msym 12821.05 3412.58 MinPt-OSF 15716.46 15503.7..mm 7421 13010.54 3411.16 . MinP1-0-ADP • 15716.'MEMEE 15397.81 74.21 13011.04 3411.15 MinPt-O-E0U • MIME 15503.70 15397.81 74.21 13011.53 3411.15 MinPt-C1Ct • 14808.39 MCIII1 18866.89 3355.82 MinPts S117SE2(P2)(Def Plan) Pass - . ' i EMEEF., 14973.13 14808.42 46.45 17406.03 3376.35 MinPt-CtCt 15332.17 14927.27 14725.30 37.96 19438.28 3350.95 TD 18366.70 3362.68 MinPts • 17865.9. 17862.6. 17833,12 5381.71 268.13 288.13 MinPt-O-EO1J OEM 17862.61 Latimia. 5392.88 270.98 270.98 MinPts 17866.17 17862.89 17833.36 299.40 299.40 MinPt-O-SF Ee . 14804.46II 17953.24 3372.97 MinPts 15347.55 15260 77 89.43 10228.96 3195.52 MinPt-CtCt 15522.3.MEE26101 15260.47 89.28 10243.61 3197.45 MinPS-0-EOU 15522.52 15347..'MEM 89.19 10251.13 3198.44 MinPt-O-ADP 1 15300.40 14989.40 14834.39 49.35 16848.50 3378.72 MinPt-0lCt 15301.15 14989.37 14833.97 49.23 16868.97 3378.89 MinPt-O-EOU I15308.39 14970.02 14801.32 45.37 17620.01 3374.85 MinPta 15307.61 14969.45 14800.87 45.40 17615.16 3374.88 MinPts 15330.51 14979.31 14804.2C 43.771 17953.53 3372.97 MinPt-O-SF IIIII '�.. 14981.72 14821 77 47.83 17136.57 3378.21 MinPt-CtCt 15308.2' 14969.'' 14801 45.37 17619.41 3374.86 MinPts 17865.84 17864.61 17833 03 14595.77 0.00 0.00 Surfac • e 0. 17863.0'Irk 6381.22 198.10 198.10 MinPts 14979.0 14803.9' 17953.83 3372.97 MinPts 14959.89 14783.73 43.46 18034.33 3371.92 MinPt-CtCt 15308.1' 14969.8 45.38 17618.81 3374.86 MinPts Emu -'1-.. ,miErmg 43.99 17905.10 3373.25 MinPts 15492.58 15125.88 14943...•=11:1M1 18579.89 3357.68 MinPt-O-SF MEOW 14991.48 14839.83 50.43 16648.09 3379.01 MinPt-CtCt 15330.01 14803.6.ma8188. 17954.14 3372.96 MinPts WREN EMMO ME= 43.46 18035.22 3371.91 MinPts ..1g= 14991.43 14839.75 50.42 16649.62 3379.00 MinPt-CtCt 15307.5. 14969.3' 14800.8. 45.40 17614.54 3374.89 MinPts !BMy ,MIMEO MEA 17954.45 3372.96 MinPts MIME 14959.83 14783.65 43.45 18036.13 3371.89 MinPt-CtCt • 15434.02 15116.92 14958.86 I 17096.86 3378.35 MinP1-0-SF MM. 14969.7.1 45.38 17817.60 3374.87 MinPts 14969.3 Egrum.mmim 17613.92 3374.89 MinPts MB=.11 MEEK 17954.76 3372.96 MinPts IIREMI 14983.45 14865.51 64.52 13703.70 3391.14 MinPt-CtCt 15307.8' 14969.6 mcnni 45.39 17817.00 3374.87 MinPts MEM 14979.9•mairEE 44.01 17901.43 3373.27 MinPts 15376.00 15024.96 14849.9 =gm 17963.56 3372.89 MinPt-OSF IIIEEEM Mann. 14865.37 63.23 14126.51 3390.60 MinPts 15307. - 14969.3. 14800.7 45.41 17612.47 3374.90 MinPts 15327.73 14978.78 14804.8 mmE 17893.52 3373.31 MinPt-O-SF 15581.78 15376.93 15275.0.16! 11449.16 3355.89 MinPt-O-SF 15998.73 15782.54 15674.''IIIMEE 12773.19 3412.89 MInPt-0SF 15908.32 15692.90 15585.6,MIME 12854.16 3412.35 MinPt-O-SF 15749.2,IMMIELEREIHIE 74.48 13024.88 3411.04 MinPts ..1=35 15536.80 15431.06 74.46 13025.85 3411.03 MinPt-CtCt EM 14969 35 14800.8' 45.43 17608.75 3374.93 MinPts 15327.500J 14978.60 14804.6. 0848 17892.13 3373.32 MinPt-O-SF I�15258.6 15027.93 14913.08 66,42 13369.70 3399.91 MinPt-CtCt 15307.1 14969.401 14801.01 45.45 17605.02 3374.96 MinPts 15327.26 14978.42 14804.49 44.061 17890.72 3373.33 MinPt-O-SF i E15313.291 14959.691 14783.38 43.42 18045.35 3371.71 MinPts 15327.02 14978.24 14804.33 44 071 17889.29 3373.34 MinP1-0SF [115313.311 14959.681 14783.36 43.42 18046.29 3371.69 MinPts 15328.79 14978.06 14804.19 44.07] 17887.83 3373.34 MinPt-O-SF • 15313.331 14959.681 14783.35 43.42 18047.24 3371.87 MinPts 15326.56 14977.88 14804.04 44.081 17886.36 3373.35 MinPt-O-SF _15313.361 14959.681 14783.34 43.42 18048.19 3371.65 MinPts 15326.32 14977.71 14803.90 44.09 17884.86 3373.36 MinPt-O-SF 15313.391 14959.691 14783.33 43.41 18049.14 3371.64 MinPts 15326.09 14977.54 14803.76 44.09A( 17883.34 3373.37 MinPt-OSF 1 15313.421 14959.691 14783.32 43 41 18050.10 3371.62 MinPts 15325.87 14977.37 14803.62 44101 17881.81 3373.38 MinPt-O-SF 1_15313.451 14959.701 14783.32 43.41 18051.06 3371.60 MinPts 15325.64 14977.21 14803.48 44.111 17880.25 3373.39 MinPt-O-SF 15313.49 14959.71 14783.32 43.40 18052.03 3371.58 MinPts 15313.53 14959.72 14783.32 43.40 18053.00 3371.56 MinPts • 15313.56 14959.7 14783.32 43.40 18053.97 3371.54 MinPts 15313.61 14959.7 14783.32 43.39 18054.95 3371.52 MinPts 15313.65 14959.7 14783.33 43.39 18055.93 3371.50 MinPts 15313.70 14959.7 14783.33 43.39 18056.91 3371.47 MinPts 15313.75 14959.8 14783.34 43.39 18057.89 3371.45 MinPts 15324.08 14976.11 14802.61 44.16 17868.77 3373.45 MinPt-O-ADP L 15313.801 14959. 14783.35 43.38 18058.88 3371.43 MinPts • 15323.87 14975.96 14802.50 44.17 17867.04 3373.46 MinPt-O-ADP Li 5313.851 14959.87 14783 37 43.38 18059.88 3371.41 MinPts 15323.65 14975 81 14802.39 44.18 17865.30 3373.47 MinPt-O-ADP Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 10 of 24 Offset Trajectory SeparationAllow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU ft Dev.(ftL Fact. MD(ft) TVD(ft) Alert I Minor I Major 15313.911 14959.90 14783.38 43.38 18060.87 3371.39 MinPts 15323.63 14975.80 14802.37 44.18 17865.12 3373.47 MinPt-O-ADP C15313.961 14959.93 14783.40 43.37 18061.88 3371.37 MinPts 15323.44 14975.67 14802.28 44.18 17863.54 3373.48 MinPt-O-ADP I 15314.04 14959.96 14783.42 43.37 18062.88 3371.35 MinPts 15323.23 14975.53 14802.17 44.19 17861.75 3373.49 MinPt-0-ADP I15314.081 14960.00 14783.44 43.37 18063.89 3371.32 MinPts 15323.02 14975.39 14802.06 44.20 17859.95 3373.50 MinPt-O-ADP I15314.151 14960.03 14783.47 43.36 18064.90 3371.30 MinPts 15322.81 14975.25 14801.96 44.21 17858.12 3373.51 MinPt-O-ADP I 15314.24 14960.07 14783.50 43.36 18065.91 3371.28 MinPts 15322.60 14975.11 14801.86 44.22 17856.28 3373.52 MinPt-O-ADP I15314.281 14960.12 14783.53 43.36 18066.93 3371.26 MinPts 15322.39 14974.98 14801.76 44.23 17854.41 3373.53 MinP1-0-ADP 1 15314.361 14960.16 14783.56 43.35 18067.95 3371.23 MinPts 15322.19 1497485 1480167 44.24 17852.53 3373.54 MinPt-O-ADP I15314.44 14960.21 14783.59 43.35 18068.97 3371.21 MinPts 15321.98 14974.72 14801.58 44.24 17850.62 3373.55 MinPt-O-ADP 15314.50 14960.26 14783.63 43.35 18070.00 3371,19 MinPts _15321.78 14974.59 14801.49 44.25 17848.70 3373.56 MinPt-O-ADP 1 15314.581 14960.31 14783.66 43.35 18071.03 3371.16 MinPts 15321.58 1497446 14801.40 44.28 17848.75 3373.58 MinPt-O-ADP I 15314.661 14960.36 14783.70 43.34 18072.06 3371.14 MinPts 15321.38 14974.34 14801.32 44.27 17844.78 3373.59 MinPt-O-ADP I 15314.751 14960.42 14783.74 43.34 18073.10 3371.12 MinPts 15321.18 14974.22 14801.23 44.28 17842.80 3373.60 MinPt-O-ADP I 15314.831 14960.47 14783.79 43.34 18074.14 3371.09 MinPts 15320.98 14974.10 14801.15 44.29 17840.79 3373.61 MinPt-O-ADP 1 15314.921 14960.53 14783.84 43.33 18075.18 3371.07 MinPts 15320.78 14973.98 14801.08 44.30 17838.77 3373.62 MinPt-O-ADP I15315.011 14960.60 14783.88 43.33 18076.23 3371.04 MinPts 15320.59 14973.87 14801.00 44.31 17836.72 3373.63 MinPt-O-ADP 1 15315.14 1496066 1478393 43.33 18077.28 3371.02 MinPts 15320.39 14973.76 1480093 44.32 17834.65 3373.64 MinPt-O-ADP 1 15315.10 14960.73 14783.99 43.32 18078.33 3371.00 MinPts 15320.20 1497365 14800.86 4433 1783257 3373.66 MinPt-O-ADP I 15315.24 14960.79 14784.04 43.32 18079.38 3370.97 MinPts 15320.01 14973.54 14800.80 44.34 17830.46 3373.87 MinPt-O-ADP 1 15315.30 14960.87 14784.10 43.32 18080.44 3370.95 MinPts 15319.82 14973.43 14800.73 44.35 17828.34 3373.68 MinP1-0-ADP I15315.40 14960.94 14784.16 43.31 18081.50 3370.92 MinPts 15319.63 14973.33 14800.67 44.36 17826.19 3373.69 MinPt-O-ADP 1 15315.54 14961.01 14784.22 43.31 18082.57 3370.89 MinPts 1531944 14973.23 1480061 44.37 17824.03 3373.70 MinPt-O-ADP 1 15315.64 14961.09 14784.28 43.31 18083.64 3370.87 MinPts 15319.26 14973.13 14800.55 44.38 17821.84 3373.72 MinPt-O-ADP I-_15315.84 14961.17 14784.35 43.31 18084.71 3370.84 MinPts 15319.07 14973.03 14800.50 44.39 17819.64 3373.73 MinPt-O-ADP f 15315.911 14961.25 14784.41 43.30 18085.78 3370.82 MinPts 15318.89 14972.93 14800.44 44.40 17817.42 3373.74 MinPt-O-ADP 1.15316.04 14961.34 1478448 43.30 18086.86 3370.79 MinPts 15318.71 14972.84 14800.39 44.41 17815.17 3373.75 MinPt-O-ADP I15316.14 14961.42 14784.56 43.30 18087.93 3370.76 MinPts 15318.53 14972.74 14800.34 44.42 17812.91 3373.77 MinPt-O-ADP I 15316.25 14961.51 1478463 43.29 18089.02 3370.74 MinPts 15318.35 14972.65 1480030 44.44 17810.63 3373.78 MinPts I 15316,37 14961.60 14784.71 43.29 18090.10 3370.71 MinPts 15318.17 14972.56 14800.25 44.45 17808.33 3373.79 MinPts 15316.49 14961.69 14784.79 43.29 18091.19 3370.68 MinPts 15317.99 14972.48 1480021 44.46 17806.01 3373.81 MinPts 1 15316.62 14961.79 14784.87 43.28 18092.28 3370.66 MinPts 15317.81 14972.39 14800.17 44.47 17803.67 3373.82 MinPts I15316.65 14961.82 14784.89 43.28 18092.60 3370.65 MinPts 1531764 14972.31 14800.14 44.48 17801.31 3373.83 MinPts 1 15316.74 14961.89 1478495 43.28 18093.37 3370.63 MinPts • 15317.47 14972.23 14800.10 44.49 17798.93 3373.84 MinPts 1 15316.87 14961.99 14785.04 43.28 18094.47 3370.60 MinPts 15459.03 15092.53 1490977 42.291 18520.25 3358.51 MinP1-0SF SD37-0$P1(P4b)(Def Plan) Paas 17885.34 17882. 17852.5 6242.32 250.80 250.80 • MinPts 17885.35 17882.4 17852.55 6206.30 259.12 259.12 MinPt-O-EOU t15208.12 15024.64 14933.41 83.35 1063442 3248.81 MinPt-CtC1 15208.16 15024.60114933.33 83.31 10639.02 3249.42 MinPt-O-EOU 15208.22 15024.61 14933.32 83.29 10641.65 3249.76 MinPt-O-ADP 15269.95 15084.03 14991.57 82.56 10816.46 3272.74 MinPt-O-SF 15407.31 15193.60 15087.24 72.4 13042.96 3410.88 MinPt-O-SF 15406.74 15193.05 15086.70 72.43 13043.16 3410.88 MinPts 15177.711 1491047 14777.34 57.00 15706.04 3394.54 MinPts 15177.71 14910.47 1477734 57.00 15706.04 339454 MinPt-O-ADP 15178.05 14910.79 14777.65 57.001 15706.19 3394.54 MinPt-OSF 15552.99 15290.33 15159.49 5943 15711.38 3394.53 TO 1788534 17884.23 1785253 1604566 0.00 0.00 Surface I17885.34 17882.491 17852.531 6275.911 248.55 248.55 MinPts SD37-DSP1 current(Non-Def Survey) Pass 17886.1 17877.96 17853.3 . 2189.61 250.81 250.81 MinPts 17885.9 17880.1.ECM 3063.37 281.29 281.29 MinPts 15226.82 15038.31 14944.6 illllllllllllljEl 10519.82 3233.75 MinPt-OSF 15207.06 15018.73 14925.1- 10569.45 3240.27 MinP1-0SF 1519843 15012.r. 14919.41 82.03 10629.44 3248.16 MinPt-O-ADP 15198. •MEDIZ 14919.42 82.06 10632.83 3248.58 MinPt-O-EOU 15012 07 14919.53 82.11 10637.73 3249.25 MinPt-CtCt Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 11 of 24 i Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 15439.30 15221.86 15113.64 71.33 13040.24 3410.91 MinPt-O-SF 15396.70 15182.321 15075.62 72.14 13042.39 3410.89 MinPt-O-ADP 15396.6 15182.311 15075.63 72.15 13042.41 3410.89 MinPt-O-EOU I 15396.651 1518234 15075.87 72.17 13042.45 3410.89 MinPt-CtCt 15253.98 14985.66 14851.99 57.06 15713.72 3394.53 TD I 15167.11 14899.98 14766.91 56.99 15707.78 3394.54 MinPt-CtC8 15167.11 14899.98 14766.91 56.98 15707.79 3394.54 MinPt-O-EOU 15167.11 14899.98 14766.91 56.98 15707.81 3394.54 MinPt-O-ADP 15180.92 14912.90 14779.356.8 15710.82 3394.53 MinPt-O-SF 15204.39 14935.87 14802 10 56.83 15712.47 3394.53 MinPt-O-SF 15190.30 14922.71 14789.41 56 97 15708.95 3394.54 MinPt-O-SF • 5120-N4(P4)(Def Plan) Pass 17868.90 17865.60 17836.09 WM= 279 38 279 38 MirPt-O-SF 17869.12 17865.83 17836.31®" 299.20 299.19 MinP1-O-SF 15435.04 15174.37 15044.5 ;1:11 15583.92 3394.91 MinPt-O-SF 17868.79 17867.56 17835.98 14598.18 0.00 0.00 Surface 15475.06 15106.74 14923.07111.31EI 18569.24 3357.78 MinPt-O-SF • • NEE= 15034.89 14835.31 38.67 19329.52 3351.97 MinPt-CtCt ' 15436.50 15031.63 14829.69 38.22 19438.28 3350.95 TD 15451.02 15133.7.Emmy 48.85 17072.99 3378.40 MinPt-O-ADP ( - 15102.98 14927.12 43.94 18064.66 3371.31 MinPt-CtCt 15455.71 M'M, 14927.05 43.93 18068.39 3371.22 MinPt-O-EOU 15455.73 15102..` '° 43.93 18069.63 3371.20 MinPt-O-ADP 14897.94 MIEMII 14839.74 86.94 10070.91 3174.75 MinPts 14897.96 14725.41 MI= 86.93 10071.63 3174.84 MinPt-O-ADP 15845.91 15644.00 15543.5 miric 11523.59 3364.89 MinPt-O-SF 16397.81 16185.06 16079.1 MEM 12101.63 3407.91 MinPt-OSF 15237.16 15024.07 14918.0. • 6 13135.52 3409.57 MinPt-O-SF • 15195.98 14982.94 14876.9.Mglin 13139.35 3409.49 MinPt-O-SF Foxis14982.7. 71.66 13139.39 3409.49 MinPts 15050 48{ 4799 41 14674.37 60.18 15214.74 3399.46 MinPts • 15050 48 14799.41 14799.41.11EMBEI 60.18 15214.87 3399.46 MinPt-O-ADP 15444.80® 1,1.1.2M 17428.71 3376.19 MinPts • SP16-FN3(P2)(Def Plan) Pass 15473.04 15067.87 14865.78 38.28 19438.28 3350.95 TD 17865.1 17861.88 17832.38 5376.84 268.15 268.15 MinPt-O-EOU • 17865.18 17861.8 17832.3 5389.06 271.00 271.00 MinPts 17865.43 17862.15 17832.6 5437.4 299.45 299.45 MinPt-O-SF Oa= 15350.33 15263.72 89.62 10211.56 3193.24 MinPt-CtCt 15524.7 EMIR 15263.49 89.50 10222.32 3194.65 MinPt-O-EOU 15524.89 15350.2'EMU 89.43 10228.92 3195.52 MinPt-O-ADP 16423.30 16206.87 16099.1-IMM 12102.58 3407.98 MinPt-O-SF MEM Vii.MIME M 15600.75 3394.75 MinPts 17865.10 17863.88 17832.29 14595.17 0.00 0.00 Surface ,ION..' r' •17862.3. 6380.60 198.10 198.10 MinPts ' 111122M.MMIE MEM�"'' 18575.19 3357.72 MinPts �"4 15194.02 15044.55 51.83 16651.10 3379.00 MinPt-CICt 15501.41 MEM 15034.72 49.93 16936.09 3378.59 MinPt-O-EOU mum 15181.98 15023.60 48.93 17151.91 3378.12 MinPt-CtCt 15499.7'NE Namm 48.93 17152.81 3378.12 MinPts 15178.23 15018.06 48.38 17248.20 3377.45 MinPt-CtCt 15505.1.mum. 15000.65 46.18 17811.65 3374.91 MinPt-O-EOU 15505.32 15168.5. 15000.61 48.17 17613.93 3374.89 MinPt-O-ADP 15158.98 14983.44 44.18 18038.28 3371.85 MinPt-CtCt 15511..'IIME. 14983.43 44.18 18040.46 3371.81 MinPrO-E0U ' 15511.05 15158.9:EMU 44.18 18041.56 3371.79 MinPt-O-ADP 15513.91 15161.65 14986.01 1=IMliq 18085.95 3370.81 MinPt-O-SF • 15847.49 15633.38 15526.8.wE4• 12936.94 3411.75 MinPt-O-SF 15757.8 op=�'- s 74.53 13035.31 3410.95 MinPts MilinirEj 15545.43 15439.73 74.53 13036.09 3410.94 MinPt-Ctet • 15493.20 15201,22 15055.72 53.24 16430.64 3384.22 MinPt-CtCt MEM®MEM 40.88 18890.60 3355.67 MinPts S120-N4PB1(P1)(Def Plan) Pass • 17868.i.sannEE EmmE 566249 251.08 251.08 MinPts 17868.90 17865.60 17836..emlum 279.38 279.38 MinPt-O-SF 17869.12 17865,83 17836.31=ma 299.20 299.19 MinPt-O-SF 15171.44 14958.41 14852. % illE 13142.30 3409.42 MinPt-O-SF 15169.6 71.56 13143.30 3409.40 MinPts 15169.6 14956.71 14850.72 71.56 13143.33 3409.40 MinPt-CtCt 6. 00 14774.09 14649.20 60.15 15202.74 3399.60 MinPt-CtCt 15024.:.MI6EZIi0 14649.20 60.15 15202.86 3399.60 MinPt-O-EOU 15024.87 14774..a 11111111 60.15 15202.92 3399.60 MinPt-O-ADP 15028.52 14777.58 14652.61 NEM 15206.81 3399.55 MinPt-O-SF 15435.04 15174.37 15044.53 maxisl 15583.92 3394.91 MinP1-0SF 15666.75 15407.34 15278.13 60.62 15609.13 3394.70 TD 17868.79 17867.56 17835.98 14598.18 0.00 0.00 Surface I 14882.65 14708.65 14622.23 86.10 10155.97 3185.93 MinPt-CtCt 14882.69 14708.62 14622.17 86.07 10159.91 3186.45 MinPt-O-EOU 14882.73 14708.63 1462216 86.06 10161.88 3186,71 MinPt-O-ADP 14919.86 14744.07 14656.70( 85.371 10295.31 3204.24 MinPt-O-SF SI13-FN4(P2)(Def Plan) Pass 15645.23 15240.07 15037.97 38.71 19438.28 3350.95 TD 17862 98 17859.66 17830.18 5371.08 268.21 268.21 MinPt-O-EOU 17862.98 17859 66 17830.1 5384.15 271.06 271.06 MinPts 17863.23 1785994 17830.4 5434.401 299.60 299.60 MinPt-O-SF 15365.87 15279.74 90.20 10165.07 3187.13 MinPt-CtCt 15539.3'ME= 15279.54 90.08 10174.91 3188.42 MinPt-O-EOU 15539.45 15365.81 MMES. 90.04 10178.94 3188.95 MinPt-O-ADP 16750.95 1653451 16426.71® 12100.86 3407.86 MinPt-O-SF 16796.27 16579 11 16471 02-' 12301.11 3415.34 MioP1-0SF Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 12 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 17862.90 17861.67 17830.09 14593.37 0.00 0.00 Surface 17882.9. 17860.0'MEM 6378.74 198.10 198.10 MinPts LEIZIECE Mil=ME= 4264 18572.13 3357.75 MinPts 15621.28 15253.97 15070.81 MB= 18577.45 3357.70 MinPt-O-SF Imam ® 52.09 18651.33 3379.00 MinPts 15270.48® 49.19 17164.35 3378.04 MinPts '11111.-- --1 15341.00 15168.21 45.39 17836.57 3373.63 MinPt-CtCt 15263.15 1508741 44.42 18131.88 3369.58 MinPt-CtCt 15617.7'NI= 15085.87 44.12 18188.07 3367.92 MinPt-O-EOU 15625.28 15264.'.ME= 43.41 18323.09 3363.96 MinPt-O-ADP 15809.89 15596.97 15490." ZEE 13010.24 3411.16 MinP1-0SF 15782.3 �' 4 IliIMMEE 74.71 13047.07 3410.85 MinPts OD= 15570.15 15464.53 74.71 13047.40 3410.84 MinPt-CtCt 15273.63 15138.19 57.39 15892.36 3394.25 - MinPt-CICt 15549.2.MENIZE. 15133.28 58.20 18048.53 3394.00 MinPt-O-EOU 15550.91 NEM 15130.26 55.58 16140.08 3392.73 MinPt-0-EOU . 15558.38 15271.7• 54.47 16291.40 3388.30 MinPt-O-ADP Milli=11113M5 18905.30 3355.58 MinPts SP12-SE3(P2)(Def Plan) Paw 17861.06 17857.73 17828.25 5365.64 268.26 268.26 MinPt.O-EOU 17861.05 17857.73 17828.25 5379.52 271.12 271.12 MinPts 17861.30 17858.01 17828.4 5431 A9 299.75 299.74 MinPt-O-SF 1 15556.55 15384.26 15298.64 90.85 10114.28 3180.45 MinPt-CtCt 15556.64 15384.191 15298.50 80.77 10121.58 3181.41 MinPt-O-EOU 15556.69 15384.2 15298.4 90.74 10123.44 3181.65 MinPt-O-ADP 16175.91 15974.59 15874.4 80.74 11480.81 3359.92 MinPl-0SF 17860.97 17859.74 17828.16 14591.79 0.00 0.00 Surface MEM 17858.1 EMCEE 6377.03 198.10 198.10 MinPts MEMO 15357.20 15174.12 42.94 18598.15 3357.54 MinPt-CtCt 15722.9 15332.96-/1 15138.44 40.41 19106.04 3354.08 MinPt-CtCt 15724..' 15331.74 15136.14 40.18 19156.17 3353.61 MinPt-O-EOU 15725.12 15331.98 15135.91 40.10 19175.44 3353.42 MinPt-0-ADP 15795.92 15394.12 15193.71 39.411 19365.46 3351.84 MinPt-0SF 15826.44 15424.28 15223.66 39.45 19372.89 3351.57 TD 15726.98 15395.31 IMME111 47.56 17499.46 3375.69 MinPt-O-ADP 15735.44 15383.52 15208.05'.1 18075.74 3371.06 MinPt-O-SF 15733.01 15368.71 15187.06 43.30 18407.18 3381.49 MinPt-CtCt 15733.48 15367.471 15184. 43.10 18445.47 3380.36 MinPts 15825.09 15482.74 15312. 46. 17744.19 3374.15 MinPt-0SF 16088.32 15720.68 15537. 43. 1845544 3360.07 MinPt-O-SF Nom 15904.32 15751.29 52.97 16766.61 3378.84 MinPt-CtCt 15831.37 15618.82 15513..'=go 13031.88 3410.98 MinPt-O-SF 15809.9'II=IIIIMMIC 74.92 13057,76 3410.75 MinPts 15809.9. 15597.95 15492.45 74.93 13058.06 3410.75 MinPt-CtCt itiziEE 16360.37 16249.95 75.08 13118.09 3409.93 MInPt-CtCt 18582.3• 16360.28 16249.71 75.00 13128.85 3409.72 MinPt-O-EOU 16582.46 163602 18249.8' 74.98 13133.34 3409.62 MinPt-O-ADP 15589. 1532291 15190.19 58.72 15744.73 3394.48 MinPt-CtCt 15590.24 15322.12 15188.55 58.36 15790.98 3394.41 MinPt-O-EO1J 15591.57 15322.40 15188.30 58.13 15820.05 3394.36 MinPt-O-ADP 15618.98 15339.40 15200.10 56.06 16108.29 3393.50 MinPt-O-ADP 15685.51 15388.51 15240.51 52.94 18580.61 3380.41 MinPt-O-SF 15728.0 15354.78 15168.62 42.2 18736.09 3356.66 MinPts 16430.911 18185.74 16063.84 67.28 14534.09 3382.98 MinPt-O-EOU 16430.98 16185.75 16063.6 67.27 14537.41 3382.92 MinPt-0-ADP 18443.56 16190.4 16064. 65.21 14940.09 3396.65 MinPt-O-ADP I 15731.48 15351.66 15162.2 41.531 18880.82 3355.73 MinPts SP10-FN5(P2)(Def Plan) Pass I15851.351 15468.571 15277.64 41.521 18940.06 3355.35 MinPts 15946.06 15540.86 15338.75 39.45 19438.28 3350.95 TD 17859.5 17856.24 17826.76 5360.23 268.30 268.30 MinPt-O-EOU 17859.57 17856.24 17826.76 5375.06 271.17 271.17 MinPts 17859.81 17856.52 17827.00 5429.41 299.85 299.85 MinPt-O-SF mann 15391.31 15305.91 91.12 10092.37 3177.57 MinPt-CtCt 15563.2 Ma= 15305.77 91,04 10098.91 3178.43 MinPt-O-EOU 15563.29 15391.2 �• `.., 91.02 10100.57 3178.65 MinPt-O-ADP 16305.32 16104.38 16004.4.MIK.DM 11450.96 3356.13 MinPt-O-SF 1728161 17065.17 16957..• IljE 12097.72 3407.64 MinPt-0SF 17344.37 17127.15 17019.0.MIR 12297.72 3415.35 MinPt-O-SF .1=1:E MaMEE 15562.65 75.65 13077.13 3410.56 MinPts 17859.48 17858.26 17826.67 1459057 000 0.00 Surface 17859.4: 17856.6,MEM 6375.79 198.10 198.10 MinPts EMILE may;Mi=i1 43.11 18598.21 3357.54 MinPtu MEM MIEEDIM NIMBI 5276 16643.09 3379.02 MinPts EIKEIE WM=MIME 49.82 17162.34 3378.06 MinPts 15841.40 15628.95 15523.21 11111K133 13043.32 3410.88 MinPt-O-SF 15821.56 15609.6.MIME 75.00 13063.47 3410.70 MinPt-O-ADP 15821.5 15609.6 15504.15 75.00 13063.72 3410.70 MinPt-O-EOU 1113110. 15609.62 15504.16 75.00 13083.97 3410.70 MinPt-CtCt 15609.1 15345.30 15213.87 59.38 15869.94 3394.80 MinPt-CtCt 15609.58 mazamo 15213.02 59.19 15693.29 3394.56 MinPt-O-EOU 15610 28 15345.01 mono 59.06 15708.95 3394.54 MinPt-O-ADP S108-F N6(P2)(Def Plan) Pass 15991.4 1111EDIEI®]MIEI 18958.09 3355.24 MinPts 1615444 15749.18 15547.04 39.96 19438.28 3350.95 TD 17858.35 17855.06 17825.5.4 5427.34 299.95 299.95 MinPt-O-SF 1 15556.49 15384.9-4/ 15299.69 91.24 10074.82 3175.26 MinPt-CtCt 15556.54 15384 15299.58 91.19 10079.21 3175.84 MinPt-O-EOU 15556.57 15384. 15299.57 91.17 10080.70 3176.04 MinP1-0-ADP 18509.88 16308.84 16208.91 82.80011145080 3356.11 MinPt-0SF 17802.64 17586.39 17478.76 82.7 12097.46 340762 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 13 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 15866.86 15655 79 15550.75 75.52 13079.61 3410.53 MinPts 17858.01 17856.75 17825.20 14589.38 0.00 0.00 Surface 15890.96 -MEM 43.32 18597.34 3357.54 MinPts 15873.08 MENSEmlinga 53.06 18645.45 3379.01 MinPts � 15903.89': 50.15 17182.68 3378.05 MinPts 15836.72 15624.36 15518.6,M"' 13055.23 3410.78 MinPt-O-SF 15819.94 15608.0.MEM 75.00 13070.02 3410.64 MinPI-0-ADP - •-•1 15608.0. 15502.56 75.00 13070.22 3410.63 MinPts IME 15353.19 15222.73 59.84 15613.12 3394.69 MinPl-CtCt 15615,1 ELTEEEN 15222.60 59.81 15615.15 3394.68 MinPt-O-EOU 15615.40® 15222.47 59.76 15621.22 3394.67 MinPt-O-EOU 15615.74 15353.19 EMU 59.70 15628.39 339466 MinPt-0-ADP 0107-004(P2)(Def Plan) Pass 16697.90 16346.54 16171.35 47.65 17989.42 3372.62 MinPts 16488.91 16084.04 15882.10 40.82 19438.28 3350.95 TD 16880.63 16528.88 16353.4•MIME 18005.07 3372.41 MinPt-OSF 17857.•• 1782463 5352.07 268.36 268.36 MinPt-0-EOU MOM 17854 11: 17824.62', 5368.32 271.23 271.23 MinPts 17857.68 17854.39 17824.87'1M r-, 300.00 300.00 MinPt-O-SF 16188.48:�l®1 51.21 17081.67 3378.38 MinPts 15580.95 15410.14 15325.27 91.79 10042.25 3170.98 MinPt-CtCt 15580.9:M1Z1M 15325.20 91.75 10045.03 3171.35 MinPt-0-EOU 15581 02 15410.11j60 91.73 10046.43 3171.53 MinPt-O-ADP 16700 20 16500.35 16400.92 83 97 11427.35 3353.03 MinPt-O-SF 16190.39 INEEMIESSEC 51.22 17080.28 3378.39 MinPts 16883.49 16531.73 16356.34® 18005.43 3372.41 MinP1-0-SF p15O>a � 890 . ' 75.70 13080.52 3410.51 MinPts 16190 39i�: y,MIME. 51.21 17081.04 3378.38 MinPts 16529 74 16178.46 16003.31 MEM 17989.54 3372.62 MinPt-O-SF 17857.34 17856.12 17824.53 14588.83 0.00 0.00 Surface 17857. 17854. 17824.53 6373.97 198.10 198.10 MinPts 16009.8 15642.4 15459.23 43.69 18599.66 3357.53 MinPts 16000.7 15700.8 15551.48 53.54 16648.71 3379.01 MinPts 16535.08 16183.80 16008.65 47.2 17989.29 337262 MinPt-O-SF 16097.24 15787,15 15632.6 52.0 16905.25 3378.64 MinP1-0SF I16098.71 15788.1 15633.92 52.06 16908.84 3378.63 MinPts 16030. 15712. 15554.19 50.60 17162.58 3378.05 MinPts 16537.75 16186.47 16011.33 47.211 17989.18 3372.62 MinPt-O-SF 16030.31 15712.48 15554.03 50.5881 17165.54 3378.03 MinPts 16237.20 15900.78 15733.06 48.41 17613.85 337490 MinPt-O-5F 16349.17 16010.18 15841.17 48.3 17668.06 3374.58 MinPt-O-SF 1 16351.521 16012.461 15843.42 48.366���aaa 17669.77 3374.57 MinPts 16422.03 16081.19 15911.26 48 17712.28 3374.33 MinPt-O-SF I16359.01 16007.1 15832.32 46.6 18007.18 3372.38 MinPts 16127.0 15775. 15599.52 45. 18080.32 3370.95 MinPts 17162.40 16794.80 16611.49 46.81 18455.35 3360.07 MinPt-OSF . 1 16983.82 16783.171 16683.34 85.06 11467.03 3358.20 MinPts 15864.58 15652.50 15546.96 75.11 13061.97 3410.72 MinP1-0SF 15849 15637,861 15532.51 75.22 13073.42 3410.60 MinPts I 15849.5 15637.86 15532.51 75.22 13073.60 3410.60 MinPt-CtCt 16559.27 16207.99 16032.: MEM 17988.41 3372.63 MinPt-0SF 17733. 17513.46 17403.74 80.81 13118.52 3409.92 MinPt-CtCt 17734.01 17513. 17403.52 80.73 13128.45 3409.72 MinPt-O-EOU 17734.12 17513.3 17403.51 80.69 13132.58 3409.64 MinPt-0-ADP ORME 15387.98 15257.90 60.15 15603.60 3394.73 MinPt-CICt 15649.16 MEM 15257.85 60.13 1560448 3394.72 MinPt-O-EOU 15649.23 15387.97 MMil 60.12 15605.38 3394.72 MinPt-O-ADP . 16561.97 18210.70 16035. wariz 17988.33 3372.63 MinPt-O-SF 16097.8'MEM ME=1111111=0 18506.86 3358.78 MinPts SP05-FN7(P2)(Def Plan) Pass 16271.221 15886.21 15694.21 42.37 18988.32 3355.05 MinPts 16485.47 1608027 15878.17 40.78 19438.28 3350.95 TD 17855.33 17852.00 MinPt-O-EOU 17855.33 17852.00 17822.517822.53 5364.475347.76 271.30268.41 271.30268.41 MinPts 17855.57 17852.28 17822.7 5423.8 300.16 300.16 MinPt-O-SF 15589.46 15419.06 15334.39 9206 10020.18 3168.08 MinPt-CtCt 15589.5'MEM. 15334.33 92.02 10022.73 3168.42 MinPt-0-EOU 15589.53 15419."Nammiz 92.01 10024.02 3168.59 MinPt-O-ADP ) 16957.59 16756.73 16656.7!min 11450.83 3356.11 MinP1-0SF 18540.09 18324.24 18216.81 MDEE 12060.94 3405.08 MinPt-O-SF r'15902.6 NE=Min 75.76 13083.93 3410.47 MinPts . 17855.24 1785401 1782243 14587.11 0.00 0.00 Surface 'MM 17852...1 r' 6372.17 198.10 198.10 MinPts 17855.5'®I 17822.69 5329.12 243.10 243.10 MinPt-O-EOU �. ,LISESIM�•0 43.90 18599.73 3357.53 MinPts MEIMEEI=DM 1 53.86 16648.41 3379.01 MinPts mum maamm15676.26 50.94 17162.88 3378.05 MinPts 16411.94 16075.10 15907.1: 48.86 17613.83 3374.89 MinPt-O-SF 15877.51 1566544 15559.98 al 13088.01 3410.66 MinPI-0SF 15862.56 156508.I�'� 75.29 13077.84 3410.55 MinPts .11=2' 1565089 15545.55 75.29 13078.00 3410.54 MinPt-CtCt 15666. , 15405.56 15275.65 60.30 15595.20 3394.79 MinPt-CtCt 15666.38 MI= 15275.58 60.28 15596.21 3394.78 MinPt-O-EOU 15666.41 15405.53 EMED 60.27 15596.56 3394.78 MinPt-O-ADP SP18-N5(P4)(Def Plan) Pap 16660.16 .4. 16161.8:MEE 17469.83 3375.90 MinPts 17866 69 17863 39 17833.8:1I 279.25 279.24 MinPt-O-SF 17866.90 1786362 17834.09 5441.00 299.12 299.12 MinPt-O-SF I 15455.09=saw® 90.44 10098.90 3178.43 MinPts 15157.85 14944.97 14839.02 MEV 13193.08 3408.05 MinPt-O-SF �• 1494496 1483901 71 53 13193.39 340804 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 14 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft). EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 15049.27 14803.755J 1468148 61.54 15040.62 3400.20 MInPI-C1Ct 15049.28 14803.75 14681.45 61.53 15041.36 3400.21 MinPt-O-EOU 15049.31 14803.7 14681.45 61.53 15042.10 3400.22 MinPt-O-ADP 15480.09 15219.70 15089.9,`,11 59.671 15583.01 3394.92 MinPt-O-SF 17866.57 17885.35 17833.77 14596.37 0.00 0.00 Surface .= 16284.20 16099.85 45.17 18598.66 3357.53 MinPt-CtCt 16656.8 16250.84 16048.33 41.12 19420.79 3351.11 MinPt-ClCt 16656.86 16250.07 16047.17 41.04 19438.28 3350.95 TD 16615.93 16314.02 16163.56 55.21 16648.37 3379.01 MinPt-CtCt 16628.40 16308.53 16149.09 52.14 17162.18 3378.06 MinPt-CtCt 16654.15 16299.46' 16122.61 47.08 18129.15 3369.65 MinPts 16654.15 16299.'•'•11 16122.58 47.08 18129.63 3369.64 MinPts 14793.98 14627.14 14544.34 89.33 9759.51 3133.82 MinPt-CtCt 14793.98 14627.131 14544.32 89.32 9760.34 3133.93 MinPts 14903.06 14734.13 14650.30 88.88 9869.15 3148.23 MinPt-OSF 17770.27 17552.72 1744444 82.0 12100.71 3407,85 MinPt-O-SF I 15410.81 15198.001 15092 07 72.73 13220.36 3407.13 MinPts SP04-SE5(P2)(Def Plan) PM 16735.66 MEM 16238.24IrrI�� 17498.71 3375.70 MinPts MIME 16657.46��1� 17623.49 3374.83 MinPts 17854.92 17851.63 17822.1 a 300.21 300.21 MinPt-O-SF ME=MIME 16270.6 53.29 17028.29 3378.46 MinPts 17198.38 16846.69 16671. • 1, 18015.79 3372.25 MinPt-O-SF 15578.82 15408.51-/1 15323.89 92.04 10012.88 3167.12 MinPt-CtCt 15578.84 1540844 15323.83 92.01 10015.06 3167.41 MinPt-O-EOU 15578.88 154084 15323.82 92.00 10016.16 3167.55 MinPt-O-ADP 16827.08 16635.17 16539.71 88.13 11034.41 3301.38 MinPt-O-SF 16743.05 16425.55 16267.29 52.89 17092.29 3378.36 MinPts 16738.92 16406.89 16241.36 50.56 17501.03 3375.68 MinPts 15885.04 15673.95 15568.89 75.60 13085.29 3410.45 MinPts 17202.25 16850.56 16675.21 49.05 18015.67 3372.25 MinPt-O-SF 16746.38 16428.88 16270.63 52.91 17091.83 3378.37 MinPt-O-SF 1[116742.201 16410.071 16244.49 50.56 17503.33 3375.67 MinPts 17854.59 17853.37 17821.78 14586.58 0.00 0.00 Surface L16749621 16434.271 16277.08 53.28 17030.72 3378.46 MinPts 17206.12 18854.44 16679.09 49.01 18015.55 3372.25 MinPt-O-SF 16745.4 16413.251 16247.63 50.5 17505.62 3375.65 MinPts 16445.35 16092.44 15916.48 46.73 18130.22 3369.62 MinPt-CtCt 17210.00 16858.31 16682.96 49.071 18015.44 3372.25 MinPt-O-SF 1 16299.931 15931.931 15748.43 4441 18598.22 3357.54 MinPts 16590.39 16203.37 16010. 42.9 19030.36 3354.78 MinPt-0SF 16915.74 16517.46 16318.82 42.58 19286.81 3352.38 MinP1-0SF 17393.71 16990.23 16788.99 43.21 19406.42 3351.25 TD I 16364.491 16064.171 15914.50 54.67 16647.41 3379.01 MinPts 16753.05 16435.57 16277.33 52.93 17090.91 3378.37 MinPt-O-SF I 16748.761 16416.44 16250.78 50.55 17507.90 3375.64 MinPts 17213.87 16862.19 16686.84 49.08 18015.34 3372.25 MinPt-O-SF 16411.07 16092.79 15934.14 51.72 17162.86 3378.05 MinPts 16752.05 16419.64 16253.93 50.54 17510.18 3375.62 MinPts 16411.07 16092.74 15934.07 51.71 17164.30 3378.04 MinPts 17217.75 16886.07 16690.72 49.0418015.23 3372.26 MinPt-O-SF I 16758.661 16426.071 16260.26 50.54 17514.65 3375.59 MinPts 17225.52 16873.84 16698.49 49.12 18015.04 3372.26 MinPt-O-SF I16761.971 16429.29( 16263.44 50.53 17516.87 3375.57 MinPts 17229.40 16877.73 16702.38, 49.13 18014.94 3372.26 MinPt-O-SF 18036.63 17669.45 17486.35 49.25 18455.15 3360.08 MinPt-O-SF 1 16765.291 16432.521 16266.62 50.53 17519.08 3375.56 MinPts 17233.29 16881.62 16706.27 49.14 18014.85 337226 MinPt-O-SF I 16768.611 16435.71 16269.82 50.52 17521.27 3375.54 MinPts 17237.19 16885.51 16710.17 4915 18014.76 3372.26 MinPt-0SF I 16771.94 16439.061 16273.02 50 52 17523.46 3375.53 MinPts 17241.08 16889.41 16714.07 49.16 18014.68 3372.26 MinPt-O-SF I16780.01 16462.60 16304.38 53.02 17087.34 3378.37 MinPts 16775.2 16442.2 16276.22 50.52 17525.62 3375.51 MinPts 15867.07 15655.05 15549.53 75. 3 13075.83 3410.57 MinPt-O-SF 15854.6 15643.001 15537. 75.24 13081.88 3410.50 MinPts 15854.6 15643.00 15537.65 75.24 13081.79 3410.50 MinPt-CtCt 17244.98 16893.31 16717 96 49.17 18014.60 3372.27 MinPt-O-SF 16783.42 16466 16307 79 53.04 17086.90 3378.38 MinPts 16778.63 164456 16279.44 50.51 17527.78 3375.50 MinPts 15662.47 15402.02 15272.29 60.36 15586.90 3394.87 MinPt-CtCt 15662.48 15402.01( 15272.27 60.36 15587.14 3394.87 MinPt-O-EOU 15662.50 15402. 15272.27 60.35 15587.39 3394.87 MinPt-O-ADP 17248.88 16897.21 16721.87 49.181 18014.52 3372.27 MinPt-O-SF I16781.9 16448.71 16282.66 50.51 17529.92 3375.48 MinPts 16447.8 16094.761 15918.73 46.71 18133.58 3389.52 MinPts 17252.78 16901.11 16725.77 49.19 18014.45 3372.27 MinPt-O-SF I16413.72' 16095.26 15936.52 51.70 17167.57 3378.02 MinPts 16785. 16452. 16285.88 50.51 17532.05 3375.47 MinPts 17258.69 16905.02 16729.68 49.21 18014.38 3372.27 MinP8-O-SF I16416.31 16097.78 15938.98 51.68 17170.83 3378.00 MinPts 16788.7 16455.3'41 16289.12 50.50 17534.16 3375.45 MinPts 17260.59 16908.93 16733.59 49.22 18014.31 3372.27 MinPt-O-SF I16419.01 16100.30 15941.43 51.67 17174.09 3377.97 MinPts 16792.0 16458.6 16292.36 50.50 17536.26 3375.44 MinPts 17284.50 16912.84 16737.50 49.23 18014.25 3372.27 MinPt-O-SF I16421.69' 16102.83' 15943.89 51.66 17177.35 3377.95 MinPts 16795. 16461. 16295.61 50.50 17538.35 3375.42 MinPts 17268.42 16916.75 1674141 49 24, 18014.19 3372.27 MinPt-O-SF I 16424.34 16105.351 15946.34 5164 17180.62 3377.93 MinPts 16798.83 16465.20 16298.87 50 501 17540.42 3375.41 MinPt-OSF s. 17272.33 16920.67 16745.33 45.251 18014.14 3372.27 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 15 of 24 Offset Trajectory L Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft EOU(ftDev.(ft) Fact. MD(ft) 1 TVD(ft) Alert 1 Minor I Major 16427.001 16107.871 15948.801 51.63 17183.88 3377.90 MlnPts 16802 22 16468.50 16302.131 50.491 17542.47 3375.39 MinPt-O-SF 17272.82 16921.16 16745.821 49.251 18014.13 3372.27 MinPt-O-SF 16429.6611 16110.401 15951.26( 51.62 17187.14 3377.88 MlnPts 16805.62 16471.82 16305.41 50.491 17544.52 3375.38 MinPt-O-SF 17276.25 16924.58 16749.24 49.261 18014.08 3372.27 MinPt-O-SF L 16432.320 16112.920 15953.72 51.60 17190.41 3377.86 MinPts 16809 02 16475.14 16308.681 50.491 17546.55 3375.36 MinPt-O-SF 17280.17 16928.50 16753 161 49.271 18014.03 3372.27 MinPt-O-SF 11 16434 984 16115.45 15956.171 51 59 17193.67 3377.84 MinPts 16812 43 16478.46 16311.971 50 491 17548.57 3375.35 MinPt-O-SF 17284.09 16932.42 16757.091 49 281 18013.99 3372.28 MinPt-O-SF 16437.63 16117.97 15958.631 51.58 17196.93 3377.81 MinPts 16815.85 16481.80 16315 26 50.49 17550.57 3375.34 MinPt-0SF 17288.01 16936.35 16761.01 49.30 18013.94 3372.28 MinPts 16440.29 16120.5 15961.09 51.56 17200.19 3377.79 MinPts 16819,27 1648514 16318.56 50.4 17552.56 3375.32 MinPt-O-SF 17291941 16940.271 16764.94 49.31 18013.90 3372.28 MinPts 1682820 16510.871 16352.691 53.19 17081.56 3378.38 MinPts 16442.95 16123,021 15963.551 51.55 17203.46 3377.77 MinPts 16822.69 16488.48 16321.87 50.48 17554.53 3375.31 MinPt-O-SF 16831.68 16514.42 16356.27 53.21 17079.61 3378.39 MinPt-O-SF 17295.86 16944.2 16768.86 49.3 18013.87 3372.28 MinPts 16831.6 16514.36 16356.19 53.2 17081.18 3378.38 MinPts 16445.61 16125.5 15966.01 51.54 17206.72 3377.74 MinPts 16826.13 16491.84 16325 18F 50.481 17556.49 3375.30 MinPt-O-SF 16755.35 16422.85 16257.10 50.541 17512.41 3375.60 MinPt-OSF 1 16763 6111 16411.3911 16235.77 47 721 18053.60 3371.54 MinPts 1 16448 2711 16128.0711 15968.461 51.52 17209.98 3377.72 MinPts 16829.57 16495 20 16328.50 50.481 17558.44 3375.28 MinPt-O-SF 1 16836.3 16484.3011 16308.751 47 951 18043.32 3371.75 MinPts 1 16450.9 16130.6011 15970.921 51.51 17213.24 3377.70 MinPts 16833.01 16498.56 16331.83 50.481 17560.37 3375.27 MinPt-O-SF 16839.78 16487.701 16312.151 47.961 18042.88 3371.76 MinPts 16453.60 16133.131 15973.381 51.50 17216.51 3377.68 MinPts 16836.46 16501.94 16335.16 50.471 17562.29 3375.25 MinPt-O-SF I16843.171 16491.1 16315.55 47.971 18042.46 3371.77 MlnPts 16456 26 16135.6 15975.84 51.48 17219.77 3377.65 MinPts 16839.92 16505.31 16338.50 50.471 17564.20 3375.24 MinPt-O-SF 16846.57 16494.5 16318.96 47.981 18042.03 3371.78 MinPts 16458.92 16138.1 15978.30 51.47 17223.03 3377.63 MinPts 16843.38 16508.70 16341 85 50.471 17566.09 3375.23 MinPt-O-SF 1 16849.9 16497 9211 16322 381 47 991 18041.61 3371.78 MinPts 1 16461. 16140.7111 15980 761 51 46 17226.30 3377.61 MinPts 16846.85 16512.09 16345.211 50 471 17567.96 3375.22 MinPt-O-SF 1 16853.40 16501.3,1 16325 801 48.001 18041.19 3371.79 MinPts F16464.25 16143 2411 15983.221 51 44 17229.56 3377.58 MinPts 16850.33 16515.49 16348.57 50.471 17569.82 3375.20 MinPt-O-SF 1 16856 8211 16504.771 16329.23 48.011 18040.77 3371.80 MinPts 1 16466.9111 16145.771 15985.68 51.43 17232.82 337756 MinPts 16853.81 16518.90 16351.94 50.47 17571.67 3375.19 MinPt-O-SF 1 16860.2511 16508.2011 16332.6711 48.0 18040.36 3371.81 MinPts 1 16469 5811 16148.2911 15988.1511 5142 17236.08 3377.54 MinPts 16857.29 16522.31 16355.31 50.47 17573.51 3375.18 MinPt-O-SF 16863.61 16511.644�ryerye 16336.11 48 03 18039.95 3371.82 MinPts 16472. 16150.82 15990.61' 5140 17239.35 3377.52 MinPts 16860.79 16525.73 16358.6r. 50.471 17575.33 3375.16 MinPt-O-SF 16867.1 16515." 16339.56', 48.r, 18039.55 3371.82 MinPts 16474.911 15993.07 51.39 17242.81 3377.49 MinPts 16864 28 16529.15 16362.08 50.4 17577.13 3375.15 MinPt-O-SF 1Z11511=41 16343.01 48.r. 18039.14 3371.83 MlnPts 1 15995.531 51.38 17245.87 3377.47 MlnPts 16867 79 16532.58 16365.47 50.471 17578.93 3375.14 MinPt-O-SF 1 16874.0211 16522.0011 16346.471 48.071 18038.74 3371.84 MlnPts 1 16480.2411 16158.4211 15998.001 51.36 17249.13 3377.45 MlnPts 16871.30 16536.02 16368.881 50.471 17580.70 3375.13 MinPt-O-SF 1 16877.44 16525.4611 16349.941 48.081 18038.35 3371.85 MlnPts 1 16482.901 16160.9511 16000 461 51.35 17252.40 3377.42 MinPts 16874.81 16539.46 16372.28 50.471 17582.47 3375.11 MinPt-O-SF 16880.951 16528.931 16353 42 48.091 18037.95 3371.85 MinPts 16485.57 16163.481 16002.92 51 34 17255.66 3377.40 MinPts 16878.33 16542.91 16375.70 50 47 17584.22 3375.10 MinPt-O-SF 16884.42 16532.41 16356.90 481 18037.56 3371.86 MinPts 16488.24 16166.01 16005 39 51.32 17258.92 3377.38 MinPts 16881.86 16546.37 16379.1 50.4 17585.95 3375.09 MinPt-O-SF r 16887.90)6535.891 16360. 48.11 18037.18 3371.87 MinPts If 16490.91 16168 5 16007.8 51.31 17262.18 3377.36 MinPts 16885.39 16549.83 16382.54 50.471 17587.87 3375.08 MinPt-O-SF 16891.38 16539.381 16363.88 481•`,1 18036.79 3371.88 MinPts 1 16493.57) 16171.0811 16010.32 51.30 17265.45 3377.33 MinPts 16888 93 16553.30 16385.98 50.471 17589.38 3375.07 MinPt-O-SF 16894.671 16542.8811 16367.371 48.131 18036.41 3371.88 MinPts "116486.241 16173.6111 16012.791 51.28 17268.71 3377.31 MinPts 1689247 16556 77 16389.421 50.471 17591.07 3375.05 MinPt-O-SF 16898.37 16546.381 16370 881 48.141 18036.03 3371.89 MinPts 16498.91 16176.1 16015.25 51.27 17271.97 3377.29 MinPts 16896.02 16560.25 16392.86 50 471 17592.75 3375.04 MinPt-O-SF 1 16901.87 16549.8411 16374.39 4815) 18035.66 3371.90 MinPts 16501.58 16178 64 16017.72 51.26 17275.24 3377.26 MinPts 16899.57 16563.74 16396.32 50.471 17594.41 3375.03 MinPt-O-SF 16905.3e 16553.4 16377.91 48.161 18035.29 3371.90 MinPts 16504.25 1618121 16020.19 51.24 17278.50 3377.24 MinPts 16903.13 16567.23 16399.771 50.4711 17596.06 3375.02 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 16 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 17221.63 16869.95 1669461 49.10 18015.13 3372.26 MinPts _16504.80 16197.95 16045.01 53.96 16812.77 3378.77 MinPts 17794.36 17476.93 17318.71 56.23 17080.84 3378.39 MinPts 16506.92 16183.75 16022.65 51.231 17281.76 3377.22 MinPts 16906.70 16570.73 16403.24 50.47 17597.69 3375.01 MinPis 16507.56 16200.58 16047.58 53.94 16815.97 3378.77 MinPts 16509.59 16186.28 16025.12 51.22 17285.02 3377.20 MinPts 16910.27 16574.23 16406.71 50.47' 17599.32 3375.00 MinPt-OSF 16915.91 16563.95 16388.49 48.104 18034.19 3371.93 MinPts 16512.2 16188.8 16027.57 51.20 17288.26 3377.17 MinPtu 16913.84 16577.74 16410.19 50.471 17600.92 3374.98 MinPt-O-SF 18885.05 18643.11 1852267 78.38 14536.29 3382.94 MinPt-O-ADP 1 16512.261 16188.8 16027.59 51.20 17288.29 3377.17 MinPts 16917.42 16581.26 16413.67 50.471 17602.51 3374.97 MinPt-O-SF 1 16514.94 16191.361 16030.07 51.19 17291.54 3377.15 MinPts 16921.0116584.78 16417.16 50.47' 17604.09 3374.96 MinPt-O-SF 16926.51 16574.61 16399.13 48.2''11 18033.13 3371.94 MinPts 16517.6 16193.9 16032.56 51.18 17294.79 3377.13 MinPts 16924.60 16588.31 16420.65 50.4 17605.65 3374.95 MinPt-O-SF 16930.11 16578.11 16402.69 48.2 18032.78 3371.95 MinPts 16520.3 16196.48' 16035.05 51.17 17298.02 3377.11 MinPts 16928.19 16591.84 16424.16 5047 17607.20 3374.94 MinPt-O-SF 18239.92 1787204 17688.59 49.71 18489.65 3359.16 MinPt-O-SF I16933.61 165817 16406.25 48.25 18032.44 3371.96 MinPts 16523.02 16199.0 16037.56 51.15 17301.24 3377,08 MinPts 16931.79 16595.38 1642766 50,47 17608.74 3374.93 MinPt-O-SF 18202.06 17834.32 17650.94 498 18482.43 335934 MinPt-O-SF 16937.21 1658521 16409.82 48.26 18032.09 3371.96 MinPts 16525 7 16201 6 16040.07 51.1 444"""��/��1 17304.46 3377.06 MinPts 16935.40 16598.92 16431.18 50 17610.25 3374.92 MinPt-O-SF 16940 8 16588.8 16413.39 48.2 18031.75 3371.97 MinPts 16528.45 16204.2 1604259 51.13 17307.65 3377.04 MinPts 16939.01 16602.47 1643469 50.44 17611.76 3374.91 MinPt-O-SF 16944.35 16592.45 16416.97 48.2`0'11 18031.42 3371.98 MinPts 165311 16206.8 16045.13 51.12 17310.84 3377.02 MinPts 16942.63 16606.03 16438.22 50.481 17613.25 3374.90 MinPt-O-SF 1_6947.95 16596.03 16420.56 48.2"71 18031.09 3371.98 MinPts 16533.9_41 16209.4_41 16047.67 51.11 17314.02 3376.99 MinPts 16946.25 16609.63 16441.81 50.49 17613.66 3374.90 MinPt-O-SF _16951.55 1659961 16424.15 48.3,"J1 18030.76 3371.99 MinPts 1653666 16212 04� 1605022 51.09 17317.18 3376.97 MinPts 16949.87 16613.24 16445.41 50.5 17613.88 3374.89 MinPt-O-SF I16955.15 16603211 16427.74 48.31 18030.43 3371.99 MinPts 16539 41 16214 66 16052.78 51.08 17320.33 3376.95 MinPts 16953.51 16616.86 16449.02 506 17614.10 3374.89 MinPt-O-SF 1 16958.711 16606.811 16431.35 48.3 18030.11 3372.00 MinPts 8114-N6(P2)(Def Plan) PassMIME' 17860.12 17830.47 5658.27 251.08 251.08 MinPts 17863.72 17860.42 17830.91 NEM 279.59 279.59 MinPt-O-SF 17863.94 17860.65 17831.1'1 299.55 299.55 MinPt-O-SF MEM 15009.1.MIME IrE 13172.17 3408.67 MinPts 15098.7 14851.28 14728.02 61.25 15102.44 3400.69 MinPt-CtCt 15098.7, 14728.00 61.24 15103.18 340069 MinPt-O-EOU 15098.82 14851.2: 'r' 61.23 15103.93 3400.69 MinPt-O-ADP 15497.51 15237.69 15108.2 Ilmrifi 15562.42 3395.17 MinPt-O-SF 17863.60 17862.38 17830.80 14593.95 0.00 0.00 Surface 17872.57 17466.90 1726457 44.16 1943828 3350.95 TD 14880.47 14712.07 14628.48 89.00 9848.28 3145.23 MinPt-CtCt 1488049 14712.071 14628.46 88.99 9847.48 3145.38 MinPts 14940.80 14770.76 14686.37 88.51 9931.81 3156.47 MinPt-O-SF 18406.38 18204.89 1810464 91.79 11450.83 3356.09 MinPt-OSF 18419.78 18218.15 18117.83\ 91.80 11456.44 3356.85 MinPt-OSF 18523.57 18320.80 18219.91 91.79 11500.82 3362.31 MinPt-O-SF 19156.31 18939.97 18832.29 88.95 12101.27 3407.89 MinPt-O-SF 17898.67r 17580.331 1742166 56.40 17081.06 3378.38 MinPts S102-SE6(P2)(Def Plan) Pass 1 17936.751 17599.561 1743141 53.35 17615.39 3374.88 MinPts 18465.99 18123.08 179521 54.0 17754.11 3374.10 MinPt-O-SF • I17853,381 17850.031 17820.57 5341.85 268.47 268.47 MinPt-O-EOU 17853.3 17850. 17820.56 5359.14 271.37 271.37 MinPts 1785362 17850.32 17820.81 5421.48 300.32 300.31 MinPt-O-SF I17454.75 17136 16978.02 55.0 17133.10 3378.23 MinPts 17453.9 17129 y4�� 16967.66 53.94 17313.38 3377.00 MinPts 18467.17 18115.68 1794043 52.69 17983.02 3372.70 MinPt-O-SF _ I 17941.48 17589.19 17413.53 51 07 18023.48 3372.12 MinPts 15604.30 15434.83 15350.63 92.66 9975.05 3162.15 MinPt-CtCt 15604.32 15434.83 1535061 92.64 9975.87 3162.26 MinPt-O-EOU 15604.35 15434.83 15350.61 9263 9978.69 3162.37 MinPt-O-ADP 15775.47 15602.58 15516.67 91.81 10117.25 3180.84 MinPt-O-SF 17456.23 17149.01 16995.89 57.00 16820.63 3378.76 MinPts 17940.61 17603.40 17435.28 53.36 17615.74 3374.88 MinPts • 15906.82 15695.84 15590.84 75.74 13087.37 3410.42 MinPts 17458.55 17140.41 16981.83 55.041 17132.62 3378.23 MinPt-O-SF I 17457.751 17133.121 16971.29 53.94 17315.85 3376.98 MinPts 18471.53 18120.05 17944.80 52.70 17982.90 3372.70 MinPt-O-SF 1 17945.24 17593.04 17417.35 51.08 18022.97 3372.13 MinPts 17460.08 1715276 16999.60 56.99 16823.00 3378.76 MinPt-O-SF 17944.481 17607.24 1743912 53.36 17616.08 3374.88 MinPts 17853 28 17852.06 17820.47 14585.51 0.00 0.00 Surface 17853.2 178504 17820.4 6370.43 198.10 198.10 MinPts 17462.3 17144.2 16985.6 55.061 17132.13 3378.23 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 17 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.j_ft Fact. MD(ft) I TVD(ft) Alert I Minor I Major 17461.54r 17136.801 16974.92 5393 17318.32 3376.96 MinPts 18475.90 18124.42 17949 171 52.711 17982.79 3372.70 MinPt-O-SF 17949.09 17596.82, 17421 181 51.091 18022.45 3372.14 MinPts 17948.35 17611.09' 17442 96 53.37 17616.42 3374.88 MinPts 17465.32 17140.48 16978 55 5393 17320.79 3376.95 MinPts 18480.26 18128.79 17953 54 1 52.7211 17982.68 3372.70 MinPt-O-SF 17952.91 17600.651 17425.011 51.101 18021.95 3372.14 MinPts 16887.49 16519.431 16335.89 46.00 18597.49 3357.54 MinPts 17207.01 16854.03 16678.02 48.88 18130.24 3369.82 MinPts 17179.49 16879 071 16729 35 57.37 16647.42 3379.01 MinPts 17471.64 17164.04 17010 731 56.981 16830.11 3378.74 MinPt-0SF 17473 80 17155.67 16997 10 55.091 17130.68 3378.24 MinPt-O-SF 17472 8911 17147 8511 16985.8211 53.92 17325.73 3376.91 MinPts 17227.3911 16909.0311 16750.35 54.281 17162.69 3378.05 MinPts 17227.391 16908.9511 16750.2111 54.261 17165.21 3378.04 MinPts 17231.16 16912.611 16753 831 54.26 17167.68 3378.02 MinPts 17963.90 17626.57 17458.401 53.411 17617.76 3374.87 MinPt-O-SF 17480.46 17155.22 16993.081 53.901 17330.67 3376.88 MinPts 17968.28 17616.03 17440.411 51.151 18019.95 3372.18 MinPts 17483.21 17175.32 17021.87 56.96 16837.22 3378.73 MinPts 17967.81 17630.46 17462.27® 17618.09 3374.87 MinPt-O-SF 17484.251 17158.901 16996.72 17333.13 3376.86 MinPts 17487 06 17179 08 17025.58 56.96 16839.59 3378.73 MinPts 17971 72 17634.35 17466.16 53.42 17618.42 3374.86 MinPt-O-SF 17488.041 17162.581 17000.351 53.89 17335.60 3376.84 MinPts 17975.64 17638.25 17470.0, 53.43 17618.75 3374.86 MinPt-O-SF 17491.8. 17166.21 17003.98 53.89 17338.07 3376.82 MinPts 17494.77.. 17186.601 17033.011 56.951 16844.33 3378.72 MinPts 17979.56 7642 51 17473.941 53.441 17619.07 3374.86 MinPts I 17495611 17169.951 17007611 53.88 17340.54 3376.81 MinPts 17983.49 17646.06 17477 841 53.451 17619.39 337486 MinPt-O-SF II 17499 4011 17173.6411 17011.251 53.88 17343.01 3376.79 MinPts 18519 64 18168.18 17992 941 52.841 17981.82 3372.71 MinPt-O-SF L 17987 5911 17635.4111 17459 821 51.221 18017.51 3372.22 MinPts 15897 58 15685.82 15580 441 75.421 13083.58 3410.47 MinPt-O-SF 15886.60 15675.1 15569.90 75.47 13086.03 3410.44 MinPt-O-ADP 15886 591 15675.131 15569.90 75 48 13086.08 3410.44 MinPts 17502.49 17194.13 17040.., 56.94 16849.07 3378.72 MinPt-O-SF 17987.43 17649.9: 17619.71 3374.86 MinPts MIME MEOW ME= 53.87 17345.48 3376.77 MinPts 18524 02 18172 56 17997.33 MIRO 17981.75 3372.71 MinPt-O-SF 17991.48 MEMOS 18017.03 3372.23 MinPts 15699.11 15439.75 15310,57 60.76 15564.72 3395.14 MinPt-CtCt 15699.1.MEM 15310.54 60.75 15565.19 3395.14 MinPt-O-EOU 15699.15 15439.74 El 60.75 15565.67 3395.13 MinPI-0-ADP 15772.81 15511.05 15380.6 60.48 15602.39 3394.74 MinPt-O-SF 17506.34 17197.89 17044.1 IMEDI 16851.44 3378.71 MinPt-O-SF 17989.39 17483.69 17619.87 3374.85 MinPts 17506.97 53.87 17347.95 3376.76 MinPts 18528.40 18176.95 18001.71 mmED 17981.67 3372.71 MinPt-O-SF ®limo 7465 661.11111111111E. 18016.80 3372.23 MinPts MEM16828.78 16639.50 45.46 18859.39 3355.87 MinPts 17418.78 17031.71 16838.67 M13111 19029.70 3354.78 MinP1-0SF 17959.85 17554.45 17352.25 44.41 19438.28 3350.95 TD 1.17991 37 17653.91 17485.8: 53.47117620.03 3374.85 MinPts 17510.761 17184.691 17022.15 53.86 17350.42 3376.74 MinPts 18532.79 18181.33 18006.10 52.881 17981.60 3372.71 MinPt-O-SF 17995.37 17643.21 17467.63 51,24118016.56 3372.23 MinPts 17254,05 16899.58 16722.84 48.81 18164.57 3368.61 MinPts Nam 17657.84 17489.58 ME21' 17620.35 3374.85 MinPts 17514.55 17188.38 17025.7• 53.86 17352.89 3376.72 MinPts 18537.17 18185.72 18010.49 52.8•, 17981.53 3372.71 MinPt-O-SF 17999.27 17647.12 17471.5,1 51.251 18016.09 3372.24 MinPts I 17999 2811 17661 771 17493.5111 53.481 17620.66 3374.85 MinPts 17029.42 53.85 17355.36 3376.70 MinPts 18541.56 18190.11 18014.871 52.901 17981.46 3372.71 MinPt-O-SF 18003.1: 17651.041 17475.4611 51.271 18015.62 3372.25 MinPts 18003.2, 17665 711 17497 4411 53.491 17620.98 3374.85 MinPts ®1®] 17033 061 53.85 17357.83 3376.69 MinPts 18545.94 18194.50 18019 2611 52.921 17981.40 3372.72 MinPI-0-3F 18007.09 17654.961 17479.3911 51.281 18015.15 3372.26 MinPts 18007.20 17669.66 17501.38 MEE 17621.30 3374.85 MinPts 17199.44 17036.69 53.84 17360.30 3376.67 MinPts 18550.33 18198.88 18023.65 52.93 17981.34 3372.72 MiePt-OSF 18011.01 17658.89 17483.32 51.2•1 18014.69 3372.26 MinPts 18011181- 17673.621 17505.33 53.51 17621.61 3374.84 MinPts ®I 17203 131 17040 33 53 84 17362.77 3376.65 MinPts 18554 72 18203.27 18028 041 52.941 17981.28 3372.72 MinPt-O-SF I 18014 931 17662 821 17487 261 51.301 18014.23 3372.27 MinPts I 18015 161 17677 5811 17509 281 53.521 17621.93 3374.84 MinPts I 17533 5011 17206 8111 17043 961 53.83 17365.24 3376.63 MinPts 18559.11 18207.67 18032 441 52.951 17981.23 3372.72 MinPt-OSF I 18018 870 17666 7611 17491.201 51.321 18013.78 3372.28 MinPts I 18019 141 17681.5411 17513 241 53.531 17622.24 3374.84 MinPts 1 17537 291 17210 501 17047 601 53.83 17367.71 3376.62 MinPts 18563.50 18212.06 18036.83 52.971 17981.18 3372.72 MinPt-O-SF 1 18022 AMEN IMME 51 331 18013.32 3372.29 MinPts I 18023 131 17685 521 17517.201 53.541 17622.55 3374.84 MinPts 17541.0817214.19 17051.24 53.82 17370.18 3376.60 MinPts 18567 89 18216.45 18041.22, 52.981 17981.13 3372.72 MinPt-O-SF 18026.75 17674.66 17499.11® 18012.87 3372.29 MinPts 18027.13 17689.49®® 17622.85 3374.84 MinPts I 17544 871 17217 881 17054 8711 53.81 17372.65 3376.58 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 18 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert 1 Minor 1 Major 18572.28 18220.84 18045.61 52.99' 17981,08 3372.72 MinP1-0-SF 18030.70 17678.62 17503.07 51.35 18012.43 3372.30 MinPts 18031.13 17693.48 17525.151 53.551 17623.16 3374.83 MinPts 17548.661 17221.56 17058.51 53.81 17375.12 3376.57 MinPts 18576.68 18225.24 18050.01 53.00 17981.04 3372.72 MinPt-O-SF 18034.66 17682.5, 17507.0, 51.37 18011.98 3372.31 MinPts 18035.1•, 17697.4 17529.13 53.56 17623.46 3374.83 MinPts 1755245 17225.25 17062.15 53.80 17377.59 3376.55 MinPts 18581.07 18229.63 18054.4• 53.02 17981.00 3372.72 MinPt-O-SF 1 18038 6211 17686 5611 17511.02 51.381 18011.54 3372.31 MinPts 18039.15 17701.46 17533.11 53.571 17623.87 3374.83 MinPts 17556.2 17228. 17065.78 53.80 17380.05 3376.53 MinPts 18585.47 18234.03 18058.80 53.03 17980.97 3372.72 MinPt-O-SF 18042.59 17890.53 17515.00 51.39 18011.10 3372.32 MinPts 18043.17 17705.40 17537.01 53.57 17625.89 3374.82 MinPts 17560.03 17232.63 17069.42. 53.79 17382.52 3378.51 MinPts 18589186 18238.42 18063.20 53.04 17980.94 3372.72 MinPt-O-SF 18046. c 1769452 17518.99 51.40 18010.67 3372.33 MinPts 18047.1' 17709.34 17540.91 53.57J 17627.88 3374.81 MinPts 17563.82 17236.32 17073.06 53.79 17384.99 3376.50 MinPts 18594.26 18242.82 18067.59 53.06 17980.91 3372.72 MinPt-O-SF 18050.54 17698.51 17522.98 51.42 18010.24 3372.33 MinPts 18051.22 17713.29 17544821 53.57 17629.87 3374.80 MinPts 17567.61 17240.01 17076.701 53.78 17387.46 3376.48 MinPts 18598.65 18247.21 18071.99 53.07' 17980.88 3372.72 MinPt-O-SF 18054.53 17702.50 17526.98 51.43 18009.81 3372.34 MinPts 18055.26 17717.25 17548.74 53.571 17631.84 3374.79 MinPts 17571.41 17243.70 17080.34 53.78 17389.93 3376.46 MinPts MinPt-0SF 18603.05 18251.61 18076.39) 53.06 17980.86 3372.72 18058.52 17706.501 17530.99 51.44 18009.38 3372.35 MinPts 18059.30 17721.21 17552.66 53.57 17633.80 3374.77 MinPts 17575.20 17247,39 17083.98 53.77 17392.40 3376.44 MinPts 18607.44 18256.01 18080.78 53.09 17980.84 3372.72 MinPt-O-SF 8062 52 17710.51 17535.00 51.45 18008.96 3372.35 MinPts 80 3 34 17725.18 17556.59 53.57 17635.74 3374.76 MinPts 17578.99 17251.08 17087.61 53.77 17394.87 3376.43 MinPts 18611 84 18260.41 18085.18 53.11 17980.82 3372,72 MinPt-O-SF 18066.52 17714.528 17539.01 51.47 18008.54 3372.36 MinPts 18067.39 17729.15_ 17560.53 53.57 17637.67 3374.75 MinPts 17582.78 17254.77 17091.25 53.76 17397.34 3376.41 MinPts 18616.24 18264.80 18089.58' 53.12 17980.81 3372.72 MinPt-O-SF 1 18070.5 7718 5,1 17543 04 51.481 18008.12 3372.37 MinPts 18071.. 17733.131 17564 4711 53.571 17639.59 3374.74 MinPts LL17586. = 17258.466 1 17094 891 53 76 17399.81 3376.39 MinPts 18620.84 18269.20 18093.98 53.13 17980.80 3372.72 MinP1.0-5F 18074.5 17722.561 17547.061 51.49 18007.71 3372.37 MinPts :r®1®1 17568 44 53.571 17641.49 3374.73 MinPts MIEN®1 17098 531 53.75 17402.28 3376.38 MinPts 18625.03 18273.60 18098 3811 53.141 17980.79 3372.72 MinPt-O-SF 1 18078.571®1 17551 1011 51.501 18007.30 3372.38 MinPts 1 18079.581®1 17572 3711 53.571 17643.38 3374.72 MinPts 17594.16 mg= 17102.17) 53.75 17404.75 3376.36 MinPts 18629.43 18278.00 18102.778 17980.79 3372.72 MinPt-O-SF 18082.60 E8.I881 17555.1411 51.521 18006.89 3372.38 MinPts 18083.65 17745 11 17576 33 53.571. 17645.25 3374.71 MinPts ® 17269.53 17105.81 53.74 17407.22 3376.34 MinPts 18633.83 18282.40 18107.17 5317 17980.79 3372.72 MinPt-OSF 18086.63 17734 67 17559.18 51.53 18006.49 3372.39 MinPts 18087.72 17749 11 1 17580.2911 53.571 17647.11 3374.70 MinPts 17601.75 17273 22 17109.451 53.74 17409.69 3376.32 MinPts 18638 23 18286.80 18111.571 17980.79 3372.72 MinPt-O-SF 18090 67, 17738 721 17563.231® 18006.09 3372.40 MinPts 18091.801._1775312] 17584.261® 17648.96 3374.69 MinPts 1760555 17276.911 17113.0911 53.73 17412.16 3376.31 MinPts 18642.63 18291.19 18115.9711 53.191 17980.79 3372.72 MinP1-0SF 1 1A094.711 17742.7711 17567 24 51.55] 18005.69 3372.40 MinPts 1 18095 8911 17757 1311 17588 241f 53 57] 17650,79 3374.68 MinPts 1 17609 341 17280.611 17116.731 53.72 17414.63 3376.29 MinPts 18098.76 17746 82 17571 35 51.57 18005.30 3372.41 MinPts 18099 98 1776115 17592.22 53.57 17652.60 3374.67 MinPts 17613.1, 17284 30 17120.3 53.72 17417.10 3376.27 MinPts 18102.82 17750 89 17575.41 51.58 18004.91 3372.41 MinPts 18104.0: 1776517 17596.21 53.57111 17654.40 3374.66 MinPts 17616.9 17287.99 17124.011 53.71 17419.57 3378.25 MinPts 18106.8: 17754.9 17579.49 51.591 18004.52 3372.42 MinPts 18108.18 17769. 1 17600.21 53.57 17656.19 3374.65 MinPts 17620.73 17291.68 17127.65 53.71 17422,04 3376.24 MinPts 18110.94 17759.03 17583.561 51.611 18004.13 3372.42 MinPts 18112.281 17773.2411 17604.2111I99 17657.97 3374.64 MinPts NEM MIE11 17131 291 53 70 17424.51 3376.22 MinPts 1 18115.011®[ 17587 641 51.621 18003.75 3372.43 MinPts 1 •ItOMM1 17608.2111 17659.73 3374.63 MinPts 17628.32 17299.07 17134.93 53.70 17426.97 3376.20 MinPts 18119.09 17767.1.' 17591.731 51.631 18003.37 3372.44 MinPts 17633 75! 17322.16 17166.8 . 56.77 16929.66 3378.60 MinPts 18120 51 17781.3 17612. . 53.58 1766147 3374.62 MinPts 17632.11 17302.7617138.5: 5369 17429.44 3376.18 MinPts 18123.17 17771.28 17595.82 51.6• 18002.99 3372.44 MinPts 17637.61 17325.93 17170.58 56 76 16932.03 3378.60 MinPts 18124.63 17785.37 1761624 53 58 17663.20 3374.61 MinPts 17635.91 17306.45 17142.22 53.69 17431.91 3376.17 MinPts 18127.26 17775.37 17599.92 51.661 18002.62 3372.45 MinPts 1 17641 4811 17329.70111 16934.40 3378.60 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 19 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft EOU(ft), Dev.(ftL Fact. MD(ft) I TVD(ft) Alert I Minor I Major -.18128.7 17789.43 17620.26 53.58 17664.92 3374.60 MinPts 17639.71 17310.15 17145.86 53.68 17434.38 3376.15 MinPts G 18131.35 17779.47 17604.02 51.67 18002.25 3372.45 MinPts 17645.34 17333.47 17178 021 56.75 16936.77 3378.59 MinPts 18132.88 17793.49 17624.29 53.58 17666.62 3374.59 MinPts 17643.50 17313.84 17149.50 53.68 17436.85 3376.13 MinPts 18135.45 17783.57 17608.13 51.68 18001.89 3372.46 MinPts 17649.21 17337.24 17181.74 56.75 16939.14 3378.59 MinPts 18137.01 17797.56 17628.32 53.58 1766831 3374.58 MinPts 17647.30 17317.54 17153.15 5:67 17439.32 3376.12 MinPts 18139.55 17787.68 1761224 51.69 18001.52 3372.46 MinPts 17653.08 17341 01 17185.47 56.74 16941.51 3378.59 MinPts 18141.15 17801.63 17632.36 5358 17669.98 3374.57 MinPts 17651.10 17321.23 17156.79 53.67 17441.79 3376.10 MinPts 1 18143.65 17791.80 17616.36 51.71 18001.16 3372.47 MinPts 17656.94 17344.78 17189.19 56.74 16943.88 3378.58 MinPts 18145.29 17805.70 17636.40 53.59 17671.64 3374.56 MinPts 17654.90 17324.93 17160.43 53.66 17444.26 3376.08 MinPts 18147.77 17795.92 17620.48 51.72 18000.81 3372.47 MinPts 17660.81 17348.55 17192.91 56.73 16948.25 3378.58 MinPts 18149.44 17809.79 17640.45 53.59 17673.29 3374.55 MinPts 1765870 17328.62 17164.07 53 66 17446.73 3376.06 MinPts Q 18151.88 17800.04 17624 61 51 73 18000.45 3372.48 MinPts 17664.67 17352.32 17196.64. 56.73 16948.62 3378.57 MinPts 18153.59 17813.87 17644.51 53.59 17674.92 3374.54 MinPts 17662.49 17332.32 17167.72 53.65 17449.20 3376.05 MinPts 18156.00 17804.17 17628.74 51.75 18000.10 3372.48 MinPts 17668.54 17356.09 1720036 56.72 16950.99 3378.57 MinPts • 18157.75 17817.96 17648.56 53.59 17676.53 3374.53 MinPts 17866.29 17336.01 17171.36 53.65 17451.67 3376.03 MinPts 18160.13 17808.30 17632.88 51.76 17999.75 3372.49 MinPts 17672.41 17359.86 17204.08 56.72 16953.36 3378.57 MinPts 18161.91 17822.06 17652.63 53.59 17878.13 3374.53 MinPts _17670.09 17339.71 1717501 53 64 17454.14 3376.01 MinPts 18164.26 17812.44 17637.02 51 77 17999.41 3372.49 MinPts _17676.28 17363.64 17207.81 56 71 1695573 3378.56 MinPts 18166.07 17826.16 17656.70 53.60 17679.72 3374.52 MinPts 17673.89 17343.40 17178.65 53.63 17456.61 3375.99 MinPts _18168.40 17816.58 17641.17 51.78 17999.07 3372.50 MinPts 17680.14 17367.41 17211.53 56.71 16958.10 3378.56 MinPts 18170.24 17830.27 17660.77 53.60 17681.29 3374.51 MinPts 17677.89 17347.10 17182.30 53.63 17459.08 3375.98 MinPts 18172.54 17820.73 17645.32 51.80 17998.73 3372.50 MinPts 17684.01 17371.18 17215.26 56.70 16960.47 3378.56 MinPts 18174.42 17834.38 17664.85 53.60 17682.85 3374.50 MinPts 17681.49 17350.80 17185.94 53.62 17461.55 3375.96 MinPts 18176.68 17824.88 17649.47 51.81 17998.39 3372.51 MinPts 17687.88 17374.95 17218.98 56 70 16962.84 3378.55 MinPts 18178.59 17838.50 17668.94 53.60 17684.39 3374.49 MinPts 17685.29 17354.49 17189.59 53.62 17464.02 3375.94 MinPts 18180.83 17829.04 17653.63 51.82 17998.06 3372.51 MinPts 17691.75 17378.73 17222.71 56.69 16965.21 3378.55 MinPts 18182.77 17842.62 17673.03 53.611 17685.92 3374.48 MinPts 17689.09 17358.19 17193.23 53.61 17466.49 3375.93 MinPts 18184.99 17833.20 17657.80 51.84 17997.73 3372.51 MinPts 17695.62 17382.50 17226.43 56.69 16967.58 3378.55 MinPts 18186.96 17846.74 17677.12 53.81 17887.44 3374.47 MinPts 17692.89 17361.89 17196.88 53.61 17468.96 3375.91 MinPts 18189.15 17837.37 17661.97 51.8 17997.41 3372.52 MinPts 17479.01 17117.451 16937 16 48.4 1832828 3363.80 MinPts Nikailchuq 4PB1(Def Survey) Pap L .�. r 18585.13��1 9456.73 51.00 51.00 MinPts 18587.6 ISI 18554.83 6519.21 165.92 165.92 MinPt-O-EOU jjl*' - 2 4318.14 408.88 408.80 MinPts 18588.7. 18583.8 18555.93 3824.10 454.17 453.95 MinPt-O-EOU 18590...MIZZIE 18557.19 3150.41 515.55 514.92 MinPt-O-EOU 18366.48 18343.69 404.04 3000.64 224024 MInPt-CtCt 18413.86 MIME 18343.68 403.89 3002.11 2240.55 MinPt-0-EOU 18413.88 18366.47 18343.68 403.85 3002.48 2240.63 MInPt-O-ADP 18496.97 1844872 18425.48 11111M2 3090.67 2256.86 MinPt-O-SF 18541.31 18493.00 1846973 398.30 3105.36 2259.08 TD SP11-N7(P2)(Def Plan) Pass I 17859.811 17856.64 17827.00 5624.59 251.09 251.09 MinPts 17860.23 17856.93 178274 5407.5 279.74 279.74 MinPt-O-SF 17860.44 17857.16 17827.64 5430.4 299.80 299.80 MinPt-OSF I 15330.491 15117.611 15011.67 72.34 13214.41 3407.34 MinPts 15330.51 15117.63 15011.68 72.341 13214.90 3407.32 MinPt-O-SF 15233.0 14988.72 14867.04 62.59 15002.63 3399.26 MinPt-CtCt 15233.1 14988.70 14866.98 62.57 15005.02 3399.33 MinPt-O-EOU 15233.13 14988.7 14866 98 62 57 15005.63 3399.35 MinPt-O-ADP 15592.76 15333.28 15204 03 60.321 15566.37 3395.12 MinPt-O-SF 17860.11 17858.89 17827.30 14591.09 0.00 0.00 Surface 19051.59 18680.83 18495.94® 18595.08 3357.56 MinPt-OSF 19055.57 18647.54 18444.01 46.81 19438.28 3350.95 Ti) MUM 14765.57 14684.59 92.16 9554.59 3106.89 MinPt-CtCt 14928.77 EOM 14684.52 92.12 9558.55 3107.41 MinPt-O-EOU 14928.82 14765.55 MIME 92.10 9560.52 3107.67 MinPt-O-ADP 15258.76 15089.52 15005.'- 90.76 9916.63 3154.47 MinPt-O-SF 19238.24 19020.18 18911.:. 88.6 13075.07 3410.58 MinPt-OSF 19190.01 18972.39 18864.x: 88.58 13098.77 3410.26 MinPt-O-SF 19081.97 18865.44 18757.6 ®I 13155.23 3409.11 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 20 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 18284.77 18041 84 17920.87 75.57 14942.53 3396.77 MinP1-0-SF 20715.6 20483 62 20368.101 89 66 12490.61 3414.39 MinPts SP01-SE7(P2)(Def Plan) Pass T i0 69- 18787.66 1818®. 19180 63 17640.91 337677 MinPts 19787 66' 19280 63 MINIM 17640.92 3374.73 MinPts 14:558;5saimactolom17819.80' 5202.20 251.10 251.10 MinPts 17852.94 17849.65 17820.1 5420,641 300.37 300.37 MinPt-O-SF 51 57.21 17492.77 3375.74 MinPts 19790.43 19438.52 19263.0 MZIEZ 18001.83 3372.46 MinPt-O-SF 15421.77 15337.53 92.53 9974.81 3162.12 MinPt-CtCt 15591.35 II= 15337.51 92.52 9975.48 3162.21 MinPt-O-EOU 15591.37 15421.7 mama,. 92.51 9976.16 3162.30 MinPt-O-ADP 15668.19 15496.90 15411.79,1111111=1n 10040.06 3170.70 MinPt-O-SF E:.1 4 17347.21 3376.76 MinPts 86 " 19453 98. 19285.30 MOM 17640.77 3374.74 MinPts IIMEi 15674.98 15569 85 75.55 13088.83 3410.40 MinPts 18950.56 57.21 17494.57 3375.73 MinPts 19795.09 19443.18 19267.72 11.11111001, 18001.84 3372.46 MinPt-O-SF 21061.82 20692 84 205088• 18512.47 3358.66 MinPt-O-SF 15709 05. 15450 85.1=- 15543.17 3395.41 MinPts 18598.9•RIMIgE.MIIME MEIBE 17349.01 3376.75 MinPts 17852.60 17851.38 17819.80 14584 96 0.00 0.00 Surface 17852.60 17849.19 17819.80 5226.96 248.10 248.10 MinPts 18954.91 18622.65 18457.01 57.21 17496.37 3375.72 MinPts 19799.74 19447.84 19272.38 56.42 18001.86 3372.46 MinPts 18803.23 18276.99 18114.36 57.19 17350.80 3376.74 MinPts 18606.66 18299.03 18145.71 60.67 16826.90 3378.75 MinPts 18959.26 18626.92 18461.25 57.21 17498.16 3375.70 MinPts 19804.40 19452.50 19277.04 56.431 18001.88 3372.46 MinPt-0SF 17454.04 17085.71 16902.05 47.51111' 18597.11 3357.54 MinPts 18607.57 18281.25 18118.59 57_ 17352.60 3376.72 MinPts 19273.36 18936.15 18768.03 57.3 17615.12 3374.88 MinPts 18963.61 18631.20 18465.48 57.2 17499.96 3375.69 MinPts 18015.10 17661.86 17485.73 51.14 18129.75 3369.63 MinPts 18147.17 17846.54 17696.72 60.56 16647.48 3379.01 MlnPts 18611.90 18285.51 18122.81 57.19 17354.40 3376.71 MinPts 18147.17 17846 45 17696.58 60.54 16650.24 3379.00 MinPts 18967.95 18635.47 18469.72 5722 17501.76 3375.68 MinPts 19813.71 19461.81 19286.35 56.461 18001.93 3372.46 MinPt-O-SF 18153.25 17834.67 1767588 57.16 17162.96 3378.05 MinPts 18153.25 17834.64 17675.83 57.15 17163.91 3378.04 MinPts 18976.60 18644.02 18478.19 5722 17505.35 3375.65 MinPts 18981.00 18648.29 18482.43 57.22 17507.15 3375.64 MinPts 19827.68 19475.78 19300.32 56.501 18002.03 3372.45 MinPt-0SF I 18985.351 18852.561 18486.66 57.22 17508.95 3375.63 MinPts 19832.34 19480.43 19304.97 56.511 18002.06 3372.45 MinPt-O-SF I 18989.701 18656.841 18490.90 57.22 17510.74 3375.62 MinPts 19836.99 19485.09 19309.62 56.531 18002.11 3372.45 MinPt-O-SF I 18994.051 18661.111 18495.14 57.22 17512.54 3375.60 MinPts 19841.64 19489.74 19314.28 56.541 18002.15 3372.45 MinPt-O-SF I18646.13 18337.91 18184 28 60.68 16842.05 3378.73 MinPts 18998.44 18665.3 18499.37 57.22 17514.34 3375.59 MinPts 19846.30 19494.39 19318.93 18002.20 3372.45 MinPt-O-SF • 15884.99 15673.16 15567 74 75. 13087.37 3410.42 MinPt-OSF 15874.92 15663.361 15558.07 75.38 1308842 3410.41 MinPts 1587491 15663.36 15558.07 75.39 13088.44 3410.41 MinPt-CtCt 18646.59 18319.61 1815657.201 17368.77 3376.61 MinPts 18650.51 18342.22 18188. 60.69 16843.73 3378.73 MinPts 19002.75 18669.66 18503.61 57.22 17516.13 3375.58 MinPts 19850.95 19499.04 19323.5 56.571 1800224 3372.45 MinPt-O-SF 15689.36 15430.34 15301.32 80.80 15550.18 3395.32 MinPt-CtCt 15689.3 NEKEE 15301.30 60.79 15550.46 3395.32 MinPt-O-EOU 15689.40 15430.33 MIME60.79 15550.75 3395.32 MInPt-O-ADP 15730.29 15469.44 15339.51- 15584.02 3394.91 MinPt-O-SF 16123.26 15857.28 15724.78 60.84 15693.53 3394.56 MinPt-O-SF 16186.44 15919.41 15786.38 60.84 15721.28 3394.52 MinPt-O-SF 17200.30 16918.20 16777.63 16138.11 339279 MinPt-O-SF ME c ®i 16350.15 3386.57 MinPts limn 18160 8,®i 17370.57 3376.60 MinPts 19007.1'maga muff,---- 57.22 17517.93 3375.57 MinPts 19855.60 19503.69 19328.2..11111=1 18002.30 3372.45 MinPt-O-SF w''EN=EL= 47.33 18902.19 3355.60 MinPts MECO ' 17372.37 3376.58 MinPts O' ;ti m-' 57.22. 17519.73 3375.55 MinPts 19860.25 19508.34 19332 88 MrialI 18002.35 3372.45 MinPt-O-SF mElus row 18169291 17374.16 3376.57 MinPts EnIMI ••;n 17594 30 47 28 18986.81 3355.06 MinPts 18250.09 17862.88 17669 76® 19029.11 3354.79 MinPt-O-SF 19059.06 18653.50 18451.22 47.11 19438.28 3350.95 TD 19015.7`1 18682.49 18516.32 57.22 17521.52 3375.54 MinPts ' 19277.81 18925.51 18749.85 54.87 18018.83 3372.20 MinPts 18663..' 18336.67 18173.52 57.20 17375.96 3376.56 MinPts 19277.8''1 18940.57 18772.45 57.33 17615.34 3374.88 MinPts 19020.1,! 18686.76 18520.56 57.22 17523.32 3375.53 MinPts 19282. • 18929.9' 18754 271 54881 18018.51 3372.20 MinPts 8668 2, 18340.9' 18177.751 57.201 17377.76 3376.55 MinPts 19282.2 18945.'' 18776.88 57.3• 17615.55 3374.88 MinPts 19024. • 18691.'• 18524.80 57.22 17525.12 3375.52 MinPts 19286.6 18934.3,. 18758.69 54.90 18018.20 3372.21 MinPts 18672.6 18345.19 18181.97 57.20 17379.56 3376.53 MinPts • 19286.69 18949.441 18781.301 57.35 17615.75 3374.88 MinPts 19028.85 18695.31 89 0 57.22 17526.92 3375.50 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 21 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft EOU(ft Dev.(ft Fact. MD(ft) I TVD(ft) Alert I Minor I Major 19291.04 18938.76 18763.11 54.91 18017.88 3372.21 MinPts 1- 18676.961 18349.46 18186.20 57.20 17381.35 3378.52 MinPts 1 19291.1411 18953.8811 18785.7411 57.361 17615.96 3374.88 MinPts 19033.20 18699.59 18533.27 57.22 17528.71 3375.49 MinPts 19295.46 18943.19 18767.54 54.921 18017.58 3372.22 MinPts F18681.30 18353.72 18190.43 57.20 17383.15 3376.51 MinPts 19295.60 18958.32 1879018 57.37 17616.16 3374.88 MinPts 19037.5511 18703 86] 18537.511 57.22 17530.51 3375.48 MinPts 19299.8811 18947 62] 16771.971 54.9 18017.27 3372.22 MinPts 18685.631-- 111.37.71 18194.651 57.201 17384.95 3376.50 MinPts 19300.061 18962 771 18794 621 57.391 17616.37 3374.88 MinPts 19041.901 18708.141 18541.751 57.22 17532.31 3375.46 MinPts 19304 311 18952 05] 18776 411 54.951 18016.97 3372.23 MinPts 18689.971 18362.251 18198.881 57.201 17386.74 3376.48 MinPts 11 19304.521 18967.221 18799.071 57.401 17616.57 3374.88 MinPts 1 18975.911 18657 911 18499 401 59 85 17101.24 3378.34 MinPts 119308.751 18956.491 18780 8511-TT971 18018.67 3372.23 MinPts f t 18972.301 18639.74 18473 951 57.22] 17503.55 3375.67 MinPts 1 19308.991 18971.681 18803 52] 57.411 17616.76 3374.87 MinPts 19818.37 19466 471 19291 011 56.47 18001.96 3372.46 MinPts 19050.601 18716.69 18550.23 57.22 17535.90 3375.44 MinPts 19313.18 18960.93 18785.30 54.98 18016.38 3372.24 MinPts F19059.101 18744.56 18587.79 60 78] 17000.20 3378.50 MinPts 20166 21 19848.57 19690 24 63.68 17080.11 3378.39 MinPts 19313.461 18976 141 18807.9711 57.421 17616.96 3374.87 MinPts 19054 951 18720 97 18554471 57.221 17537.70 3375.43 MinPts 19317.621 18965.38 1874.99 18016.08 3372.24 MinPts 19063.501 18748.90 18592.09 60.78 17001.88 3378.50 MinPts 19317.941 18980.60 18812.43 57.43 17617.15 3374.87 MinPts 19059 301 18725.24 18558.71 57.22 17539.50 3375.41 MinPts 19322.071 18969.83 18794.21 55,01 18015.79 3372.25 MinPts 19067.901 18753.23 18596.39 607 17003.56 3378.50 MinPts 19322 421 18985.07 18816.90 57. 17617.34 3374.87 MinPts 19063 651 18729.52 18562.95 57.22 17541.29 3375.40 MinPts 19326.521 18974.2• 18798.67 55.02 18015.51 3372.25 MinPts 19072.301 18757.56 18600.69 80.78 17005.25 3378.49 MinPts 19326 901 18989.5 18821 36 57.45 17617.53 3374.87 MinPts 19068.01 18733.86 18567.18 57.22 17543.09 3375.39 MInPts 19330.97 18978.7 18803.13 55.031 18015.22 3372.26 MinPts 20685.83 20386.8 20237.85 69.41 16566.22 3380.24 MinPts 1• 19076.70] 18761.90 18604.99 60.79 17006.93 3378.49 MinPts 19331.391 18994 02] 18825 841 57.47 17617.72 3374.87 MinPts 19072.361 18738 07] 18571 421 57.22 17544.89 3375.38 MinPts 19335431 18983 22] 18807 601 55.05 18014.94 3372.26 MinPts 19081.101 18766 23] 18609.281 60.79 17008.61 3378.49 MinPts 19335.881 18998.511 18830 311 57.48 17617.91 3374.87 MinPts 19076.711 18742 351 18575 661 57.22 17546.68 3375.36 MinPts 19339.901 18987 681 1881221,1 55.06 18014.66 3372.26 MinPts 19085.501 18770 561 18613.581 60.79 17010.29 3378.49 MinPts 19340.371 19002.991 18834.7911421 17618.09 3374.87 MinPts 19081 06] 18746 631 18579.901 57.22 17548.48 3375.35 MinPts 19344.361 18952.161 18816.55 55.07 18014.39 3372.27 MinPts 19087.481 18772.51118615.52 60.79 17011.05 3378.49 MinPts 19344.871 19007.481 18839 281 57.501 17618.27 3374.86 MinPts 19083.02 18748.55 18581 81 57.22 17549.29 3375.35 MinPts 19348 83 18996.6• 18821 03 55.09 18014.11 3372.27 MinPts 19089.90 18774.90 18617 88 60.79 17011.98 3378.48 MinPts 19349.38 19011 97 18843 76 57.51 17618.45 3374.86 MinPts 1 19085.4111 18750.9111 18584 141 57.221 17550.28 3375.34 MinPts 1 19353.3111 19001.1211 18825 511 55.101 18013.85 3372.28 MinPts 19094.311 18779.2311 18622 181 60.791 17013.66 3378.48 MinPts 19353.88 19016.471 18848 261 57.52] 17618.63 3374.88 MinPts 19089.77 EIMIE1 18588.381 57.22 17552.08 3375.33 MinPts map= 19005.60 18830 001 55.121 18013.58 3372.28 MinPts 19098 7 IIMME3 18626 481 60.791 17015.34 337848 MinPts 19358.39 19020.971 18852 751 57.541 17618.80 3374.86 MinPts 19094.12 18759.461 18592.621 57.22 17553.87 3375.31 MinPts M' 19010.091 18834.491 55.131 18013.32 3372.29 MinPts Ea= 18630.78 60.791 17017.02 3378.48 MinPts 19362.91. 19025 481 18857 25] 57.551 17618.97 3374.86 MinPts 19098.471 18596 86] 57 22 17555.67 3375.30 MinPts 19366.76 19014.58 18838.99 55.1 18013.06 3372.29 MinPts 19107.51 111111 18635.08 60.7 17018.71 3378.47 MinPts 19367.42 19029.98 18861 75 57.56 17619.14 3374.86 MinPts I? 19102.83 18768.02 18601.10 5722 17557.47 3375.29 MinPts 1 19371.2511 15015.0811 18843 491 55.1 18012.80 3372.29 MinPts 1 19111 911 18796.5711 18635.381 60.79 17020.39 3378.47 MinPts 1 19371.951 19034.49 18866 26 57 571 17619.31 3374.86 MinPts 19107 181 18772.291 18605.34 57.22 17559.26 3375.28 MinPts 19375.7511 19023.58 18847 991 55.171 18012.54 3372.30 MinPts 19116.318800.90 18643 681 60.791 17022.07 3378.47 MinPts 1 19376.4 19039.011 18870 77] 57 581 17619.48 3374.86 MinPts 19111.5 18776.5711 18609.591 57.22 17561.06 3375.26 MinPts 19380.2• 19028 09] 18852 50j 55.181 18012.29 3372.30 MinPts 19120 721 18805.23 18647.99 60.79 17023.75 3378.47 MinPts 19381.001 19043.53 18875.29 57.60 17619.64 3374.86 MinPts 19115.881 18780.8 18613.83 57.22 17562.86 3375.25 MinPts 19384.75 19032.5. 18857.01 55.20 18012.04 3372.31 MinPts ® 18809.5 18652.29 60.80 17025.44 3378.46 MinPts EIMIE19048.05 18879.80 57.61 17619.81 3374.85 MinPts 19120.24 18618.07 57.22 17564.65 3375.24 MinPts 19389.25= 18861 53 55.211 18011.80 3372.31 MinPts 1 19129.5211 18813.9011 18656 5911 60.801 17027.12 337846 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 22 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft). EOU(ft) `Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 19390.06 19052.58 18884.33 57.62 17619.97 337485 MinPts 19124.59\ 18789.41 18622.31 57.22 17566.45 3375.23 MinPts 19393.76 19041.62 18866.04 55.23 18011.56 3372.31 MinPts 19133.93 1881824 18660.89 60.80 17028.80 3378.46 MinPts 1939460 19057.11 18888,85 57.63 17620.13 3374.85 MinPts 19128.95 18793.69 18626.55 57.22 17568.25 3375.21 MinPts 19398.28 19046.14 18870.56 55.24 18011.32 337232 MinPts 19138.33 1882257 18665.19 60.80 17030.48 3378.46 MinPts 19399.14 19061.64 18893.38 57.64 17620.28 337485 MinPts 19133.30 18797.97 18630.79 57.22 17570.05 3375.20 MinPts 19402.79 19050.66 18875.09 55.25 18011.08 3372.32 MinPts 19142.73 18826.91 18669.49 60.80 17032.17 3378.45 MinPts 19403.69 19066.17 18897.91 57.66 17620.44 3374.85 MinPts 19137.65 18802.25 18635.03 57.22 17571.84 3375.19 MinPts 19407.31 19055.19 18879.62 55.27 18010.85 3372.32 MinPts 19147.13 18831.25 18673.79 60.80 17033.85 3378.45 MinPts 19408.23 19070.71 1890244 57,67 17620.59 3374.85 MinPts 19142.01 18806.52 18639.27 57.22 17573.64 3375.18 MinPts 19411.84 19059.72 18884.15 55.28 18010.62 337233 MinPts 19151.54 18835.58 18678.09 60.80 17035.53 3378.45 MinPts 19412.79 19075.26 18906.98 57.68 17620.74 3374.85 MinPts 19146.36 18810.80 18643.52 57.22 17575.44 3375.16 MinPts 19416.37 19064.25 18888.69 5529 18010.39 3372.33 MinPts 19155.94 18839.92 18682.40 60.80 17037.21 3378.45 MinPts 19417.34 19079.80 18911.52 57.69 17620.89 337485 MinPts 19150.72 18815.08 18647.76 57.22 17577.23 3375.15 MinPts 19420.90 19068.79 18893.22 55.31 18010.16 3372.33 MinPts 19160.34 1884425 18686.70 60.80 17038.90 3378.45 MinPts 19421.90 19084.35 18916.07 57.70 17621.04 3374.85 MinPts 19155.07 18819.36 18652.00 57.22 17579.03 3375.14 MinPts _19425.43 19073.33 18897.77 55.32 18009.94 3372.34 MinPts 19164.75 18848.59 18691.00 60.80 17040.58 3378.44 MinPts 19426.46 19088.90 18920.62 57.72 17621.19 3374.85 MinPts 19159.43 18823.64 18656.24 57.22 17580.83 3375.12 MinPts 19429.97 19077.87 18902.31 55.33 18009.72 3372.34 MinPts , 19169.15 18852.92 18695.30 60.80 17042.26 3378.44 MinPts 19431.02 19093.46 18925.17 57.73 17621.34 3374.85 MinPts 19163.78 18827.92 18660.49 57.22 17582.63 3375.11 MinPts 19434.51 19082.42 18906.86 55.35 18009.51 3372.34 MinPts 19173.56 18857,26 18699.60 60.81 17043.94 3378.44 MinPts 19435.58 19098.01 18929.72 57.74 17621.48 3374.84 MinPts 19168.14 18832.20 1866473 57.22 17584.42 3375.10 MinPts 19439.06 19086.96 18911.41 55.36 18009.30 337235 MinPts 19177.96 18861.6 18703.91 60.81 17045.63 337844 MinPts 19440.15 19102.5 1893428 57.75 17621.62 3374.84 MinPts 19172.4 18836.48 18668.97 57.22 17586.22 3375.09 MinPts 19443.61 19091.52 18915.97 55.38 18009.09 3372.35 MinPts 19182.37 18865.93 18708.21 60.81 17047.31 3378.43 MinPts 19444.72 19107.14 18938.84 57.76 17621.76 3374.84 MinPts 19176.85 18840.76 18673.21 57.22 17588.02 3375.07 MinPts ' 19448.15 19096.07 18920.52 55.39 18008.88 3372.35 MinPts 19186.77 18870.27 18712.51 60.81 17048.99 3378.43 MinPts 19449.30 19111.70 18943.40 57.78 17621,90 3374.84 MinPts _19181,20 18845.04 1867746 57.22 17589.81 3375.06 MinPts 19452.71 19100.63 18925.08 5540 18008.68 3372.36 MinPts 20779.00 20411.22 20227.82 56.65 18455.24 3360.08 MinPts 19191.17 18874.61 18716.82 60.81 17050.67 3378.43 MinPts 19453.87 19116.27 18947.97 57,79 17622.03 3374.84 MinPts 19185.56 18849.33 18681.70 57.22 17591,61 3375.05 MinPts 19457.26 19105.19 18929.65 55,42 18008.48 3372.36 MinPts 19195.58 18878.94 18721.12 60811 17052.36 3378.43 MinPts 19458.45 19120.85 18952.53 57.80 17622.16 3374.84 MinPts 19189.91 18853.61 18685.94 57.2_21 17593.41 3375.04 MinPts 19461.82 19109.76 18934.21 55.4;1 18008.28 3372.36 MinPts 19199.98 1888328 1872542 6a81 17054.04 3378.42 MinPts 19463.04 19125.42 18957.11 57.81 17622.30 3374.84 MinPts 19194.27 18857.89 18690.19 57.231 17595.20 3375.02 MinPts 19466.39 1911432 18938.78 55. 18008.08 3372.37 MinPts 19204.39 18887.62 18729.73 60.81 17055.72 3378.42 MinPts 19467.62 19130.00 18961.68 57.83 1762242 3374.84 MinPts 19198.63 18862.17 1869443 57.23 17597.00 3375.01 MinPts 19470.95 19118.89 18943.36 55.46 18007.89 337237 MinPts 1920524 18888.46 18730.56 60.81 17056.05 3378.42 MinPts 19472.21 19134.58 18966.26 57.84 17622.55 3374.84 MinPts 19199.47 18863.00 18695.25 57.23 17597.35 3375.01 MinPts 19475.52 1912347 18947.93 55.47 18007.70 3372.37 MinPts 19208.80 18891.96 18734.03 60 811 17057.40 3378.42 MinPts 19476.80 19139.16 18970.84 57.85 17622.67 3374.84 MinPts 19202.98 18866.45 18698.68 57.23 17598.79 3375.00 MinPts 19480.09 19128,04 18952.51 55.49 18007.52 3372.37 MinPt-O-SF 19213.21 18896.31 18738.35 60.81 17059.06 3378,42 MinPts 19481.39 19143.75 18975.42 57.86 17622.80 3374.84 MinPts 19207.35 18870.74 18702.93 57.23 17600.57 3374.99 MinPts 19484.66 1913262 18957.09 55.50 18007.33 3372.38 MinPt-O-SF 19217.62 18900.66 18742,66 60.8`^71 17060.71 3378.41 MinPts 19485.98 19148.34 18980.00 57.88 17622.92 3374.84 MinPts 19211.72 18875.04 18707.19 5723 1760234 3374.97 MinPts 19489.24 19137.20 18961.67 55.51 18007.16 3372.38 MinPt-O-SF 20858971 20491.901 20308.36 56.8 18468.97 3359.69 MinPts Nikeitchuq 3PB3(Del Survey) Pass s. �: 18544.3 NM= 9435.58 51.00 51.00 MinPts 18547.0 18542.9..13113E2 4469.09 368.28 368.26 MinPts Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 23 of 24 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 18547 07 18542.91 18514.26 4450.91 375.56 375.54 MinPt-O-EOU 18547.33 18542.96 18514.52 4243.04 412.33 412.25 MinPt-O-EOU I 18372.81 18324.08 18300.61 391.39 3098.51 2258.08 MinPt-CtCt 18372.82 18324.071 18300.59 391.20 3100.30 2258.33 MinPt-O-EOU 1 18370.20 18321.20 18297.60 389.15 3123.12 2261.58 MinPt-CtCt 18370.20 18321.20 18297.59 389.13 3123.41 2261.62 MinPt-O-EOU 18370.20 18321.20 18297.59 389.10 3123.69 2281.66 MinPt-O-ADP 18897.35 18841.86 18814.99 351.661 3712.62 2339.07 MinPt-O-SF 18947.43 18891.95 18865.08 352.62 3719.10 2339.92 TD r 118948.84 18893.34 18866.471 352.661 3719.10 2339.92 MinPts Nikaitchuq 3PB2(Def Survey) Pass 18546.30 18544.33 18513.4 9435.58 51.00 51.00 MinPts 1854707 18542.9 18514. 4469.09 368.28 368.26 MinPts 18547.07 18542.91 18514.26 4450.91 375.56 375.54 MinPt-O-EOU 18547.33 18542.96 18514.52 4243.04 412.33 412.25 MinPt-0-EOU [18372.81 18324.08 18300.81 391.39 3098.51 225806 MinPt-CtCt 18372.82 18324.071 18300.59 391.20 3100.30 2258.33 MinPt-O-EOU 1 18370.20 18321.20 18297.60 389.15 3123.12 2261.58 MinPt-CtCt 18370.20 18321.20 18297.59 389.13 3123.41 2261.62 MinPt-O-EOU 18370.20 18321.20 18297.59 389.10 3123.69 2261.66 MinPt-O-ADP 18991.05 18935.11 18908.0 350.4 3763.98 2345.82 MinPt-0SF 18993.45 18937.50 18910.41 350.49 3764.89 2345.94 MinPt-O-SF 19040.37 18984.42 18957.33 351.36 3772.88 2346.99 TD 1[19041.581 18985 621 18958 521 351.401 3772.87 2346.99 MinPts Nikaitchuq 3PB1(Def Survey) Pass 18546.30 18544,331 1851345 9435.58 51,00 51.00 MinPts 18542.92 18514 26 4469.09 368.28 368.26 MinPts 18547.07 18542.91 18514.26 4450.91 375.56 375.54 MinPt-O-EOU 18547.33 18542. 18514.52 4243.04 412.33 412.25 MinPt-0-EOU IF 18372.81 18324.08 18300.81 391.39 3098.51 2258.06 MinPt-CtCt 18372.82 18324.01 18300.59 391.20 3100.30 2258.33 MinPt-O-EOU 1 18370.20 18321.20 18297.60 389.15 3123.12 2261.58 MinPt-CtCt 18370.20 18321.20 18297.59 389.13 3123.41 2261.62 MinPt-O-EOU 18370.20 18321.20 18297.59 389.10 3123.69 2261.66 MinPt-0-ADP 18991.05 18935.11 18908.0 350.4 3763.98 2345.82 MinPt-O-SF 18993.45 18937.50 18910.41 350.49 3764.89 2345.94 MinPt-OSF 19040.37 18984.42 18957.33 351.36 3772.88 2346.99 TD L 19041.561 18985.64 18958.521 351.40 3772.87 2346.99 MinPts Nikaitchuq 3(Def Survey) Pass E18544.3•11111131HE 9435.58 51.00 51.00 MinPts mizEn 18542.9.MIME 4469.09 368.28 368.26 MinPte 18547.0 MOMal 18514.26 4450.91 375.56 375.54 MinPt-O-EOU 18547.3Ips'; 18514.52 4243.04 412.33 412.25 MinPt-O-EOU l 18324.08 18300.61 391.39 3098.51 2258.06 MinPt-CtCt 18372.8.Nam= 18300.59 391.20 3100.30 2258.33 MinPt-O-EOU NUM 18321.20 18297.60 389.15 3123.12 2261.58 MinPt-CtCt 18370.20 mum 18297.59 389.13 3123.41 2261.62 MinPt-O-EOU 18370.20 18321.20 18297.59 389.10 3123.69 2261.66 MinPt-O-ADP 18897.35 18841.86 1881499 IN um3712.62 2339.07 MinPt-O-SF 18947.43 18891.95 18865.08 352.62 3719.10 2339.92 713 19686.58 19631.7 19605.2 371.02 2996.56 2239.36 MinPt-O-ADP 19686.52 19631.7 19605.25 371.40 2997.98 2239.67 MinPt-O-EOU 1, 19686.46 19631.81 19605.37 372.18 3000.83 2240.28 MinPt-CtCt 19680.52 19627.161 19601.31 381.42 3039.27 2248.00 MinPts E.._L 19680.50 19627.17 19601.38 381.57 3039.98 2248.14 MinPt-CtCt '18948.82 18893.341 18866.471 352.661 3719.10 2339.92 MinPts Nikaitchuq 4(Def Survey) Pass r 18587.09 18585.13 18554.2 9456.73 51.00 5100 MinPts 18587.64 18584.79 18554.83 6519.21 165.92 165.92 MinPt-O-EOU I 18588.45 18584.15 18555.651 4318.14 408.88 408.80 MinPts 18588.7�418583.88 18555.93 3824.10 454.17 453.95 MinPt-O-EOU 18590.0 1V 6584.10 18557.19 3150.41 515.55 514.92 MinPt-O-EOU 1 18413.85 18366.48 18343.69 404.04 3000.64 2240.24 MInPt-CtCt 18413.86 18366.47 18343.68 403.89 3002.11 2240.55 MInPt-O-EOU 18413.86 18366.47 18343.68 403.85 3002.48 2240.63 MInPt-O-ADP 20988.92 20880.32 20826.90 196.441 6043.44 2645.41 -MinPt-O-SF Nikaitchuq 1(Def Survey) Pass L 18490.17 18444.45 18422.47 420.62 2894.03 2213.91 MinPt-CtCt 18490.17 18444.44 18422.45 420.47 2895.05 2214.19 MinPt-O-EOU 18490.19 18444.44 18422.45 420.32 2896.06 2214.48 MinPt-O-ADP 24564.17 24477.67 24435.29 289.851 5389.06 2559.41 MinPt-O-SF Nikaitchuq 2(Def Survey) Pass 19150.63 19146.87 19117.82 5096.17 295.00 295.00 MinPts 19150.63 19146.85 19117.82 5073.26 299.41 299.40 MinPt-O-EOU 19150.99 19147.19 19118.1: 5036.6: 34121 341.20 MinPt-0SF 19153.37 19149.45 19120. .wrirE 386.63 386.60 MinPt-O-SF 19811.50 19789.05 19778.8'MEE 837.70 827.27 MinPt-O-SF 20350.95 2031930 20304."imizE 1000.42 977.15 MinP1-0SF 20905.37 20872.08 20856.3' 666.4 1161.07 1117.73 MinPt-O-SF 21194.55 21160.92 21145.07 668.3: 1242.97 1186.06 MinPt-O-SF 21428.07 21394.09 21378.06 668 26 1304.92 1236.07 MinPt-O-SF 22004.05 21969.04 21952.4• 664.82 1446.24 1344.36 MinP1-0SF 24790.92 24744.99 24722.98 IIMMII 2388.87 1996.06 MinPt-O-SF 24877.87 24831.80 24809.7 MIMI 2400.89 2002.93 MinPt-O-SF 24930.61 24884.44 24862.31=MEE 2408.07 2006.99 MinPt-O-SF Drilling Office 2.0.960.0 Nikaitchuq\Oliktok Point\0120-07\0120-07\0120-07(P14) 9/28/2011 2:52 PM Page 24 of 24 Drilling Hazards Summary Open Hole / 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets),pumping out 12-1/4" Open Hole / 9-5/8" Casing Interval _ Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight,use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Lecithin. Stuck Pipe Low Good hole cleaning,pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates,mud rheology, LCM Hole swabbing on trips Moderate Trip speeds,proper hole filling (use of trip sheets),pumping out 8-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud Pressure weight. Stuck Pipe Low Good hole cleaning, PWD tools,hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates,mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling(use of trip sheets),pumping out,backreaming Drilling Hazards Summary.doc 9/22/2011 9:06:00 AM tikillirilli c o b._0 LL CO VP Ili 41411P . e 'Iti\ - - . - „,, ... ,,. . . ...,-''' - - 0 i !�\ '! 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Z 0 CO Q§ / »k \0\ Li ' ±cam � \ 8):-- - 6 ° /3e 1 \(A �» - I I - 5 Schlumberger CemCAD E* well cementing recommendation for 13.375" Surface Casing Operator : Eni Petroleum Well : 0120-07 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Luca Borri Location : Nabors 245E Proposal No. : Draft v1 (P14) Service Point : Prudhoe Bay Alaska Date Prepared : 10-08-2011 Business Phone : (907)659-2434 FAX No. : (907)659-2538 Prepared by : Jeff Long Phone : (907)273-1778 Cell : (907)223-0093 E-Mail Address : JLong1@slb.com n C URT E Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment.experience,and good oilfield practices. This information is provided in accordance with generally accepted industry practice,relying on facts or information provided by others,limitations,computer models.measurements.assumptions and inferences that are not infallible. Calculations are estimates based on provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED,EFFECTIVENESS OF MATERIAL,PRODUCTS OR SUPPUES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. `Mark of Schlumberger Client : Eni Petroleum Well : 0120-07 Schlumberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2764.0 ft BHST : 36 degF Bit Size : 16 in ft (x 1000) psi < J > 0 n1 .0 1.a r Frac . . . . . . . . . . . . Pore '.'.'Sandstone'.'.' o —Siltstone 0 o , 1 • •Sandstone • • •Sandstone• • • ! i Coal Ett Well Lithology Formation Press. Page 2 oi20-07 draft vl(p14)10-8-2011.cfw,10-10-2011: LoadCase Surface Casing,Version wcs-cem462--12 • Client : Eni Petroleum Well : 0120-07 Schlinbrgnr String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 160.0 20 169.0 18.376 Landing Collar MD : 2682.0 ft Casing/liner Shoe MD : 2762.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2762.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 173.5% Mean OH Equivalent Diameter: 19.741 in Total OH Volume : 985.8 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv.Diam. (ft) (in) (%) (in) 2057.0 16.000 225.0 20.724 2762.0 16.000 35.0 16.822 2763.0 16.000 0.0 15.999 2764.0 16.000 0.0 15.999 Page 3 oi20-07 draft v1(p14)10-8-2011.cfw;10-10-2011: LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 Schlinkerger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Max. Deviation Angle : 69 deg Max. DLS : 3.760 deg/100ft Directional Survey Data MD ND Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 290.0 0.000 100.0 100.0 0.0 290.0 0.000 200.0 200.0 0.0 290.0 0.000 250.0 250.0 0.0 290.0 0.000 300.0 300.0 0.8 290.0 1.500 350.0 350.0 1.5 290.0 1.500 400.0 399.9 3.4 290.0 3.760 500.0 499.5 7.1 290.0 3.750 600.0 598.3 10.9 290.0 3.750 700.0 695.8 14.6 290.0 3.750 800.0 791.6 18.4 290.0 3.750 900.0 885.4 22.1 290.0 3.750 1000.0 976.8 25.9 290.0 3.750 1100.0 1065.2 29.6 290.0 3.750 1200.0 1150.5 33.4 290.0 3.750 1300.0 1232.1 37.1 290.0 3.750 1400.0 1309.8 40.9 290.0 3.750 1456.9 1352.2 43.0 290.0 3.741 1500.0 1383.6 43.2 290.0 0.511 1600.0 1456.2 43.7 290.0 0.500 1700.0 1528.1 44.2 290.0 0.500 1800.0 1599.5 44.7 290.0 0.500 1900.0 1670.2 45.2 290.0 0.500 2000.0 1740.3 45.7 290.0 0.500 2100.0 1809.8 46.2 290.0 0.500 2161.3 1852.1 46.5 290.0 0.489 2200.0 1878.4 48.0 289.7 3.751 2300.0 1942.9 51.7 288.9 3.750 2400.0 2002.3 55.4 288.2 3.754 2500.0 2056.5 59.1 287.5 3.751 2600.0 2105.0 62.8 286.9 3.748 2700.0 2147.9 66.5 286.3 3.744 2764.0 2172.2 68.9 286.0 3.753 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 716.0 11.90 8.43 SV-4 Sandstone 979.0 12.00 8.43 SV-3 Siltstone 1278.0 12.20 9.20 SV-2 Sandstone 1946.0 12.30 9.20 SV-1 Sandstone 2057.0 12.50 9.20 Permafrost Base Shale 2350.0 12.50 9.20 Ugnu Top(UG4) Coal 2763.0 12.50 9.20 Casing Pt. Shale 2764.0 12.50 9.20 TD Shale I i Page 4 oi20-07 draft v1(p14)10-8-2011.cfw,10-10-2011; LoadCase Surface Casing:Version wcs-cem462_12 I Client : Eni Petroleum Well : 0120-07 Schlumberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 2057.0 1780.0 32 0.7 2764.0 2172.2 36 0.7 ft degF 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 O— 1 I I I t i I I t I I I I —Geoth.Profile — Tubular Fluids —Annulus O O O O— N 0 0 0 M— Temp. Profile At 205 min Page 5 oi20-07 draft v1(p14)10-8-2011.cfw,10-10-2011, LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 Schlumberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 2: fluid sequence Job Objectives: Cement to surface in Permafrost, and shoe integrity, sufficient to drill ahead. Original fluid Mud 9.30 lb/gal k : 2.06E-3 Ibf.s^n/ft2 n : 0.812 Tv: 8.74 lbf/100ft2 Displacement Volume 401.6 bbl Total Volume 1072.6 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 k:2.54E-2 Ibf.s^n/ft2 n:0.420 Ty:13.04 lbf/100ft2 Lead Slurry 508.0 2257.4 10.70 k:8.93E-2 lbf.s^n/ft2 n:0.282 Ty:24.97 lbf/100ft2 DeepCRETE(12.5) 63.0 504.6 2257.4 12.50 k:7.96E-3 Ibf.s^n/ft2 n:0.895 Ty:14.59 lbf/100ft2 Mud 401.6 0.0 9.30 k:2.06E-3 lbf.s^n/ft2 n:0.812 Ty:8.74 lbf/100ft2 Static Security Checks: Frac 10 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2019 psi at 2682.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 51 ton Check Valve Diff Press 177 psi Page 6 oi20-07 draft v1(p14)10-8-2011.cfw,10-10-2011, LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 Sehl �rg�r String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing CemCADE Client : Eni Petroleum Well :0120-07 String : 13.375"Surface Casing District : Prudhoe Bay Alaska Country : USA ft lb/gal O 8 9 10 11 12 13 -Hydrostatic -Mn.Hydrostatic -Max.Dynanic -Mn.Dynamic -Frac --Pore \\\\ . .E O y d - O 8 d M Fluid Sequence Dynamic Well Security c ■MUDPUSH II 100.0 bbl 10.10 lb/gal Herschel:k=2.54E-2 Ibf.s^n/ft2 n=0.420 Ty=13.04lbf/100H2 d .285, 3 Lead Slurry 508.0 bbl 10.70 lb/gal Herschel:k=8.93E-2 Ibf.s^n/ft2 n=0.282 Ty=24.97 Ibf/100ft2 DeepCRETE(12.5) 63.0 bbl 12.50 lb/gal Herschel:k=7.96E-3 Ibf.s^n/ft2 n=0.895 Ty=14.59 lbf/100H2 ■Mud 401.6 bbl 9.30 lb/gal Herschel:k=2.06E-3 lbf.s^n/ft2 n=0.812 Ty=8.74 Ibf/100ft2 Total Depth = 2764.0 ft Top of Cement= 0.0 ft *Mark of Schlumberger S PIT Page 7 oi20-07 draft v1 ip14)10-8-2011 cfw.10-10-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 SGhI berger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 Spacer Ahead Pause 0.0 0.0 5.0 0.0 80 Drop Bottom Plug Lead Slurry 5.0 508.0 101.6 508.0 80 Mix&Pump Lead Slurry DeepCRETE 3.0 63.0 21.0 63.0 80 Mix&Pump Tail Slurry Pause 0.0 0.0 3.0 0.0 80 Drop Top Plug Mud 8.5 10.0 1.2 10.0 80 Kick Out Plug w/Cement Pump Pause 0.0 0.0 3.0 0.0 80 Line Up Rig Pumps Mud 8.5 381.6 44.9 391.6 80 Displace w/Rig Pumps Mud 5.0 10.0 2.0 401.6 80 Slow Rate Shut-In 0.0 0.0 3.0 0.0 80 Bump Plug Total 03:21 hr:mn 1072.6 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 4 psi at 160.0 ft Pore 6 psi at 1278.0 ft Collapse 2018 psi at 2682.0 ft Burst 4759 psi at 0.0 ft Temperature Results BHCT 58 degF Simulated Max HCT 75 degF Simulated BHCT 75 degF Max HCT Depth 2762.0 ft CT at TOC 68 degF Max HCT Time 03:05:07 hr:mn:sc Static temperatures : At Time 00:01 hr:mn 00:03 hr:mn Geo.Temp. Top of Cement 70 degF 68 degF 20 degF Bottom Hole 76 degF 75 degF 36 degF Page 8 o120-07 draft v1(p14)10-8-2011.cfw;10-10-2011; LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 Schikerger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing ECD at Casing Shoe: Depth= 2762 ft co Hydrostatic Dynamic 0 Frac V 1 Pore d1 Tr1 01 d 091 N oi- 1 co I 0 20 40 60 80 100 120 140 160 180 200 220 Time(min) ECD at Conductor Shoe: o Depth= 160 ft Fluids at 2762 ft -- �1Hydrostatic Dynamic N Frac Ire 7.CO o --T--� 0 20 40 60 80 100 120 140 160 180 200 220 Time (min) Page 9 oi20-07 draft v11p141 10-8-2011 cfw;10-10-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 SchIinrgnr String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing BHCT Simulated: E -r- - 0 First Sack Depth R -First Sack Temp. Q -Last Sack Depth Last Sack Temp. _8 P ci _8 i i _8 '4 1 P- _8 4ii‘ _q g N N 8 -8 N 0 20 40 60 80 100 120 140 160 180 200 220 il Time(min) Surface Pressure Model: Calc.Pump Press. Calc.CemHP §— / N 8-` — J r I I - � I I -- 0 20 40 60 80 100 120 140 160 180 200 220 Time(min) Page 10 oi20-07 draft v1(p14)10-8-2011.cfw;10-10-2011; LoadCase Surface Casing;Version wcscem462_12 Client : Eni Petroleum Well : 0120-07 ScIrmerip String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Returns Rate: Fluids at 2762 ft_ -0 out -Qh CO- 1••- (0- U) o-f.-- O-N 0 20 40 60 80 100 120 140 160 180 200 220 Time (min) Anullar Velocity: Depth= 2762 ft p Annular Velocity 53- - p l (D- g- �3- rr 0 20 40 60 80 100 120 140 160 180 200 220 Time(min) Page 11 oi20-07 draft v1(p14)10-8-2011.cfw;10-10-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 Schlumberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 4: fluid description Mud DESIGN Fluid No: 1 Density :9.30 lb/gal Rheo. Model : HERSCHEL_B. k :2.06E-3 lbf.s^n/ft2 At temp. : 80 degF n :0.812 Ty : 8.74 lbf/100ft2 Gel Strength : 38.42 Ibf/100ft2 MUD Mud Type : WBM Job volume : 401.6 bbl Water Type : Fresh VOLUME FRACTION Solids : 7.0% Oil :0.0% Water :93.0% MUDPUSH II DESIGN Fluid No: 2 Density : 10.10 lb/gal Rheo. Model : HERSCHEL_B. k :2.54E-2 lbf.s^n/ft2 At temp. : 65 degF n : 0.420 Ty : 13.04 lbf/100ft2 Gel Strength : (lbf/100ft2) Job volume : 100.0 bbl Lead Slurry DESIGN Fluid No: 3 Density : 10.70 lb/gal Rheo. Model : HERSCHEL_B. k : 8.93E-2 lbf.s^n/ft2 At temp. : 69 degF n : 0.282 Ty :24.97 lbf/100ft2 Gel Strength : 11.88 Ibf/100ft2 DESIGN BLEND SLURRY Name : B809(a1001b Mix Fluid :9.758 gal/sk Job volume : 508.0 bbl Dry Density : 104.25 lb/ft3 Yield : 2.26 ft3/sk Quantity : 1260.02 sk Sack Weight : 100 lb Solid Fraction : 42.4% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 9.758 gal/sk Page 12 oi20-07 draft v1(p14)10-8-2011.cfw,10-10-2011, LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 Schlumberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing DeepCRETE (12.5) DESIGN Fluid No:4 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 7.96E-3 Ibf.s^n/ft2 At temp. :69 degF n :0.895 Ty : 14.59 I bf/100ft2 Gel Strength : 52.26 lbf/100ft2 DESIGN BLEND SLURRY Name : 12.5(0.76) Mix Fluid : 5.165 gal/sk Job volume :63.0 bbl Dry Density : 119.32 Ib/ft3 Yield : 1.54 ft3/sk Quantity :230.21 sk Sack Weight : 100 lb Solid Fraction : 55.1 % BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.165 gal/sk Additives Code Conc. Function D046 0.2000%BWOB Antifoam D065 0.2500%BWOB Dispersant D167 0.2500%BWOB Fluid loss Annulus ID : 13.375 in-OD: 16.000 in O O- - DeepCRETE(12.5) Lead Slurry MUDPUSHII 0_--- Mud O_ O O O O N N. 1? O— N O U) N i d C O_ O LU U .c O_ O_ 4.8 5.2 5.6 6.0 6.4 6.8 7.2 7.6 8.0 8.4 8.8 9.2 Flow Rate (bbl/min) Page 13 oi20-07 draft v1 014)10-8-2011.cfw;10-10-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 Schlumberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2755.3 ft Casing Shoe :2762.0 ft NB of Cent. Used :39 NB of Floating Cent. :39 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 2442.0 30 1/2 NW-TR-13 3/8-8-TR 3 W304 0.0 2062.0 2682.0 6 1/1 NW-TR-13 3/8-8-TR 3 W304 72.4 2442.0 2762.0 3 3/2 NW-TR-13 3/8-8-TR 3 W304 74.1 2682.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW-TR-13 3/8-8-TR 3 W304 13 3/8 16.654 15.394 No Hannover 16.000 283.26 2832.59 ft 0 20 40 60 80 100 o- I Between Cent. + 4-At Cent. +t ++ O ++ 00 L H . 1t+ �+ 1+ t 1- fl- O N ++ I + + + L - o M— Well Pipe Standoff Page 14 oi20-07 draft v11p14)10-6-2011.cfw,10-10-2011; LoadCase Surface Casing,Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 Schlumberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 6: WELLCLEAN II Oro % ft 0 50 100 0 25 50 75 100 0 - F- > L J — -- - - Std Betw.Cent. — Mud Contamination —Cement Coverage — Uncontaminated Slurry t—, OO— ' 1111111111 — — 11111111E— f1 — Fluid Sequence Cement Coverage Uncontaminated Slury Fluids Concentrations Risk Mud on the Wall a z N 0-1 I -0 0--I -0 590- -500 590- -500 t 1600- -1000 t 1000- , _., -1000 c - '7 - a 1500- -1500 fa a 1500-.5 1 `. -1500 a 0 o c ,--> A. �o 2090- 20002600- - - -2000 2590- -2500 2500- -2500 1 r I a N MI Mud IMII High Low I I DeepCRETE[12.5) ME Medium ENone Lead Slurry El MLIDPUSH II I Page 15 oi20-07 draft v1(p14)10-8-2011.cfw;10-10-2011; LoadCase Surface Casing;Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 ScIlmnbergcr String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section7: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total Item Pack. Packaging Comments Quantity Quantity Name B809 1260021b 1261 sack 100lb D929 23022 lb 231 sack 100 lb D182 5551b 23 sack 251b D046 47 lb 1 sack 50 lb D031 9527 lb 87 sack 110 lb D065 58 lb 2 sack 50 lb D167 58 lb 3 sack 25 lb Mix Water Requirements : Fresh water 414 bbls MIXING PREPARATION MUDPUSH II Volume : 100.0 bbl Density: 10.10 lb/gal Code Quantity Design Fresh water 92.485 bbl D182 554.912 lb 6.0000 Ib/bbl of base fluid D046 20.000 lb 0.2000 lb/bbl of spacer D031 9526.843 lb 95.27 lb/bbl of spacer Lead Slurry Volume :508.0 bbl Density : 10.70 lb/gal Yield : 2.26 ft3/sk Dry Phase Liquid Phase Blend: 126002 lb Design Mix Water 292.7 bbl 10.0 bbl LAS Design 8809(a1001b 126001.984 Fresh water 292.734 bbl 10.001 bbl lb DeepCRETE (12.5) Volume :63.0 bbl Density : 12.50 lb/gal Yield : 1.54 ft3/sk Dry Phase Liquid Phase Blend: (Ib) Design Mix 28.3 bbl 10.0 bbl LAS Design . Water 12.5(0.76) 23021.473 lb Fresh 28.309 bbl 10.001 bbl water D046 46.043 lb 0.2000%BWOB D065 57.554 lb 0.2500%BWOB D167 57.554 lb 0.2500%BWOB Page 16 oi20-07 draft v1(p141 10-8-2011.cfw•10-10-2011- LoadCase Surface Casing;Version wcs-cem462_12 Schlumberger CemCAD E*well cementing recommendation for 9 5/8" Intermediate Casing Operator : Eni Petroleum Well : 0120-07 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Luca Borri Location : Nabors 245E Proposal No. : Draft v1 (P14) Service Point : Prudhoe Bay Alaska Date Prepared : 10-9-2011 Business Phone : (907)659-2434 FAX No. : (907)659-2538 Prepared by : Jeff Long Phone : (907)273-1778 Cell : (907)223-0093 E-Mail Address : JLong1©slb.com d C 04„ Ito oTE • Disclaimer Notice: Schlumberger submits this document with the benefit of its judgment.experience.and good oilfield practices. This information is provided in accordance with generally accepted industry practice.relying on facts or information provided by others.limitations.computer models,measurements,assumptions and inferences that are not infallible. • Calculations are estimates based on provided information.All proposals,recommendations,or predictions are opinions only. NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA,INFORMATION PRESENTED.EFFECTIVENESS OF MATERIAL,PRODUCTS OR SUPPLIES,RECOMMENDATIONS MADE,OR RESULTS OF THE SERVICES RENDERED. Freedom from infringement of any intellectual property rights of Schlumberger or others is not to be inferred and no intellectual property rights are granted hereby. *Mark of Schlumberger Client : Eni Petroleum Well : 0120-07 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 50.0 ft Total MD : 12060.0 ft BHST : 63 degF Bit Size : 12 1/4 in ft lb/gal < _ - 0 12 16 • •▪ •Sandstone• •▪• •Sandstone• • • • • i Coal •▪• •Sandstone• • • • smemireemer VENIENIMMEMEN EMI - 1 Well Lithology Formation Press. Page 2 0120-07 draft v1(p14)10-8-2011.cfw;10-10-2011; LoadCase 9 5/8 FP;Version wcs-cem482_12 Client : Eni Petroleum Well : 0120-07 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 2763.0 13 3/8 68.0 12.415 Landing Collar MD : 11979.0 ft Casing/liner Shoe MD : 12059.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 12059.0 9 5/8 40.0 47.0 8.681 L-80 4760 6870 BTCM Mean OH Diameter : 12.250 in Mean Annular Excess : 50.0 % Mean OH Equivalent Diameter: 13.371 in Total OH Volume : 1614.5 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 12059.0 12.250 50.0 13.371 12060.0 12.250 0.0 12.249 Page 3 oi20-07 draft v1(p1 4)10-8-2011 cfw;10-10-2011, LoadCase 9 5/8 FP:Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 Schhouhrger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Max. Deviation Angle : 86 deg Max. DLS : 3.760 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 290.0 0.000 100.0 100.0 0.0 290.0 0.000 200.0 200.0 0.0 290.0 0.000 250.0 250.0 0.0 290.0 0.000 300.0 300.0 0.8 290.0 1.500 350.0 350.0 1.5 290.0 1.500 400.0 399.9 3.4 290.0 3.760 500.0 499.5 7.1 290.0 3.750 600.0 598.3 10.9 290.0 3.750 700.0 695.8 14.6 290.0 3.750 800.0 791.6 18.4 290.0 3.750 900.0 885.4 22.1 290.0 3.750 1000.0 976.8 25.9 290.0 3.750 1100.0 1065.2 29.6 290.0 3.750 1200.0 1150.5 33.4 290.0 3.750 1300.0 1232.1 37.1 290.0 3.750 1400.0 1309.8 40.9 290.0 3.750 1456.9 1352.2 43.0 290.0 3.741 1500.0 1383.6 43.2 290.0 0.511 1600.0 1456.2 43.7 290.0 0.500 1700.0 1528.1 44.2 290.0 0.500 1800.0 1599.5 44.7 290.0 0.500 1900.0 1670.2 45.2 290.0 0.500 2000.0 1740.3 45.7 290.0 0.500 2100.0 1809.8 46.2 290.0 0.500 2161.3 1852.1 46.5 290.0 0.489 2200.0 1878.4 48.0 289.7 3.751 2300.0 1942.9 51.7 288.9 3.750 2400.0 2002.3 55.4 288.2 3.754 2500.0 2056.5 59.1 287.5 3.751 2600.0 2105.0 62.8 286.9 3.748 2700.0 2147.9 66.5 286.3 3.744 2763.9 2172.1 68.9 286.0 3.758 2800.0 2184.7 70.2 285.8 3.747 2900.0 2215.5 73.9 285.3 3.752 3000.0 2240.0 77.7 284.8 3.750 3100.0 2258.2 81.4 284.3 3.750 3128.7 2262.2 82.4 284.2 3.755 3200.0 2271.6 82.4 284.2 0.000 3300.0 2284.7 82.4 284.2 0.000 3400.0 2297.9 82.4 284.2 0.000 3500.0 2311.0 82.4 284.2 0.000 3600.0 2324.2 82.4 284.2 0.000 3700.0 2337.3 82.4 284.2 0.000 3800.0 2350.4 82.4 284.2 0.000 3900.0 2363.6 82.4 284.2 0.000 4000.0 2376.7 82.4 284.2 0.000 4100.0 2389.9 82.4 284.2 0.000 4200.0 2403.0 82.4 284.2 0.000 4300.0 2416.1 82.4 284.2 0.000 4400.0 2429.3 82.4 284.2 0.000 4500.0 2442.4 82.4 284.2 0.000 4600.0 2455.6 82.4 284.2 0.000 Page 4 oi20-07 draft vt fp14)10-8-2011.cfw,10-10-2011: LoadCase 9 5/8 FP,Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 Schlmi/rger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg)_ _ (deg/100ft) 4700.0 2468.7 82.4 284.2 0.000 4800.0 2481.8 82.4 284.2 0.000 4900.0 2495.0 82.4 284.2 0.000 5000.0 2508.1 82.4 284.2 0.000 5100.0 2521.3 82.4 284.2 0.000 5200.0 2534.4 82.4 284.2 0.000 5300.0 2547.5 82.4 284.2 0.000 5400.0 2560.7 82.4 284.2 0.000 5500.0 2573.8 82.4 284.2 0.000 5600.0 2587.0 82.4 284.2 0.000 5700.0 2600.1 82.4 284.2 0.000 5800.0 2613.2 82.4 284.2 0.000 5900.0 2626.4 82.4 284.2 0.000 6000.0 2639.5 82.4 284.2 0.000 6100.0 2652.6 82.4 284.2 0.000 6200.0 2665.8 82.4 284.2 0.000 6300.0 2678.9 82.4 284.2 0.000 6400.0 2692.1 82.4 284.2 0.000 6500.0 2705.2 82.4 284.2 0.000 6600.0 2718.3 82.4 284.2 0.000 6700.0 2731.5 82.4 284.2 0.000 6800.0 2744.6 82.4 284.2 0.000 6900.0 2757.8 82.4 284.2 0.000 7000.0 2770.9 82.4 284.2 0.000 7100.0 2784.0 82.4 284.2 0.000 7200.0 2797.2 82.4 284.2 0.000 7300.0 2810.3 82.4 284.2 0.000 7400.0 2823.5 82.4 284.2 0.000 7500.0 2836.6 82.4 284.2 0.000 7600.0 2849.7 82.4 284.2 0.000 7700.0 2862.9 82.4 284.2 0.000 7800.0 2876.0 82.4 284.2 0.000 7900.0 2889.2 82.4 284.2 0.000 8000.0 2902.3 82.4 284.2 0.000 8100.0 2915.4 82.4 284.2 0.000 8200.0 2928.6 82.4 284.2 0.000 8300.0 2941.7 82.4 284.2 0.000 8400.0 2954.8 82.4 284.2 0.000 8500.0 2968.0 82.4 284.2 0.000 8600.0 2981.1 82.4 284.2 0.000 8700.0 2994.3 82.4 284.2 0.000 8800.0 3007.4 82.4 284.2 0.000 8900.0 3020.5 82.4 284.2 0.000 9000.0 3033.7 82.4 284.2 0.000 9100.0 3046.8 82.4 284.2 0.000 9200.0 3060.0 82.4 284.2 0.000 9300.0 3073.1 82.4 284.2 0.000 9400.0 3086.2 82.4 284.2 0.000 9500.0 3099.4 82.4 284.2 0.000 9600.0 3112.5 82.4 284.2 0.000 9700.0 3125.7 82.4 284.2 0.000 9800.0 3138.8 82.4 284.2 0.000 9900.0 3151.9 82.4 284.2 0.000 10000.0 3165.1 82.4 284.2 0.000 10100.0 3178.2 82.4 284.2 0.000 10200.0 3191.4 82.4 284.2 0.000 10300.0 3204.5 82.4 284.2 0.000 Page 5 oi20-07 draft v1(p14)10-8-2011.cfw;10-10-2011, LoadCase 9 5/8 FP;Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 10400.0 3217.6 82.4 284.2 0.000 10500.0 3230.8 82.4 284.2 0.000 10600.0 3243.9 82.4 284.2 0.000 10700.0 3257.0 82.4 284.2 0.000 10800.0 3270.2 82.4 284.2 0.000 10900.0 3283.3 82.4 284.2 0.000 11000.0 3296.5 82.4 284.2 0.000 11100.0 3309.6 82.4 284.2 0.000 11200.0 3322.7 82.4 284.2 0.000 11300.0 3335.9 82.4 284.2 0.000 11400.0 3349.0 82.4 284.2 0.000 11450.5 3355.7 82.4 284.2 0.000 11500.0 3361.8 83.3 283.6 1.993 11600.0 3372.0 85.0 282.6 1.999 11658.4 3376.6 86.0 282.0 2.003 11700.0 3379.5 86.0 282.0 0.000 11800.0 3386.5 86.0 282.0 0.000 11900.0 3393.4 86.0 282.0 0.000 12000.0 3400.4 86.0 282.0 0.000 12060.0 3404.6 86.0 282.0 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 716.0 11.90 8.43 SV-4 Sandstone 979.0 12.00 8.43 SV-3 Siltstone 1278.0 12.20 9.00 SV-2 Sandstone 1946.0 12.30 9.00 SV-1 Sandstone 2057.0 12.50 9.00 Permafrost Base Shale 2350.0 12.50 9.00 Ugnu Top(UG4) Coal 2763.0 12.50 9.00 Casing Pt. Shale 4387.0 12.50 9.00 UG2 Coal Bed Marke Coal 8920.0 12.50 9.00 Lower Ugnu Sandstone 8984.0 12.50 9.00 Fault 17-02 1 Sandstone 10392.0 12.80 9.00 Schrader Bluff Shale 10501.0 12.50 9.00 N Seq Top Sandstone 10797.0 12.50 9.00 N Top Sandstone 11043.0 12.50 9.00 N Bottom Sandstone 11365.0 12.50 9.00 N Seq Base Sandstone 11974.0 12.50 9.00 OA Sand Top Sandstone 12060.0 12.50 9.00 TD Shale Page 6 oi20-07 draft v1(p14)10-8-2011.cfw,10-10-2011, LoadCase 9 5/8 FP,Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 50 0.0 2057.0 1780.0 32 -1.0 12060.0 3404.6 63 0.4 ft degF 0 30 35 40 45 50 55 60 65 70 75 80 85 - Geoth.Profile -Tubular Fluids -Annulus O O a- u) O 1 O O- O O O Temp. Profile At 194 min Page 7 oi20-07 draft v1(p14)10-8-2011.cfw,10-10-2011, LoadCase 9 5/8 FP;Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 2: fluid sequence Job Objectives: Cement coverage verifiable to 1000'above the top of the N-Sand Original fluid Mud 9.40 lb/gal k: 8.82E-3 Ibf.s^n/ft2 n : 0.572 Ty: 9.46 lbf/100ft2 Displacement Volume 876.9 bbl Total Volume 1187.9 bbl TOC 9786.5 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) Citric Pill 35.0 418.3 8412.1 10.00 k:8.82E-3 lbf.s^n/ft2 n:0.572 Ty:9.46 lbf/100ft2 MUDPUSH II 80.0 956.1 8830.4 11.00 k:4.94E-2 Ibf.s^n/ft2 n:0.369 Ty:18.29 lbf/100ft2 DeepCRETE(12.5) 196.0 2272.5 9786.5 12.33 k:7.81 E-3 Ibf.s^n/ft2 n:0.899 Ty:17.24 lbf/100ft2 Mud 876.9 0.0 9.40 k:8.82E-3 lbf.s^n/ft2 n:0.572 Ty:9.46 lbf/100ft2 WARNING : Differential pressure across casing equipment valve is low. This will be remedied with the use of a positive seal Float Collar, typically used for Oliktok Pt. Wells Static Security Checks: Frac 342 psi at 2763.0 ft Pore 44 psi at 2763.0 ft Collapse 4570 psi at 11979.0 ft Burst 6846 psi at 50.0 ft Csg.Pump out 68 ton Check Valve Diff Press 28 psi • Page 8 oi20-07 draft v1(p14)10-8-2011.cfw;10-10-2011. LoadCase 9 5/8 FP,Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP CemCADE Client : Eni Petroleum Well :0120-07 String :9 5/8" Intermediate Casing District : Prudhoe Bay Alaska Country : USA ft lb/gal o 0 2 4 6 8 10 12 14 - —Hydrostatic —Mn.Hydrostatic —Max.Dynamic O - --- Mn.Dynamic - Frac N - Pore o - 0 ,E, O O 3 � - LL 00 co _ ■i i■ U O - O 0 0 o C O- 3 o O d O �J Fluid Sequence Dynamic Well Security 5 Citric Fill 35.0 bbl 10.00 lb/gal Herschel:k=8.82E-3 Ibf.s^n/ft2 n=0.572 Ty=9.46 Ibf/100ft2 MUDPUSH II 80.0 bbl 11.00 lb/gal Herschel:k=4.94E-2 lbf.s^n/ft2 n=0.369 Ty=18.29 Ibf/100ft2 DeepCRETE(12.5) 196.0 bbl 12.33 lb/gal Herschel:k=7.81E-3 lbf.s^n/ft2 n=0.899 Ty=17.24 lbf/100ft2 ■Mud 876.9 bbl 9.40 lb/gal Herschel:k=8.82E-3 Ibf.s^n/ft2 n=0.572 Ty=9.46 Ibf/100ft2 Total Depth =12060.0 ft Top of Cement= 9786.5 ft *Mark of Schlumberger SCIilimberpr Page 9 oi20-07 draft v1(p141 10-8-2011.ctw;10-10-2011, LoadCase 9 5/8 FP;Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) Citric Pill 5.0 35.0 7.0 35.0 80 Pump Citric Pill Ahead 5.0 80 Line-up Cement Unit MUDPUSH II 5.0 80.0 16.0 80.0 80 Pump Spacer Ahead 3.0 80 Drop Bottom Plug 2.0 80 Line up to Pump Cement DeepCRETE 5.0 196.0 39.2 196.0 80 Mix&Pump Slurry at 3 to 7 BPM 5.0 80 Drop Top Plug Mud 8.0 10.0 1.3 10.0 80 Kick Out Plug 3.0 80 Line Up Rig Pumps Mud 8.0 856.9 107.1 866.9 80 Displace w/Rig Pumps Mud 5.0 10.0 2.0 876.9 80 Slow Rate Shut-In 3.0 80 Bump Plug Total 03:10 hr:mn 1187.9 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 125 psi at 12060.0 ft Pore 44 psi at 2763.0 ft Collapse 4452 psi at 45.2 ft Burst 6378 psi at 50.0 ft Temperature Results BHCT 71 degF Simulated Max HCT 70 degF Simulated BHCT 55 degF Max HCT Depth 246.1 ft CT at TOC 56 degF Max HCT Time 03:08:33 hr:mn:sc Static temperatures : At Time (hr:mn) 00:03 hr:mn Geo.Temp. Top of Cement (degF) 56 degF 58 degF Bottom Hole (degF) 55 degF 63 degF Page 10 oi20-07 draft v1(p141 10-8-2011.cfw,10-10-2011, LoadCase 9 5/8 FP,Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP ECD at Casing Shoe: Depth= 12059 ft coN v r Hydrostatic li -Dynamic O Frac Pore t0 -FA N a) tp 52 cfr____ oi- cv O oS co cd O 20 40 60 80 100 120 140 160 180 200 220 Time (min) ECD at Surface Casing Shoe: Depth= 2763 ft Fluids at 12059 ft coN -r Hydrostatic -Dynamic O Frac - Fare CO 0s- v 5 co o�- Mm W -T-- 1 -- O 20 40 60 80 100 120 140 160 180 200 220 Time(min) Page 11 0120-07 draft v1(p141 10-8-2011 cfw,10-10-2011; LoadCase 9 5/8 FP;Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 SOW" String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP BHCT Model: Fo o le- -First Sack Depth First Sack Temp. L[� Last Sack Depth -N I� -Last Sack Temp. 1 ....„3_ �fl g <n . k•E @_ 1 (-..‘ 8_] -d 1 1 Aii&__ in1 .111 0 30 60 90 120 150 180 210 Time(min) Surface Pressure Model: 8 Calc.Pump Press.� Calc.CemHP § Yr § \ yo 77 — 8 O 0 30 60 90 120 150 180 210 Time(min) Page 12 oi20-07 draft v1(p14)10-8-2011.cfw;10-10-2011, LoadCase 9 5/B FP:Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 SII Schbokrier String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Returns Rate: Fluids at 12059 ft O Out Oh co- (0- ^c u' - - O -- 0 30 60 90 120 150 180 210 Time (min) Anullar Velocity: Depth= 12.059 ft Annular Velocity p� ! 8 9- 11\ O T 0 30 60 90 120 150 180 210 Time(min) Page 13 oi20-07 draft v1 4314)10-8-2011.cfw;10-10-2011; LoadCase 9 5/8 FP;Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 4: centralizer placement Top of centralization :50.0 ft Bottom Cent. MD :12049.0 ft Casing Shoe :12059.0 ft NB of Cent. Used :37 NB of Floating Cent. :37 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 10299.0 0 0/0 0.0 10317.0 11059.0 19 1/1 NW-TR-9 5/8-6-TR 3A W090 0.0 11042.4 11419.0 0 0/0 0.0 11059.0 11979.0 14 1/1 NW-TR-9 5/8-6-TR 3A W090 0.0 11435.6 12059.0 4 2/1 NW-TR-9 5/8-6-TR 3A W090 82.2 12059.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW-TR-9 5/8-6-TR W090 9 5/8 12.850 11.591 No Hannover 11.625 775.59 5626.97 3A ft o 0 20 40 60 80 100 Between Cent. c - + +At Cent. O O O O O — i — —' - S - N Well Pipe Standoff Page 14 oi20-07 draft v1(p14)10-8-2011.cfw;10-10-2011; Loadtase 9 5/8 FP;Version wcs-cem462_12 Client : Eni Petroleum Well : 0120-07 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 5: fluid description Mud DESIGN Fluid No: 1 Density :9.40 lb/gal Rheo. Model : HERSCHEL_B. k :8.82E-3 Ibf.s^n/ft2 At temp. :80 degF n :0.572 Ty :9.461bf/100ft2 Gel Strength :21.35 Ibf/100ft2 MUD Mud Type :WBM Job volume :876.9 bbl Water Type : Fresh VOLUME FRACTION Solids : 4.0% Oil :20.0 Water : 76.0 MUDPUSH II DESIGN Fluid No: 2 Density : 11.00 lb/gal Rheo. Model : HERSCHEL_B. k :4.94E-2 Ibf.s^n/ft2 At temp. : 58 degF n :0.369 Ty : 18.29Ibf/100ft2 Gel Strength : 40.56 Ibf/100ft2 Job volume : 80.0 bbl DeepCRETE(12.5) DESIGN Fluid No:4 Density : 12.33 lb/gal Rheo. Model : HERSCHEL_B. k : 7.81E-3 Ibf.s^n/ft2 At temp. : 58 degF n : 0.899 Ty : 17.24 lbf/100ft2 Gel Strength : 55.82 Ibf/100ft2 DESIGN BLEND SLURRY Name : 12.5(0.76) Mix Fluid : 5.662 gal/sk Job volume : 196.0 bbl Dry Density : 119.32 lb/ft3 Yield : 1.60 ft3/sk Quantity : 686.22 sk Sack Weight : 100 lb Solid Fraction : 52.8% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.662 gal/sk Additives Code Conc. Function_ D046 0.2000%BWOB Antifoam D065 0.2500%BWOB Dispersant D167 0.2500%BWOB Fluid loss D153 0.1000%BWOB Antisettling Page 15 oi20-07 draft v1(p14)10-8-2011.cfw,10-10-2011, LoadCase 9 5/8 FP,Version wcs-cem482_12 Client : Eni Petroleum Well : 0120-07 ScIliderger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Citric Pill DESIGN Fluid No:5 Density : 10.00 lb/gal Rheo. Model : HERSCHEL_B. k :8.82E-3 lbf.s^n/ft2 At temp. : 58 degF n :0.572 Ty :9.461bf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :35.0 bbl Annulus ID: 9.625 in-OD: 12.250 in In — MIDPUSH II — Mid — DeepCRETE(12.5) O O— O O O N z co P- o 0_ O .0 O 1.0 1 I I 4.8 5.2 5.6 6.0 6.4 6.8 7.2 7.6 8.0 8.4 8.8 9.2 Flow Rate (bbVmin) Page 16 oi20-07 draft v1(p14)10-8-2011.cfw;10-10-2011; LoadCase 9 5/8 FP;Version wcs-cem482_12 Client : Eni Petroleum Well : 0120-07 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 6: WELLCLEAN II % 0,0 ft 0 50 100 0 25 50 75 100 Q < > �( -Std Betw.Cent. -- Mud Contamination $� -Cement Coverage - Uncontaminated Slurry W - S l7- � Ll I Fluid Sequence Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall 6 z° 5000 5004 5000 -5004 6600 6000 6000 -8000 7000 7000 7000 -7000 8000 .I !I8000 f f 8000 -8000 9600 1 i J.. 9006 0 o 9000 -9000 0 14000 10000 10,000 -10000 11000- 11000 11000 -11000 MIMI 12000 • 12000 12000 -12000 s d o o z 0 m Mud I I High ' Low 1 = DeepCRETE (12.5) 1 I Medium I . I None I I MUDPUSH II I I Citric Pill Page 17 oi20-07 draft v1 1014)10-8-2011.ctw;10-10-2011; LoadCase 9 5/6 FP;Version wcs-cern462_12 Client : Eni Petroleum Well : 0120-07 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 FP Section 7: operator summary TOTAL MATERIAL REQUIREMENTS Additives Total Item Pack. Packaging Comments Quantity Quantity Name D972 68623lb 687 sack 100lb D047 8.0 gal 2 can 5.0 gal D182 560lb 23 sack 251b F103 160.0 gal 33 can 5.0 gal D031 Barite 14827 lb 135 sack 110 lb D046 137 lb 3 sack 50 lb D065 172 lb 4 sack 50 lb D167 172 lb 7 sack 251b D153 69 lb 3 sack 251b Mix Water Requirements : Fresh water 193 bbls MIXING PREPARATION MUDPUSH II Volume :80.0 bbl Density: 11.00 lb/gal Code Quantity Design Fresh water 67.134 bbl D047 8.000 gal 0.1000 gal/bbl of spacer D182 560.000 lb 7.0000 lb/bbl of spacer F103 160.000 gal 2.0000 gal/bbl of spacer D031 11619.204 lb 145.24 lb/bbl of spacer DeepCRETE Volume : 196.0 bbl Density : 12.33 lb/gal Yield : 1.60 ft3/sk Dry Phase Liquid Phase Blend: (Ib) Design Mix 92.5 bbl 10.0 bbl LAS Design Water 12.5 68622.469 lb Fresh 92.516 bbl 10.001 bbl water D046 137.245 lb 0.2000%BWOB D065 171.556 lb 0.2500%BWOB D167 171.556 lb 0.2500%BWOB 0153 68.622 lb 0.1000%BWOB Citric Pill Volume : 35.0 bbl Density: 10.00 lb/gal Code Quantity Design Fresh water 32.886 bbl Barite 3208.279 lb 91.67 lb/bbl of spacer Page 18 oi20-07 draft v1(p14)10-8-2011 cfw,10-10-2011: LoadCase 9 5/8 FP;Version wcs-cem462_12 00.41 Oliktok Point Nikaitchuq Field o ' 2nd p troieum 0120-07 (P14) Alaska DIR/LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD MD TVD SIZE SPECS Hazards Cement to Surface I 20" Hole Angle X-65 0° 20"Conductor Shoe 160' 160' N/A Welded/Driven N/A 0 GR/Res Surface Csq Dir -o 13-3/8" Base Permafrost 2,057' 1.779' D 68 lbs/ft MW(ppg) Wellbore Stability cn Mud Motor L-80.BTC 9.2-9.5 Lost Circulation Hole Cleaning O 13-3/8"Casing Point 2,763' 2,172' 16" 50°F WBM GR/RES PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Xceed 900 40 lbs/ft MW(ppg) Hole Cleaning L-80,Hydril 563 9.4 Torque&Drag TOO 9.797' 2T N N "N"Sand Top 10,797' Injection Packer 10,859' _ _ NOTE: Injectors REQUHE CBL on Intermediate Casing : n TOL 11.859' 9-5/8"Casing Point 12.059' 3,405' 12-1'4" 85°F LSND GR/RES Periscope/PWD Wellbore Stability SONIC Lost Circulation Schrader Bluff Slotted Liner Hole Cleaning Lateral 4-1/2" Torque&Drag 11.6 lbs/ft MW(ppg) Xceed 675 L-80,Hydril 521 9.4 (Geo-Steering) 4-1/2"Liner TD 19,438' 3,351' 8-1.2" 85 F OBM it ENI S.p.A. SPEO IDENTIFICATION CODE PAG 206 OF 338 Enn E&P Division REVISION STAP-P-1-M-6140 0 1 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of`Equivalent Mud Weight' (EMW): Imperial units EMW= +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight (PPG) Metric units EMW = P x 10 + MW TVD where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight (kg/I). ENI S.p.A. SPEO IDENTIFICATION CODE PAG 207 OF 338 Eni E&P Division REVISION STAP-P-1-M-6140 0 1 LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance, the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT) or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 1/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. LS P E O IDENTIFICATION CODE PAG 208 OF 338 ENI S.p.A. Eni E&P Division REVISION STAP-P-1-M-6140 0 1 13) Continue this procedure until: • Two or three points on the plot are reached where the pressure deviates and falls below the approximate straight line (or if the pressure does not increase with the injected volume). The point on the plot where the curve begins to bend away from the straight line is called Leak Off Point (Refer to Figure 15-1) • Or the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot pressure versus time until stabilisation (usually it takes 15-20min). In the early stage (2-3min) one value every 15-30sec should be collected while for the remaining a value of pressure every 30- 60sec may be sufficient. The use of PACR or an equivalent device, if available, is preferred. 15) Bleed off the pressure and record the quantity of fluid returned into the cementing unit. Compare it to the volume used for the test to obtain the amount of fluid lost to the formation. 16) Open the BOP and calculate the formation strength in terms of `Equivalent Mud Weight' using the lowest between leak off point pressure and stabilised pressure. 17) Collect the data recorded during the test in a data sheet together with the following information: borehole diameter, depth of test, depth and type of the last casing, mud density, plastic viscosity, filtrate and gels (refer to the example on the next page). Note: The LOT pressure doesn't exceed the pressure which the casing was tested. Note: When a good zonal isolation behind the casing is imperative, the Leak- off test should be carried out with a retrievable packer to avoid pressurising the casing which may cause possible permanent damage to the cement bond by the creation of micro annuli in the cement. Note: The pumping rate should be kept within the limits described in step 9). If the rate is too low, filtration losses will mask any leakage loss, or, if the rate is too high the formation may suddenly break and the leak off pressure will not be determined. Also, the longer the open hole section, the higher should be the injection rate. If the initial pumping rate is not sufficient, the well should be depressurized and the test restarted with a higher rate. Note: If a float valve is used in the drilling string, the test can not be carried out by pumping down the drill pipe. In this case rig up the cementing unit to the choke or kill line, fill and test the lines against the fail-safe and establish circulation through the riser. Close the BOP and perform the formation strength test pumping down the annulus. 1101* ENI S.p.A. SPEO IDENTIFICATION CODE PAG 209 OF 338 Em E&P Division REVISION STAP-P-1-M-6140 0 1 - filth LEAK-OFF TEST REPORT Report N° Date: WELL NPAAE: WELL CODE: CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m): 825 MudTwe: FWGELS RigtWe: J.UPs Hole 13 amete r(in): 171/4 Weight(KgA): 1.3 R.K.B.elevation(m): 26 Last Csg.Shoe(m): 797 Marsh Viscosity(sec/Ot): 44 Water Depth(m): 24 C .diameter¢n): 131/8 P.V(cps): 19 Pumps: 12-P-160 Grade: J.55 Y.P.(1b1100 f°): 5 Liners(in): 6.5" Weight(b/t): 61 Gelslb/100 t): 2/8 Flow Rate(bpi): 0.25 Max.Burst pres(psi): 3103 W.L(cc 30 min): 10.5 Litholog y Shale Expected EMW 1.68 Kg/cm2110 m Time Vol une Pressure Time Volume Pressure Time Volume Pressure (min) (bbl) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 490 16 2 435 2 060 100 95 2 480 3 0.75 200 10 2 470 4 180 300 10.5 2 463 5 115 400 11 2 455 6 1.5D 500 11.5 2 460 7 1.75 570 12 2 446 8 2D0 600 13 2 440 8 200 550 14 2 437 8.5 2D0 505 15 2 435 Note: Pumped with a constant low rate of(bbl): \blume pumped(bbl): \blume returned(bbl). (per) 1000 900 • 800 • - stop pump P 700 r . e 600 • • shut in curve S500 - _+*_rti U 400 r - 18 minutes e 300 - 200 . 100 • 0 • 0 0,25 0,5 0,75 1 1,25 1,5 1,75 / 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(bbf) 4 P. Time mins RESULTS: (Press.mw+Press.LO,)x10iDepth=[(1.3 x 797/10)+(430 x 0.07)]x 10 1797=1.68(Kg/cm2/10 m) Note: I Company Representative Figure 15-1 - Leak-Off Test Report REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 01 iktok OLIKTOK 5�� 0 Point INTAKE DOCK OPP THIS 1 MODULE Pig P� P SURVEY _O N '',-.?,-.:°,0 4. j ��•, ` DS-3R OVo DEW UNE 9' U SITE STP '. TANK ' OUKTOK POINT MODULES N)C STAGING AREA•, Ti3N, R9E ;'DS-30 / ' 1 fe, X 1 1 : \ .O 15 SCALE: 1" = 150' r, / `y DSI 30 i 1 19 0 9l �,.,2, l .m.M STP PAD VICINITY MAP 00 �'� SCALE: 1" = 1 Mile O 00.0 °°°°0 ('o \ ar' \ 000 0.0 N- 00-0 °�o'rocP \ -o '-'1.4.3s0 7' \\\\ 00000 0� \ 0000 D0v'�� • 0' '\ 000\\\\ 0.0 i90j O o� \ �� 0000,0 909°;3' .; \ r�4 r 0 7 \ OLIKTOK \\ 0 POINT PAD \ ,..0, \ o• 90 \ N-3 \ \ \\ 0 ) 0A\ \ / \ \ SEE SHEET 3 FOR NOTES / \ \ / LOUNSBURY • Existing Conductor f & ASSOCIATES, INC. • Conductor Asbuilt this survey / SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: iir-' _, Eni PeA. troII�um OLIKTOK POINT PAD Cinln 1� 'r WELL CONDUCTOR ASBUILT LOCATIONS CAD LK680D1 10/9/08 DRAWING NO: NSK 6.80-d1 I PART: 1 OF 3 I REV: 2 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 PROTRACTED SECTION 5, T. 13 N., R. 9 E., UMIAT MERIDIAN AK STATE PLANE(NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD O.G. WELL NO. `y' 'X NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP-11 6,036,332.70 1,656,791.89 70°30'39.015" 149° 51'57.587" 2,052 1,519 12.1 4.0 OP-12 6,036,328.85 1,656,784.83 70°30'38.977" 149° 51'57.795" 2,056 1,526 12.2 4.0 0P03-P05 6,036,325.10 1,656,777.76 70°30'38.940" 149°51'58.004" 2,059 1,533 12.2 4.0 0PO4-P07 6,036,321.43 1,656,770.69 70°30'38.904" 149°51'58.212" 2,063 1,541 12.2 3.8 OP05 6,036,317.71 1,656,763.67 70°30'38.868" 149°51'58.419" 2,067 1,548 12.2 3.7 OP06 6,036,313.96 1,656,756.55 70°30'38.831" 149°51'58.629" 2,070 1,555 12.2 3.6 OP07 6,036,306.41 1,656,742.45 70°30'38.757" 149°51'59.045" 2,078 1,569 12.2 3.5 OP08 6,036,302.66 1,656,735.36 70°30'38.720" 149°51'59.254" 2,082 1,576 12.2 3.5 0P09 6,036,298.90 1,656,728.32 70°30'38.683" 149°51'59.462" 2,085 1,583 12.2 3.5 OP10 6,036,295.16 1,656,721.26 70°30'38.647" 149°51'59.670" 2,089 1,590 12.2 3.7 OP11 6,036,291.38 1,656,714.21 70°30'38.610" 149°51'59.878" 2,093 1,597 12.2 3.8 OP12 6,036,287.63 1,656,707.14 70°30'38.573" 149°52'00.086" 2,097 1,604 12.2 4.0 OP13 6,036,276.37 1,656,685.97 70°30'38.463" 149°52'00.711" 2,108 1,626 12.2 3.6 OP14 6,036,272.66 1,656,678.89 70°30'38.426" 149°52'00.920" 2,112 1,633 12.2 3.5 OP15 6,036,268.88 1,656,671.79 70°30'38.389" 149°52'01.129" 2,115 1,640 12.2 3.4 OP16 6,036,265.11 1,656,664.75 70°30'38.353" 149° 52'01.337" 2,119 1,647 12.2 3.3 OP17 6,036,261.36 1,656,657.70 70°30'38.316" 149°52'01.545" 2,123 1,654 12.2 3.2 OP18 6,036,257.62 1,656,650.62 70°30'38.279" 149°52'01.753" 2,127 1,681 12.2 3.1 OP19 6,036,250.09 1,656,636.50 70°30'38.205" 149°52'02.170" 2,134 1,675 12.2 2.5 OP20 6,036,246.31 1,656,629.41 70°30'38.168" 149°52'02.379" 2,138 1,682 12.2 2.2 OP21 6,036,242.57 1,656,622.39 70°30'38.132" 149°52'02.586" 2,141 1,689 12.2 1.9 OP22 6,036,238.82 1,656,615.39 70°30'38.095" 149°52'02.793" 2,145 1,696 12.2 1.7 OP23 6,036,235.05 1,656,608.27 70°30'38.058" 149°52'03.003" 2,149 1,703 12.2 1.5 OP24 6,036,231.36 1,656,601.27 70°30'38.022" 149°52'03.209" 2,153 1,710 12.2 1.3 DISPOSAL WELLS AK STATE PLANE (NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD O.G. WELL NO. 'y' 'X NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP25 6,036,004.35 1,656,510.91 70°30'35.791" 149°52'05.885" 2,380 1,802 12.2 -2.7 OP26 6,036,012.10 1,656,525.47 70°30'35.867" 149° 52'05.456" 2,372 1,787 12.2 -2.7 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: r Ire��urollkuu.��nni WELLOLIKTOK PAD Ci ErniASBUILTLOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80-d1 2 OF 3 2 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductos 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 NOTES 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, NAD 83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD 83. 3. BASIS OF LOCATIONS ARE DERIVED FROM OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 5, TOWNSHIP 13 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 5. ALL ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. SEE LOUNSBURY DOCUMENT L-2539 FOR NAD27 INFORMATION. SURVEYOR'S CERTIFICATE �\ ; �♦♦ I HEREBY CERTIFY THAT I AM PROPERLY .. h 1% REGISTERED AND LICENSED TO PRACTICE AP 11'. ,, �• LAND SURVEYING IN THE STATE OFJ ROOKUS �i ALASKA AND THAT THIS PLAT REPRESENTS ♦ c� A SURVEY DONE BY ME OR UNDER MY ♦ `,A�'•.,. LS-8O3,,p �: DIRECT SUPERVISION AND THAT ALL � �P. <O •'�I, Z3 �B••O • CORDIMERECT SNSIONS A OF DECEMBER 23, 2008.ND OTHER DETAILS ARE +,,11*\•"‘���OrEssi �••• LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS rAREA: MODULE: UNIT: POINT Pet�roHHeu�nnl WELLOCONDUCTOR D f ASBUILT LOCATIONS CADD FILE NO. 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TRANSMITTAL LETTER CHECKLIST WELL NAME V Te-2-0 —01 PTD# Development X Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: (Val-ICAVIVtPOOL: t?rd ,ey" 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. Rev:9/09/2011 11 a0 -n0 m - o • 3 0 0 Ov o cn •g -. O - sk 3 mCO co 3 - Is. 0 0 o @ 0•(0 � v 0 co , 0 o 0 p C) 0f N .. 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