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210-153
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, May 11, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Eni US Operating Co. Inc. OI07-04 NIKAITCHUQ OI07-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/11/2023 OI07-04 50-029-23435-00-00 210-153-0 W SPT 3471 2101530 1500 83 83 77 74 155 289 283 278 INITAL P Brian Bixby 4/5/2023 Post RWO 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 OI07-04 Inspection Date: Tubing OA Packer Depth 220 1655 1603 1591IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230405162159 BBL Pumped:1.8 BBL Returned:1.8 Thursday, May 11, 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: Ran Packer______ 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 12325 feet N/A feet true vertical 3925 feet N/A feet Effective Depth measured 12313 feet 4,305 & 4,160 feet true vertical 3924 feet 3,471 & 3,424 feet Perforation depth Measured depth 5,601'-12,325'feet True Vertical depth 3,678'-3,925'feet Tubing (size, grade, measured and true vertical depth)4.5 L-80 4,140' 3,401' Packers and SSSV (type, measured and true vertical depth)HAL/SLB AHR, PHL/TRMAXX 4305',4160/2105 3471,3424/2014 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 Stefano Pierfelici Digital Signature with Date:3/22/2023 Contact Name:Amjad Chaudhry Contact Email:amjad.chaudhry@eni.com Authorized Title:Well Operations Project Manager Contact Phone:907-865-3379 2315' 2192' Burst Collapse N/A 2260 4760 N/A 5020 6870 measured TVD Production Liner 5601' 6940' Casing Structural 3678' 5-1/2" 5601' 5,372'-12,313'3,563'-3,924' Plugs Junk measured N/A Length 160' 2315' 160'Conductor Surface Intermediate 20" 13-3/8" N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL 355024, 373301, 390616 Nikaitchuq/ Schrader Bluff Eni US Operating Co. Inc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 210-153 50-029-23435-00-00 Size 160 768 569N/A N/A 4854019 86 9-5/8" Slotted 3700 Centerpoint Dr, Ste.500, Anchorage, AK, 99503 3. Address: OI07-04 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf MD 691 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 322-683 Sr Pet Eng: Slotted 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. Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov DSR-3/22/23 RBDMS JSB 032323 13-3/8" 68 ppf Casing, 2,315' MD, 2,192 TVD, 34º Inc9-5/8" 47 ppf IntermediateCasing, 5,601' MD, 3,678' TVD, 85º Inc5-½17 ppfSlotted Liner,Alt. blank/slot 12,313' MD, 3,924' TVD, 89ºInc(drifted to 15.50#)3-1/2" 9.2 ppf Inner String, 12,085' MD, 3,918' TVD, 87º IncZonal Isolation PackersInjection Control DevicesAHR Retr. Packer with 2 Feed-Thrus, 4,305' MD, 3,471 TVD, 72º IncConfidentialAVOI07-04 Injector Nikaitchuq Field Oliktok Point Pad4,321' MD, 3,475' TVD, 72º Inc - 3.725" XN Part of nipple reducer left in hole, removed only 4 ½XN lock collar12,071' MD,3,917' TVD -Gauge Carrier, P/T at Toe As CompletedMarch, 20235,372' MD, 3,653' TVD, 84º Inc SLZXP Liner Hgr/Pkr 5,302' MD/3,647' TVD Gauge Carrier -for P,T at Heel 3-½Cable ClampsCompletion: 4-½12.6# L80 TH563 TK15-XT Internal Coated ID: 3.958"Well Head: Vault MB-247 2105' MD / 2014' TVD SSSV/SLB TRMAXX, 4-1/2" 3.813" Profile ¼Control Line4096' MD / 3401' TVD SLB Solid Gauge Mandrel, ¼TEC cable4250.53Tubing Cut w/ 54' of gauge line fish clamped at lower couplingCut located 4' below top of 4-½coupling at 4246.53' MD4160' MD / 3424' TVD PHL 9-5/8" PACKER 4182' MD / 3432' TVD SLB GX LANDING NIPPLE w/3.813 BORE4194' MD / 3436' TVD Autofill4196' MD / 3436' TVD Mirage Plug4214' MD / 3442' TVD SLB GLM w/SOV 4700PSI4236' MD / 3449' TVD Baker Sealed Overshot (not holding), 2' Swallow Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 2/22/2023 Report #: 1 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Overcast Temperature (°F) -11.0 Wind SE @ 23 MPH Days LTI (days) 1,995.00 Days RI (days) POB 47.0 24h Forecast Pump down tubing 150 bbls of 8.9# #% KCL kill fluid. Flow check. Nipple down tree and nipple up BOPE. Initial BOP test for OI07-04. 24h Summary Moving rig to OI07-04. Load 300 bbls 8.9# 3% KCL kill fluid into pits. Get well bay work permit and Rig up High pressure hoses to tree for Bull heading tubing. Operation at 07.00 Nipple down Tree. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:00 3.00 3.00 W.O. A 2 P PJSM and lay down mouse hole and secure in pipeshed. Secure BOPE and raise landings in Walker bays. Walk rig backwards 16' off well. 03:00 08:00 5.00 8.00 W.O. A 2 P PJSM and spot rig mats over herculite on driller's side of rig. Move High-line unit out of the way for pulling rig mats. Move cuttings box out of way for rig move. Begin cut out and unbolting of CP manifold for mods. PJSM and crab rig West 16'. 08:00 11:00 3.00 11.00 W.O. A 2 P PJSM and spot rig mat in front of rig. Prepare dunnage for spotting rig with no rig mats under front Walker feet. Change out 6" Demco butterfly valve on CP manifold. PJSM and walk rig 9' towards well bay. 11:00 16:30 5.50 16.50 W.O. A 2 P Continue measuring and cutting dunnage for spotting rig over OI07-04 and install 3x12 dunnage under Walker feet and front support beam. Notify DSO for removing SRL post from top of well bay. Remove same and continue rig move. 16:30 22:00 5.50 22.00 W.O. A 2 P Walk rig 10' and center over OI07-04. Install 3x12 dunnage under rig to pull front rig mat. Spot cuttings box and High-line unit. Berm up around rig. Install CLAM clamps and run High-line cable. Spot cuttings box and High-line unit. Remove/pick up and put away all unused dunnage. Install transfer manifold in pump room. Start load 300 Bbls 8.9# 3% KCL kill fluid into pits. 22:00 00:00 2.00 24.00 W.O. M 5 P Load 300 bbls 8.9# 3% KCL kill fluid into pits. Get well bay work permit and Rig up High pressure hoses to tree for Bull heading tubing. Prime mud pumps and pressure test line to 3,500 psi. Good test. Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0726 Eni representative Mark Ashley 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 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative David Fleming Nordic HSE 907-685-8603 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 2/23/2023 Report #: 2 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Overcast Temperature (°F) 12.0 Wind SE @ 23 MPH Days LTI (days) 1,996.00 Days RI (days) POB 53.0 24h Forecast Continue changing out upper ram door seals. Perform Initial BOPE test for OI07-04. Rig up E-line and Tractor for cutting the 4-1/2" tubing. Run in hole & cut TBG and POOH. 24h Summary Continue on loading 8.9# kill fluid. Pump 151 Bbls 8.9# 3% KCL kill fluid down tubing. Monitor well for 1 hour as per program. Set back pressure valve. Nipple down tree. Remove Heel/Toe Gauge wires from wellhead. Nipple up BOPE. Install Choke and Kill HCRs and steel lines. Make up Graylock clamps. Install hydraulic lines and function test BOPE. Perform Shell test, test failed. Replace upper ram door seals. Operation at 07.00 Testing BOPE. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. C 12 P Pressure test high pressure line and fittings to tree for bull heading. Tested to 3,500 psi. Good test. Continue on loading 8.9# kill fluid. Continue working on CP manifold. 02:00 04:00 2.00 4.00 W.O. M 9 P Pump 151 Bbls 8.9# 3% KCL kill fluid down tubing. Staged up pump to 3 BPM with 350 psi FCP. At pump shut down pressure bleed off to 0 psi. Well on VAC. A annulus was -12 psi and B annulus was -5 psi before bull heading began. Neither changed during the bull heading. Monitor well for 1 hour as per program. Well on vacuum. 04:00 05:00 1.00 5.00 W.O. C 5 P Rig down lines for bull heading tubing and set back pressure valve. 05:00 11:00 6.00 11.00 W.O. C 5 P PJSM and Nipple down tree. Clean and inspect TBG hanger threads along with grove sealing area for drilling riser spool. Mobilize Schlumberger and Wire technicians to OPP for removing control wire from well head. ENI electrician removed power source to Heel/Toe Gauge wires. Vault and Schlumberger hand. Remove Heel/Toe Gauge wires from wellhead. 11:00 19:00 8.00 19.00 W.O. C 5 P PJSM and N/U drilling riser and tighten graylock. Nipple up single gate, double date rams. Install Annular preventer and torque bolts on each connection. Install Choke and Kill HCRs and steel lines. Make up Graylock clamps. Install hydraulic lines and function test BOPE. Install air boots and flow nipple/riser. Set Mouse hole. 19:00 21:00 2.00 21.00 W.O. C 5 P Rig up TIW, DART Valve and Pump-in sub. Install Test Dart and test joint. Rig up testing assembly and hoses. Fluid pac choke and lines. 21:00 23:00 2.00 23.00 W.O. C 12 P Perform Shell test. Failed test. Choke hose connection to hard line leaked-Tighten. Choke manifold flange between valve #7 and #8 leaking-Tighten. Attempt shell test again and Upper ram door seals leaking. 23:00 00:00 1.00 24.00 W.O. C 25 U PJSM and Lock out and Tag out Koomey. Blown down BOPE Stack and replace upper ram door seals. Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0726 Eni representative Mark Ashley 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 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 2/24/2023 Report #: 3 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Overcast Temperature (°F) 12.7 Wind W @ 23 MPH Days LTI (days) 1,997.00 Days RI (days) POB 54.0 24h Forecast Perform 4-1/2" IBTM TBG cut. POOH and Rig down E-line and Welltec. Crane pick Schlumberger empty spools to rig floor. Pick up on TBG and verify cut. Bull head one TBG volume plus 120% A annulus volume. Pull hanger and lay down. POOH with 4-1/2" TBG. 24h Summary Change out door seal on upper pipe ram door. Perform BOPE test. Test Gas alarms and PVT alarms. All good tests. Attempt to bull head down A annulus. Pumped 2 Bbls and pressured up. Bleed off pressure. Make up crossover to landing joint and make up top drive to landing joint. Back out hanger lock down screws. Pull hanger free at 210K. Run in hole with E-line/Tractor with drift to 4,321'. POOH. Run in hole and perform correlation logs. Operation at 07.00 Prep to start pulling upper completion. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. C 25 U Drain Stack and lock out and tag out Koomey. Change out door seal on Upper pipe ram door. Flood stack and purge lines with fresh water for BOPE test. 02:00 09:30 7.50 9.50 W.O. C 12 P Perform initial BOPE test. Test 250 psi low and 3,500 psi high. Test with 4" and 4-1/2" test joints.Test witness waived by Guy Cook, OGC on 2-22-23 at 16:22 Hours. Rig down TIW, Dart valve and pump-in sub. Perform Koomey draw down test. Test Gas alarms and PVT alarms. Swap over to 4" test joint. Continue testing BOPE with 4" test joint. All good tests. 09:30 11:00 1.50 11.00 W.O. C 5 P Rig down testing equipment. Blow down choke manifold and test pump. PJSM and remove blanking plug and BPV from hanger. Install landing joint. 11:00 11:30 0.50 11.50 W.O. M 9 P PJSM and attempt to bull head down A annulus. Pumped 2 Bbls and 1/2 BPM and pressured up to 440 psi. Pressure holding after shut down pump. No increase in pressure on B annulus. Bleed off A annulus slowly and observed diesel mixture returns. Shut in both A and B annulus. 11:30 12:30 1.00 12.50 W.O. C 5 P Make up crossover to landing joint NS Make up top drive to landing joint. Back out hanger lock down screws. 12:30 14:00 1.50 14.00 W.O. M 5 P PJSM and pull up 160K and hold, continue up to 180K and hold. Pull up 200K and hold. Hanger still seated after several cycles to unseat. Hanger pulled free at 210K. Set tubing slips on tubing with 98K indicator reading. 14:00 18:00 4.00 18.00 W.O. R 5 P Rig up Halliburton E-line PCE and function test, good test. Rig up E-line sheaves. PJSM and make up Welltec Tractor. Function test tractor, good test. 18:00 21:00 3.00 21.00 W.O. R 15 P Run in hole with E-line/Tractor with 2.85" Drift to 4,321'. POOH with drift and install Welltec cutter assembly. Function test cutter, good test. 21:00 00:00 3.00 24.00 W.O. R 15 P Run in hole with E-line/Cutter, GR and CCL. Perform correlation logs-3 passes. Send correlation logs superimposed to Anchorage for review. Teams meeting and discuss log results with Welltec and Halliburton reps present. All in agreement on the log correlation depths and target cut area of 4,250.5' is correct. Proceed with cut. Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0726 Eni representative Mark Ashley 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 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 2/25/2023 Report #: 4 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Overcast Temperature (°F) -3.5 Wind SW @ 25 MPH Days LTI (days) 1,998.00 Days RI (days) POB 58.0 24h Forecast Continue POOH with 4-1/2" IBTM tubing laying down upper completion. 24h Summary Use Eline to makeTBG cut at 4,250.5' and POOH. Pick up 2 feet on TBG to verify cut. Bull head 100 bbls 8.9# brine down tubing. Rig up Schlumberger Tech wire and Fiber spoolers to pull upper completion. Bull Head 300 bbls 8.9# kill fluid down A annulus. Pull hanger to rig floor and terminate Schlumberger lines. Lay Down VIT joints. TEC Cables stopped coming out of hole with the TBG. TEC cables be come kinked and twisted inside BOPE. POOH leaving every other cannon clamps to get TEC cables out of hole. TEC cables became free and were pulled out. Continue POOH with 4-1/2" TBG. Operation at 07.00 POOH with 4-1/2" IBTM tubing laying down upper completion. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 W.O. R 15 P Correlate and make TBG cut at 4,250.5' ELM. POOH with E-line/Welltec cutter. 04:00 05:30 1.50 5.50 W.O. R 5 P PJSM and lay down E-line tools and Welltec tools on rig floor. Pick up 2 feet on TBG to verify cut. 05:30 08:00 2.50 8.00 W.O. L 9 P Make up circulating hose to landing joint and bull head 100 bbls 8.9# brine down tubing at 3 BPM with FCP =310 psi. 08:00 12:30 4.50 12.50 W.O. L 5 P Lift plan meeting with Worley crane and ENI lift advisor and rig crew. Prep Schlumberger Tech wire, Fiber spoolers and Job box. Lift Doyon 5.5" casing power tongs. Bull Head 300 bbls 8.9# kill fluid down A annulus at 3 BPM with 450 psi. Monitor B annulus at 0 psi. while continuing to rig up Schlumberger spooler and power tongs. Function test Power tongs and Spoolers, good test. Inspect all equipment and prep for pulling 4-1/2" TBG. 12:30 14:30 2.00 14.50 W.O. L 20 P PJSM and pull hanger to rig floor and terminate Schlumberger lines. Route through sheaves. Laydown VIT joints with rig tongs. 14:30 19:00 4.50 19.00 W.O. L 4 P No Polyoil cable clamps have been recovered. TEC cables stayed in position weather slacking off or picking up. Cut TEC wires after clamping them to TBG. Work TBG in attempt to free up TEC cables. While slacking TBG back into well the cables kinked and twisted inside BOPE. Decided to make up steel cannon clamps and pull on the cables to free them. 19:00 19:30 0.50 19.50 W.O. L 20 P POOH with TEC cables coming up with the TBG. No signs of parting while pulling. 19:30 00:00 4.50 24.00 W.O. L 4 P POOH skipping every other cannon clamp to get TEC cables out of hole. Making approximately 4' at a time. At 3,480' had 20K overpull. Slack off to string weight and continue POOH. The Tec cables continue to spool up when TBG was stopped for setting slips indicating parted lines. Continued spooling the Fiber cable and TEC cable until the parted ends were recovered at surface. This depth was 3,344'. Appears to be equal lengths of cables recovered. Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0726 Eni representative Mark Ashley 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 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 2/26/2023 Report #: 5 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Overcast Temperature (°F) -11.2 Wind SW @ 28 MPH Days LTI (days) 1,999.00 Days RI (days) POB 48.0 24h Forecast Make up fishing BHA and run in hole while picking up singles of 4" DP. Recover Schlumberger control cables and tubing collar clamps. 24h Summary Lay down 4.5" completion from 3,402' to 2,343'.Lay down TBG patch. Continue POOH to surface. Rig down Schlumberger cable spools and GBR power tongs. Prep pipe shed for loading 4" DP and 4" HWDP. Stop Work Authority drill with drilling crew. Load and strap 4" tubulars. Operation at 07.00 Make up Baker fishing BHA. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:30 3.50 3.50 W.O. L 4 P Lay down 4.5" completion from 3,402' to 2,343'. Up Wt =80/100K. Observed pin damage on joint # 81. Superior thread rep inspected a full row of 4.5" IBTM tubing and determined all were rejected because of deformed pins (IDs). Add 10 bbls of 8.9# 3% KCL kill fluid to annulus ever hour. 03:30 08:30 5.00 8.50 W.O. L 4 P Continue to lay down 4.5" completion tubing from 2,343' with up weight of 80-100K. Lay down TBG patch at joint number #67. While pulling joint #57 at 1,430' drag fell off to 50K. Continue POOH to surface. Recovered cut joint = 3.14', 97 joints of 4.5" IBTM tubing, 3 joints of 6" VIT, 1 GLM, 1 ea X nipple and 2 TEC cables-length to be determined. Recovered 2 SS bands and 6 ea. 6" mid-jt clamps from VITs. Add 10 bbls of 8.9# 3% KCL kill fluid to annulus ever hour. 08:30 11:30 3.00 11.50 W.O. L 5 P Off load 4.5" TBG from pipe shed, Rig down Schlumberger cable spools for crane pick from rig floor. Rig down power tongs. Add 10 bbls of 8.9# 3% KCL kill fluid to annulus ever hour. 11:30 12:00 0.50 12.00 W.O. L 1 P Stop Work Authority drill with drilling crew. 12:00 14:00 2.00 14.00 W.O. L 5 P Lay out old TBG hanger and 4 joints of 4.5" 563 tubing, GLM, assorted unused pup joints. Prep pipe shed for loading 4" DP and 4" HWDP. PJSM and removed Schlumberger cable spoolers and job box from rig floor. Add 10 bbls of 8.9# 3% KCL kill fluid to annulus ever hour. 14:00 00:00 10.00 24.00 W.O. M 1 P Load and strap 4" tubulars for next operations. Load and prep Fishing tools. Add 10 Bbls of 8.9# 3% KCK kill fluid to annulus ever hour. Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0726 Eni representative Mark Ashley 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 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 2/27/2023 Report #: 6 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Overcast Temperature (°F) -17.3 Wind SW @ 28 MPH Days LTI (days) 2,000.00 Days RI (days) POB 48.0 24h Forecast Continue fishing operations for Tec wire and clamps. 24h Summary Change out handling equipment for 4" DP. Install wear ring. Pick up BHA #1 with rope spear. Run in hole to 580' and Tag Control wires. POOH with rope spear loaded with stainless TECH wire. Run in hole with rope spear and tag at 1,373'. POOH, remove TEC and Fiber Optic line from spear. Run in hole with rope spear. Run #3 and tag at 1,380'. POOH and remove wire and clamps. Run in hole with rope spear. Run #4 and tag at 1,382'. POOH and very little collected from rope spear. Decision made to pick up additional 4" HWDP. Load 18 joints of 4" HWDP. Operation at 07.00 POOH with rope spear fishing assembly. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. C 5 P Load wear ring and setting tool into pipe shed. Install wear ring. 02:30 05:00 2.50 5.00 W.O. M 5 P Pick up BHA #1, rope spear, jars, Bumper sub and 12 joints of 4" HWDP- (28.01 lb/ft). 05:00 06:00 1.00 6.00 W.O. M 4 P Run #1. Pick up DP and run in hole to 580'. Up Wt=50K; Free TQ=2.2K. Tag Control wire at 580'. Add 10 bbls per hour of 8.9# 3% KCL kill fluid to well. 06:00 08:30 2.50 8.50 W.O. M 4 P Make up TD and rotate rope spear 5 revolutions. Pick up and have 5K overpull. POOH racking back stands of pipe. Up Wt=55K. Rope spear loaded with stainless TECH wire. Cut and measure. Recovered 317' of wire. Add 10 Bbls per hour of 8.9# 3% KCL kill fluid to well. 08:30 11:00 2.50 11.00 W.O. M 4 P Run in hole with rope spear. Run #2 and tag at 1,373'. Up Wt-62K. Make up top drive and rotate rope spear 5 revolutions. top drive stalled at 8K. Pick up and have 5K overpull. Up Wt now 62K. Add 10 bbls per hour of 8.9# 3% KCL kill fluid to well. 11:00 16:00 5.00 16.00 W.O. M 4 P POOH racking back stands from1,373'. Observed overpull at wellhead. Wear ring coming up with fish. Notify Vault wellhead Tech. Remove TECH and Fiber Optic line from spear. Had to cut off wires and unable to measure. Placing into empty dumpster for weighing after completion of the complete removal of wires. Dumpster empty weight = 9,000 lbs. Re-install wear ring with Vault. Add 10 bbls per hour of 8.9# 3% KCL kill fluid to well. 16:00 17:00 1.00 17.00 W.O. M 4 P Run in hole with rope spear. Run #3 and tag at 1,380'. Up Wt-70K; Dn Wt=60K; ROT=65K. Stack 5K on fish while rotating at 5 RPM. TQ=2.3KAdd 10 Bbls per hour of 8.9# 3% KCL kill fluid to well. 17:00 19:00 2.00 19.00 W.O. M 4 P POOH racking back stands from1,380'. Remove wire and clamps and save for weighing. 19:00 21:00 2.00 21.00 W.O. M 4 P Run in hole with rope spear. Run #4 and tag at 1,382'. Stack 10K and rotate 10 full turns and top drive stalled out at 8K. POOH racking back stands from1,382'. Add 10 bbls per hour of 8.9# 3% KCL kill fluid to well. 21:00 22:00 1.00 22.00 W.O. M 1 P Very little collected from rope spear. Decision made to pick up additional 4" HWDP. Add 10 bbls per hour of 8.9# 3% KCL kill fluid to well 22:00 00:00 2.00 24.00 W.O. M 1 P Load 18 joints of 4" (28.01lb/ft) HWDP. Strap pipe. Add 10 bbls per hour of 8.9# 3% KCL kill fluid to well. Load Baker Vac tool and Intensifier into shed. Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0726 Eni representative Mark Ashley 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 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 2/28/2023 Report #: 7 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Overcast Temperature (°F) -23.8 Wind SE @ 3 MPH Days LTI (days) 2,001.00 Days RI (days) POB 45.0 24h Forecast Continue with fishing operations as directed. 24h Summary RIH with Rope spear assembly to 346'. Observed flow from drill pipe and Annulus A. Stabbed FOSV and performed a Hard shut in. Notified Company rep and started monitoring for pressures. Monitor pressures. 0 Psi observed. Strapped pits and 3 Bbls returned to cuttings tank. Consult with management and inform of current well shut-in condition. Open Choke and monitor for flow for 30 minutes. No flow. Attempt to bullhead A annulus. Caught pump pressure with 2.7 Bbls pumped. Upon reaching 500 Psi shut off pump and monitor pressure. Bleed off rate 100 Psi for 2 minutes. Repeated pressure up/bleed off 3 times with same bleed off rate. Notify management of findings. R/U circulating hose to DP and test lines to 1000 Psi. Circulate 29 Bbls clean 8.9# 3% KCL kill fluid down DP and out full open choke. 3 BPM with 290 Psi. Brine mixed with diesel circulated out of well to cuttings tank. Shut down pump and monitor well. 30 minute flow check with no flow observed. Opened Annular preventer. Well static. POOH from 346'. Pull wear ring and set test plug. Test Annular, 4" and 4.5" test joint, FOSV, Choke/Kill HCR. 250/3500 Psi, all test good. Pull Test plug and install Wear bushing. P/U 4" HWDP for fishing BHA. RIH with BHA #6 to 1,379'. Tag up. Slack off 20K on fish and 5 RPM with 5-7K Tq applied. Repeat 3 times and pull up with 5K overpull. POOH F/1,385 to surface. Recovered minimal amount of fish. RIH with Run # 7. Operation at 07.00 In the hole with burn shoe trying to recover fish. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 00:30 0.50 0.50 W.O. L 20 P Service Rig 00:30 01:00 0.50 1.00 W.O. L 4 U RIH with Rope spear assembly to 346'. Observed flow from drill pipe and Annulus A. Stabbed FOSV and performed a hard shut in. Notified Company rep and started monitoring for pressures. 01:00 02:00 1.00 2.00 W.O. L 20 U Monitor pressures. 0 Psi observed. Strapped pits and 3 Bbls returned to cuttings tank. Consult with management and inform of current well shut-in condition. 02:00 02:30 0.50 2.50 W.O. L 20 U Open choke and monitor for flow for 30 minutes. No flow. 02:30 04:00 1.50 4.00 W.O. L 20 U Attempt to bullhead A annulus. Caught pump pressure with 2.7 Bbls pumped. Upom reaching 500 Psi shut off pump and monitor pressure. Bleed off rate 100 Psi for 2 minutes. Repeated pressure up/bleed off 3 times with same bleed off rate. Notify management of findings. 04:00 05:00 1.00 5.00 W.O. L 20 P R/U circulating hose to drill pipe and test lines to 1000 Psi. (good). Circulate 29 Bbls clean 8.9# 3% KCL kill fluid down drill pipe and out full open choke at 3 BPM with 290 Psi. Brine mixed with diesel circulated out of well to cuttings tank. Shut down pump and monitor well. 05:00 05:30 0.50 5.50 W.O. L 20 P 30 minute flow check with no flow observed. Opened Annular preventer. 05:30 06:30 1.00 6.50 W.O. L 4 P POOH from 346' standing pipe into derrick. 06:30 10:00 3.50 10.00 W.O. L 20 P Consultation with management team for plan forward. Clean recovered tech wire in pipe shed before placing into dumpster for later weighing. Prepare for testing BOPE equipment used during shut in. 10:00 10:30 0.50 10.50 W.O. C 5 P Pull wear ring and set test plug. 10:30 12:00 1.50 12.00 W.O. C 12 P R/U test equipment. Flood stack with fresh water/purge lines. Test annular, with 4" test joint, FOSV, Choke/Kill HCR. 250/3500 Psi. good tests. 12:00 14:00 2.00 14.00 W.O. C 12 P R/D 4" test joint and R/U 4.5" test joint. Test annular, choke and kill HCRs and 4" FOSV. 250/3500 Psi. good test. Note: AOGCC notified of well shut in and BOP testing, witness waived by AOGCC rep Sean Sullivan for BOP testing. 14:00 14:30 0.50 14.50 W.O. C 5 P Pull Test plug and install Wear bushing. 14:30 15:30 1.00 15.50 W.O. L 20 P Load Baker fishing tools and make tally for Run #6. 15:30 20:30 5.00 20.50 W.O. L 4 P Pipe management in Derrick. P/U 4" HWDP for fishing BHA. RIH with BHA #6 to 1,379'. Tag up and slack off 20K on fish with 5 RPM with 5-7K Tq applied. Repeat 3 times and pull up with 5K overpull. 20:30 22:30 2.00 22.50 W.O. L 4 P POOH F/1,385' to surface. Lost overpull approx. 50' from top of fish @ 1,385' 22:30 00:00 1.50 24.00 W.O. L 4 P Recovered minimal amount of fish. Consulted with management and decision made to make one more effort at recovery with rope Spear. RIH with Run # 7. Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Drilling Supv. OPPdiilling@eni.com 907-685-0710 Eni representative Mark Ashley ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 3/1/2023 Report #: 8 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Clear Temperature (°F) -14.8 Wind NE @ 20 MPH Days LTI (days) 2,002.00 Days RI (days) POB 42.0 24h Forecast Slip/Cut drilling line. Continue fishing operations as directed. 24h Summary Continue run in hole from 754' to 1,379' with rope spear, Work rope spear from 1,379' to 1,384'. Pull out of hole to surface, minimal recovery of fish. Lay down rope spear and pick up Burn shoe assembly, Run #1, RIH and tag top of fish @ 1,375' and Start burning over to 1,378'. POOH with burn shoe assembly to BHA. Drain wash pipe and collect contents. Recovered 2 ea. 5 gallon buckets of debris. RIH with Burn shoe assembly run #2. Tag up @ 1,378' burn down to 1400’ pick up no over pull, POOH to intensifier and lay down, continue to pull out of hole from 450’. Total recovery of control line so far 200 lbs = approx. 1120’ of line. Operation at 07.00 Running in hole with burn shoe BHA to recover fish. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. L 4 P Continue run in hole from 754' to 1,379' with rope spear, 60K DW. 01:30 02:00 0.50 2.00 W.O. L 20 P Work rope spear from 1,379' to 1,384', 10K WOB, 3-5K TQ. 02:00 03:00 1.00 3.00 W.O. L 4 P Pull out of hole from 1,384' to surface. Minimal recovery of fish. Bottom 4 hooks on rope spear came out of the well bent in towards body of the tool. 03:00 07:00 4.00 7.00 W.O. L 4 P Lay down rope spear. Pick up Burn shoe/wash pipe assembly and RIH to 1,375'. Run #1. 07:00 09:00 2.00 9.00 W.O. L 13 P Tag top of fish @ 1,375'. Start burning over to 1,378' with 5.5 BPM with 1,750 Psi, 40 RPM @ 3-6K Tq. and 3-5K down weight on shoe. 09:00 10:30 1.50 10.50 W.O. L 4 P POOH with Burn shoe assembly from 1378' to BHA at 80 FPM. 10:30 11:30 1.00 11.50 W.O. M 1 P Safety Stand Down on Traction device awareness/Solution to avoid trips, slips, and falls. 11:30 12:00 0.50 12.00 W.O. L 20 P Drain wash pipe and collect contents. Recovered 2 ea. 5 gallon buckets of debris. Small pieces of Clamp/cable too small to separate. 12:00 14:00 2.00 14.00 W.O. L 4 P Make up and RIH with Burn shoe assembly. Run #2. Tag up @ 1,378'. Up Wt and Dn Wt = 65K 14:00 22:00 8.00 22.00 W.O. L 13 P Make up top drive and stage pump from 3 to 6 BPM. At 6 BPM 2,100 Psi, 40 RPM with 3-6K Tq, and 5K down weight on shoe. Burn F/1,378' to 1,383' and pick up to break over weight. Pick up and break over @ 1,388' ; 1,393' ; 1,398'; and 1,400'. At 1,400' attempt to make connection and lost 10 feet of hole. Burn back to 1,400'. 22:00 23:30 1.50 23.50 W.O. L 4 P POOH 2 stands with no over pull, blow down TD. Continue POOH to Intensifier and lay it down. 23:30 00:00 0.50 24.00 W.O. L 4 P Continue POOH from 450' with Burn shoe assembly. Note: Total recovery 200 lbs control line= approx. 1120' of line. Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Drilling Supv. OPPdiilling@eni.com 907-685-0710 Eni representative Mark Ashley ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 3/2/2023 Report #: 9 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Overcast Temperature (°F) -14.1 Wind NE @ 17 MPH Days LTI (days) 2,003.00 Days RI (days) POB 39.0 24h Forecast Continue burnover milling operations with modified 8.5" Burn Shoe. 24h Summary Pull out of hole with burn shoe assembly from 450' to surface, small amount of debris recovered. Slip and cut drill line. Make up new burn shoe assembly run in hole wash and ream from 1354’ to 1390’ MD. POOH recovered 5 gallons of debris. Make up modified burn shoe assembly and run in hole, tag up at 1395’ MD, pick up to 1393’ break circulation and pump bottoms up recover 3 gallons of fine cuttings from shakers. Pump 30 bbls 65 vis sweep, minimal cuttings return at shakers. Ream down from 1,395' to 1,397' and top drive stalled out. Pick up with 20K overpull and broke free. Rotate back down to 1,395' and stalled out again. Pick up with 40K overpull and broke free. POOH 2 stands F/1,395' to 1,273'. Make up stand to top drive and establish rotating and slack off parameters. Rotate at 30 RPM with 1.5K free Tq and 70K Dn Wt. Slowly slack off into the hole monitoring Tq and slack off weight looking for possible debris that would stall out top drive. Rotate down 30' without incident. Operation at 07.00 Fishing with modified burn shoe. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. L 20 P Pull out of hole from 450' to surface. Break off burn shoe and clean out wash pipe. Small amount of debris recovered. Basket fingers were missing from both finger basket. 02:30 04:30 2.00 4.50 W.O. L 25 P Slip and cut 100' of drill line. Service rig and top drive. 04:30 06:00 1.50 6.00 W.O. L 4 P Make up new 8.5" burn shoe and double finger basket. Run in hole to 1,394', set down 5K WOB. 06:00 07:00 1.00 7.00 W.O. L 13 P Pickup to 1,384' and engage rig pumps at 1.5 BPM, pressure increased to 3000 PSI, shut down mud pump. Pickup to 1,354' and establish circulation 2 BPM with 2100 PSI. Wash and ream from 1,354' to 1,390', 2 BPM, 2100 PSI, 30 RPMs. Set down 5K WOB at 1,390' and torque increased to 3K. Decision made to pull out of hole. 07:00 13:30 6.50 13.50 W.O. L 20 P Pull out of hole from 1,390' to surface. Break off burning shoe and clean out wash pipe. 5 gallon bucket of ground debris recovered and a few larger pieces of debris above finger basket. 2 of 3 jets in jet bushing plugged with debris. Clean out jet bushing. 13:30 18:30 5.00 18.50 W.O. L 20 P Make up modified 8.5" burn shoe, 1 joint 8-1/8" wash pipe, top bushing, and remaining fishing BHA 18:30 20:00 1.50 20.00 W.O. L 4 P RIH to 446' and pick up intensifier. Continue RIH to 1,365 and obtain parameters for milling (70K up&down). Continue to 1,395' and tag up. 20:00 21:30 1.50 21.50 W.O. L 7 P Pick up to 1.393' and make up top drive. Break circulation with 6 BPM @ 97 Psi. Pump BTM up. Recovered 3 gallons of very fine cuttings. Pump 30 Bbl 65 vis sweep and chase @ 6 BPM - FCP = 229 Psi. Minimal cuttings returned to the shakers. 21:30 23:00 1.50 23.00 W.O. L 13 P Obtain parameters; 70K up & down, 30 RPM W/1.5K free TQ. Pump at 6 BPW with 117-216 Psi. Ream down from 1,395' to 1,397' with 5-10K WOB; 30 RPM with 2-4K Tq. and TD stalled out. Pick up with 20K overpull and broke free. Rotate back down to 1,395' and stalled out again. Pick up with 40K overpull and broke free. POOH 2 stand F/1,395' to 1,273'. Notify management for plan forward. 23:00 00:00 1.00 24.00 W.O. L 13 P Make up stand to top drive and establish rotating and slack off parameters. Rotate at 30 RPM with 1.5K free Tq and 70K Dn Wt. Slowly slack off into the hole monitoring Tq and slack off weight looking for possible debris that would stall out top drive. Rotate down 30' without incident. Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Drilling Supv. OPPdiilling@eni.com 907-685-0710 Eni representative Mark Ashley ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 3/3/2023 Report #: 10 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Clear Temperature (°F) -24.2 Wind W @ 5 MPH Days LTI (days) 2,004.00 Days RI (days) POB 39.0 24h Forecast Continue BOPE testing. Run in hole with BHA #11 - Rope spear assembly. 24h Summary Attempt to rotate down to top of fish @1,395'. top drive stalled out. Pulled out to 1,334' before breaking over/free. Continue burning to 1,395' and stalled out again. POOH rotating and pumping. Top drive stalled out 1,394'. POOH to 1,261' to break free jarring @ 180K/110 overpull. POOH F/1,271' to surface. Post jarring derrick inspection. RIH with Rope spear and work down to 1,401'. POOH and collected 5 lbs of stainless tubing from spear. R/U and begin testing BOPE. Operation at 07.00 Pulling out of hole with rope spear. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. L 13 P Attempt to rotate down to top of fish @1,395' rotating at 40 RPM with 2-4K Tq, pumping at 7 BPM @ 245 Psi. began torquing up at 1,390' and worked down to 1,393'. top drive stalled out. Pulled up to 1,334' before breaking over/free. 01:30 03:00 1.50 3.00 W.O. L 13 P RIH to 1,365' and start rotating and pumping down to 1,394'. Continue burning to 1,395' and stalled out again. 03:00 06:00 3.00 6.00 W.O. L 13 P POOH to 1,177' dragging debris with MAX up weight of 150K /80K overpull. Once free run back in hole to1,394' and continue rotating and pumping, top drive stalled out 1,394'. POOH to 1,261' to break free jarring @ 180K/110 overpull. 06:00 07:00 1.00 7.00 W.O. L 20 P Post jarring derrick inspection. Everything looks good. 07:00 10:00 3.00 10.00 W.O. L 4 P POOH F/1,271' to surface. Overpull encountered approximately every 45' with 40-60K overpull setting off jars. This continued until 67' from surface, recovered one small piece of composite material in side first hook up from burn shoe, no hooks showed any damage. 10:00 10:30 0.50 10.50 W.O. L 20 P Post jarring derrick inspection. OK. 10:30 13:00 2.50 13.00 W.O. L 5 P PJSM and lay down BHA #9. Pick up Rope spear BHA # 10. 13:00 15:30 2.50 15.50 W.O. L 13 P RIH with Rope spear to 1,393' and tag up. 5 RPM w/1K Off BTM TQ. Set down 15K weight on spear. Top drive stalled @ 5K Tq. Pick up 10' with 20K overpull before release. Continue working rope spear to 1,401' with 15K down weight with max torque of 10K @ 5 RPM. 15:30 17:00 1.50 17.00 W.O. L 4 P POOH with Rope spear assembly. 17:00 18:00 1.00 18.00 W.O. L 5 P Lay down BHA #10 - Rope spear. Clear debris from spear. Collected 5 lbs. of stainless tubing from spear. 18:00 19:00 1.00 19.00 W.O. C 20 P Pick up BOP flushing tool and flush stack at 5 BPM. L/D flushing tool. 19:00 20:00 1.00 20.00 W.O. C 5 P PJSM and pull wear ring and set test plug. 20:00 00:00 4.00 24.00 W.O. C 12 P Rig up BOP testing equipment. Fluid pack BOP, Choke manifold, lines. Perform Shell test, good test. Perform Weekly BOPE test. Test with 4" and 4.5" test jts. 250 Psi low and 3,500 Psi high. Test witness waived by Austin McLeod, AOGCC on 3-3-23 @ 11:24 Hrs. Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Drilling Supv. OPPdiilling@eni.com 907-685-0710 Eni representative Mark Ashley ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 3/4/2023 Report #: 11 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Clear Temperature (°F) -36.5 Wind ESE @ 8 MPH Days LTI (days) 2,005.00 Days RI (days) POB 39.0 24h Forecast Continue fishing operations with Rope spear BHA with 8.5" stop ring, circulating sub. 24h Summary Continue performing BOPE test with 4" and 4-1/2" test joints 250 PSI low and 3500 PSI high. Install wear bushing with Vault representative. RIH with rope spear with 8.5" stop ring to 1,401' and work. Work rope spear from 1,392' to 1,401' multiple times. POOH and Recovered 15 LBS (85') of control line. Re-run rope spear fishing BHA and set down at 466', POOH and recovered 3# (16.8') of control line. Re-run rope spear to 1,401' and work rope spear. POOH and recovered 4# (22.4') control line. Rerun spear to 1,403' and POOH and recovered 93# (521') control line .The well bore fluid dropped out of stack and wellhead as fish was passing thru wellhead. Add 33 Bbls of 8.9# Kill fluid-well back to taking fluid. Add 10 Bbls per hour of 8.9 ppg brine going forward. Flush Stack and re-install wear ring. Operation at 07.00 Running in hole with rope spear. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:00 3.00 3.00 W.O. C 12 P Continue performing BOPE test with 4" and 4-1/2" test joints to AOGCC test requirements, 250 PSI low and 3500 PSI high. Held each test for 5 minutes and charted. No failures. Perform accumulator drawdown test, 2950 PSI initial pressure, 2000 PSI after function, 22 seconds to build 200 PSI, 74 seconds to full recovery. 4 N2 bottles with 2787 average PSI. Witness waived by AOGCC representative Austin McLeod. 03:00 04:00 1.00 4.00 W.O. C 20 P Blow down choke and kill lines. Rig down BOPE test equipment. Install wear bushing with Vault representative. 04:00 05:30 1.50 5.50 W.O. L 4 P Make up rope spear with 8.5" stop ring, circulating sub, and remaining fishing BHA. Run in hole with same to 1,392'. 05:30 07:00 1.50 7.00 W.O. L 13 P Engage fish from 1,392' to 1,401', 76K UW/DW, 15 RPM, 1.6 TQ. Rotated spear until top drive stalled at 4K TQ. Pick up 5K over pull. Work rope spear from 1,392' to 1,401' multiple times. 07:00 09:30 2.50 9.50 W.O. L 4 P Pull out of hole from 1,401' to surface. Clean control line from rope spear. Recovered 15 LBS (~85') of control line. 09:30 10:00 0.50 10.00 W.O. L 20 P Service rig and top drive. 10:00 12:00 2.00 12.00 W.O. L 13 P Re-run rope spear fishing BHA to 94'. Set down at 94' and rotate 3 turns. Pull out of hole and recovered 1' piece of control line. Run in hole and set down at 97' and rotated 6 turns. Pull out of hole with no recovery. 12:00 13:30 1.50 13.50 W.O. L 13 P Re-run rope spear fishing BHA to 466'. Set down at 466' and rotate 5 turns. Pull out of hole and 3 LBS (~16.8') of control line. 13:30 16:00 2.50 16.00 W.O. L 13 P Re-run rope spear fishing BHA to 1,395'. Work rope spear down from 1,395' to 1,401' with 10K WOB and rotate 1.75 turns, 4K TQ. Pick up and had 12K overpull. Pick up until overpull fell off to normal 75K UW. 16:00 18:00 2.00 18.00 W.O. L 4 P Pull out of hole from 1,401' to surface. Clean control line from rope spear. Recovered 4 LBS (22.4') of control line. 18:00 20:30 2.50 20.50 W.O. L 13 P RIH with Rope Spear to 1,397'. With 15K down weight, rotate down to 1,403'. Make 3 turns to right and hold 4K Tq. Pick up with 10K overpull. At this point the well bore fluid dropped out of stack and wellhead. Add 33 Bbls of 8.9# 3% KCL and the fluid level can not be seen. We have lost the fish plugging the 9 5/8" casing and now well is back to taking fluid, start adding 10 Bbls of 8.9# kill fluid per hour. 20:30 22:00 1.50 22.00 W.O. L 4 P POOH F/1,403' slowly maintain 8-10K overpull to surface. While pulling the last stand out of the hole swabbing was observed. Continue up slowly and when fish reached the wellhead the wear ring began rising also. Fluid level dropped out of sight. Continue POOH with wear ring and fish. 22:00 23:00 1.00 23.00 W.O. L 20 P Cut off and collect the cable and clamp pieces from rope spear. 93 pounds collected equaling 521'. Remove wear ring from spear. 23:00 00:00 1.00 24.00 W.O. L 20 P Flush Stack and re-install wear ring. Total control cable recovered today is 115 Lbs equaling 644'. Total recovered since fishing operations began is 315 Lbs equaling 1,764'. Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Drilling Supv. OPPdiilling@eni.com 907-685-0710 Eni representative Mark Ashley ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 3/5/2023 Report #: 12 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Overcast Temperature (°F) -11.2 Wind E @ 25 MPH Days LTI (days) 2,006.00 Days RI (days) POB 39.0 24h Forecast Continue fishing operations as directed. 24h Summary Run #13, run in hole with rope spear fishing BHA to 1,406'. Work rope spear. POOH from 1,406' to surface with 20K-50K drag. Recovered 133 LBS (744.8') of smaller pieces. Run #14, run in hole with rope spear fishing BHA to 1,413'. Work rope spear. POOH from 1,418' to surface with 8K-12K drag. Recovered substantial amount of control line and composite pieces of clamp. Run #15, run in hole with rope spear fishing BHA to 2,129' plus singles from pipe shed. POOH 12 stands of 4" drill pipe to reposition 4" HWDP in string. RIH with BHA #16 Rope Spear to 3,547'. Singling into hole from pipeshed. Fill wellbore with 10 BBLs of 8.9 PPG brine with 3% KCL every hour. Operation at 07.00 Making up BHA #17. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. L 13 P Run BHA #13, run in hole with rope spear fishing BHA to 1,406'. Work rope spear at 1,406' with 15K WOB and rotate 3/4 turn to left, pick up with 12K overpull. Set back down to 15K WOB and rotate 3 turns to right with 4K TQ. Pick up and had 18K overpull. Pick up until overpull fell off to normal 75K UW. Fill wellbore with 10 BBLs of 8.9 PPG brine with 3% KCL every hour. 02:30 04:30 2.00 4.50 W.O. L 4 P Pull out of hole from 1,406' to surface with 20K-50K drag. Fill wellbore with 10 BBLs of 8.9 PPG brine with 3% KCL every hour. 04:30 06:00 1.50 6.00 W.O. L 20 P Clean off rope spear. Recovered substantial amount of control line and composite pieces of clamp. Recovered 133 LBS (744.8') of smaller pieces. Placed larger pieces in dumpster to be weighed later at end of day. Fill wellbore with 10 BBLs of 8.9 PPG brine with 3% KCL every hour. 06:00 06:30 0.50 6.50 W.O. L 5 P Install wear bushing with Vault representative. 06:30 09:00 2.50 9.00 W.O. L 13 P Run #14, run in hole with rope spear fishing BHA to 1,413'. Work rope spear from 1,413' to 1,418' with 15K WOB and rotate 3/4 turn to left, pick up with 10K overpull. Set back down to 15K WOB and rotate 1 turn to right with 4K TQ. Pick up and had 13K overpull. Pick up until overpull fell off to normal 75K UW. Fill wellbore with 10 BBLs of 8.9 PPG brine with 3% KCL every hour. 09:00 11:00 2.00 11.00 W.O. L 4 P Pull out of hole from 1,418' to surface with 8K-12K drag. Fill wellbore with 10 BBLs of 8.9 PPG brine with 3% KCL every hour. 11:00 12:30 1.50 12.50 W.O. L 20 P Clean off rope spear. Recovered substantial amount of control line and composite pieces of clamp. Placed in dumpster to be weighed later at end of day. Fill wellbore with 10 BBLs of 8.9 PPG brine with 3% KCL every hour. 12:30 13:00 0.50 13.00 W.O. L 4 P Install wear bushing with Vault representative. 13:00 16:00 3.00 16.00 W.O. L 4 P Run #15, run in hole with rope spear fishing BHA to 1,938'. Fill wellbore with 10 BBLs of 8.9 PPG brine with 3% KCL every hour. 16:00 17:00 1.00 17.00 W.O. L 4 P Run in hole with rope spear BHA from 1,938' to 2,129' picking up singles from pipe shed. Fill wellbore with 10 BBLs of 8.9 PPG brine with 3% KCL every hour. 17:00 18:30 1.50 18.50 W.O. L 4 P Pull out of hole to reposition 4" HWDP in string. Fill wellbore with 10 BBLs of 8.9 PPG brine with 3% KCL every hour. 18:30 19:30 1.00 19.50 W.O. L 20 P Pulled BHA above rotary table with BHA #15 inspect spear no recovery. Fill wellbore with 10 BBLs of 8.9 PPG brine with 3% KCL every hour. 19:30 20:00 0.50 20.00 W.O. L 25 P Service rig and Grease Crown and Blocks. Fill wellbore with 10 BBLs of 8.9 PPG brine with 3% KCL every hour. 20:00 21:30 1.50 21.50 W.O. L 4 P RIH with BHA #16 rope spear assembly to 2,129'. Up Wt = 80K and Dn Wt = 80K. Fill wellbore with 10 BBLs of 8.9 PPG brine with 3% KCL every hour. 21:30 00:00 2.50 24.00 W.O. L 4 P Continue running into the hole F/2,129' to 3,547' picking up 4" XT-39 Drill Pipe single joints from pipeshed. Up Wt=90K and Dn Wt=90K. Fill wellbore with 10 BBLs of 8.9 PPG brine with 3% KCL every hour. Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Drilling Supv. OPPdiilling@eni.com 907-685-0710 Eni representative Mark Ashley ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 3/6/2023 Report #: 13 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Overcast Temperature (°F) 8.8 Wind E @ 32 MPH Days LTI (days) 2,007.00 Days RI (days) POB 39.0 24h Forecast Replace air boots and RIH with Burn shoe/wash pipe Run #2. Verify well staying full and pump drill pipe volume at least every 5 stand to ensure pipe not plugging up. 24h Summary Run #16 rope spear picking up singles from pipe shed from 3,547' to 4,235'. Work rope with 5K WOB and rotate 4 turns to right. Pull out of hole from 4,230' to 37'. Pumped 30 BBLs of 8.9 PPG brine with 3% KCL down drill pipe at 2,508'. Lay down rope spear BHA. Run #17. Pick up 8.125" modified burn shoe, 2 joints 8.125" wash pipe RIH to 4,239' and set down 8K WOB. Pick up and Dry rotate down to 4,249'. Pick up no rotation to 4,430' with no overpull and slack off to 4,265' no weight decrease. POOH and break off burn shoe and check wash pipe for recovery of fish. Wash pipe empty. Make up Burn shoe and wash pipe and RIH with Run # 2 to 286' while drifting 1st 2 stands of drill pipe. RIH fluid began over flowing the drill pipe as it was being lowered into the hole. Rig up 2" circulating hose to head pin to circulate drill pipe volume. Observed that the flow nipple air boots were not holding and leaking. Pumping shut down. Immediately dispatched rig crew members to BOP enclosure and well bay to assess and stop fluid from escaping the BOP enclosure. Monitoring well for flow while responding to spill. Slight fluid level drop while monitoring. Notifications made for spill. Cleanup initiated. POOH with assembly to replace boots. Operation at 07.00 Running in hole with burn shoe filling pipe every 500'. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 W.O. L 4 P Continue run in hole with Run #16 rope spear picking up singles from pipe shed from 3,547' to 4,235'. Work rope with 5K WOB and rotate 4 turns to right. Pick up 5' and had no overpull. Fill wellbore with 10 BBLs of 8.9 PPG brine with 3% KCL every hour. 02:30 06:00 3.50 6.00 W.O. L 4 P Pull out of hole from 4,230' to 37'. Pumped 30 BBLs of 8.9 PPG brine with 3% KCL down drill pipe at 2,508' with 2 BPM, 200 PSI. Fill wellbore with 10 BBLs of 8.9 PPG brine with 3% KCL every hour. 06:00 07:00 1.00 7.00 W.O. L 20 P Lay down rope spear BHA. Clean and organize rig floor. Fill wellbore with 10 BBLs of 8.9 PPG brine with 3% KCL every hour. 07:00 07:30 0.50 7.50 W.O. L 20 P Service rig and top drive. 07:30 12:00 4.50 12.00 W.O. L 4 P Run #17. Pick up 8.125" modified burn shoe, 2 joints 8.125" wash pipe, top sub, pump out sub, pup joint, LBS (lubricated bumper sub), oil jars, X/O. Total length 102'. Run in hole from 102' to 4,239'. Fill wellbore with 10 BBLs of 8.9 PPG brine with 3% KCL every hour. 12:00 13:30 1.50 13.50 W.O. L 13 P At 4,239', set down 8K WOB. Pickup and obtain parameters, 100K UW, 90K DW, 95K ROT, 10-15 RPM, 3-3.5K TQ. Dry rotate from 4,239' to 4,249', 1' above 4-1/2" tubing stump at 4,250'. Pickup with no overpull without rotation to 4,4230'. Slack off to 4,265' without rotation with no weight decrease. Pickup to 4,230' and come back down to 4,265' without rotation with no overpull or set down. 13:30 17:30 4.00 17.50 W.O. L 4 P Pull out of the hole F/4,265' to Baker fishing assembly. 17:30 20:00 2.50 20.00 W.O. L 5 P Break off burn shoe and check wash pipe for recovery of fish. Wash pipe empty. Observed debris inside top of jars and cross over to jar. Remove debris from jar and X/O. Bend burn shoe diamonds inward 1/4" from current positions . 20:00 21:00 1.00 21.00 W.O. L 9 P Make up Burn shoe and wash pipe and RIH with BHA #17, Run # 2 to 286' . Drifting 1st and 2nd stands of drill pipe. While RIH fluid began over flowing the drill pipe as it was being lowered into the hole with brine/diesel mixture, fluid level in annulus was observed to be at the annular level in stack. 21:00 21:30 0.50 21.50 W.O. L 9 P Rig up 2" circulating hose to head pin to circulate drill pipe volume to clear diesel and to displace the diesel on top of annulus. Shortly after pumping began it was observed that the flow nipple air boots were not holding and leaking. Pumping shut down. 21:30 00:00 2.50 24.00 W.O. L 20 U Immediately dispatched rig crew members to BOP enclosure and well bay to assess and stop fluid from escaping the BOP enclosure. Monitoring well for flow while responding to spill. Fluid level has a gradual loss rate at present. Notification given to the required individuals for the spill. Clean up discharged fluid. Rig down 2" circulating hose. Rack back the 2 Stands of DP, L/D Jars and stand back burn shoe/wash pipe. Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Drilling Supv. OPPdiilling@eni.com 907-685-0710 Eni representative Mark Ashley ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 3/7/2023 Report #: 14 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Partly Cloudy Temperature (°F) 16.7 Wind E @ 9 MPH Days LTI (days) 2,008.00 Days RI (days) POB 42.0 24h Forecast POOH with burn shoe assembly # 17 run #2 and lay down. Make up and run in the hole with overshot and reverse circulating basket with finger catcher. 24h Summary Clean out flow box. Pull flow riser and change out air boot. Make up 8-1/8" burn shoe and wash pipe BHA #17; RUN #2 to 4,210' circulating bottoms up every 500'. Work burn shoe assembly multiple times from 4,210' to 4,265' without and with pipe rotation. Rotate @ 28 RPM with 3.2K free TQ, 8 BPM with 450Psi. From 4,210' to 4,290'. Work multiple times. Pump 30 Bbls 65 Vis sweep around. Minimal debris recovered. Rotate and reciprocate from 4,255' to 4,292' with 60 RPM at 5-8K Tq. Pumping at 10 BPM with 675 Psi. Pump 65 Vis sweep at 4,292'. Circulate sweep out of hole. Operation at 07.00 Running in the hole with overshot and reverse circulating basket with finger catcher. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. L 20 P Clean out flow box. Pull flow riser and change out air boot. Fill BOP with water and test flow riser for leaks, all good. 02:00 03:00 1.00 3.00 W.O. L 20 P Make up 8-1/8" burn shoe and wash pipe BHA #17; RUN #2. 03:00 09:30 6.50 9.50 W.O. L 4 P Run in hole with 8.125" modified burn shoe and wash pipe to 4,210' circulating bottoms up every 500'. Reduced RIH speed to keep fluid for overflowing drill pipe. 09:30 15:00 5.50 15.00 W.O. L 13 P Circulate bottoms up at 4,210', 7.5 BPM, 470 PSI, 124 FPM annular velocity. Wash down to 4,240' and circulate bottoms up. We had ~5 gallons of small ground composite material come back on bottoms up. Wash down to 4,265' without any increase in slack off weight. Circulate bottoms up at 4,265'. We had minimal small ground up composite material come back on bottoms up. Pick up to 4,178' and came back down and set down 10K at 4,240'. Engage rotation at 15 RPM, after 1-2 turns weight fell off. Stopped rotation and washed down to 4,265' without taking weight. Circulate 30 BBLs of 65 vis sweep around with no cuttings when came back to surface. Pickup to 4,178' and slack off without pumps or rotation and set down at 4,240'. Engage rotation and weight fell off. Slack off to 4,265' and circulate 30 BBLs of 65 vis sweep around at 10 BPM with 660 PSI, 173 FPM annular velocity. No cuttings came back with sweep to surface. 15:00 19:00 4.00 19.00 W.O. L 13 P Continue working over TBG stump @ 4,240'. P/U to 4,210' and slack off without rotation and made pass TBG stump to 4,265' 4 out of 5 attempts. Rotate @ 28 RPM with 3.2K free TQ, 8 BPM with 450Psi. From 4,210' to 4,290'. Work multiple times. Pump 30 Bbl 65 Vis sweep around. Minimal debris recovered. 19:00 21:00 2.00 21.00 W.O. L 13 P Continue working over TBG stump @ 4,240'. P/U to 4,210' and slack off without rotation and made pass the TBG stump. Bring on rotation at 40/60 RPM, 4-6K Tq, and rotate down to 4,290' at 9.5 BPM with 645 Psi. Pump 30 Bbl 65 Vis sweep. Keep working burn shoe assembly as sweep migrates up hole. Minimal returned debris. 21:00 22:00 1.00 22.00 W.O. L 13 P Rotate and reciprocate from 4,255' to 4,292' with 60 RPM at 5-8K Tq. Pumping at 10 BPM with 675 Psi. Pump 65 Vis sweep at 4,292'. Circulate sweep out of hole. 22:00 00:00 2.00 24.00 W.O. L 13 P Continue working Burn shoe/wash pipe assembly from 4,292' to 4,255'. 60 RPM with 5-8K Tq. Pumping with 10 BPM at 645 Psi. Pump another 65 Vis sweep of 30 Bbls. Position Contact Name Company Title Email Office Mobile Eni representative Stefano Pierfelici Eni Manager Stefano.Pierfelici@eni.com 907-685-0710 Eni representative Nelson Carbalo Eni Superintendent Nelson.Carbarlo@eni.com 907-685-0710 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. OPPdiilling@eni.com 907-685-0710 Eni representative David Smith ASRC Energy Services Co. Man David.Smith@external.eni.com 907-685-0710 Eni representative Mark Ashley ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 3/8/2023 Report #: 15 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Overcast Temperature (°F) 17.8 Wind WSW @ 10 MPH Days LTI (days) 2,009.00 Days RI (days) POB 41.0 24h Forecast Continue organizing fishing components in pipe shed. Load 2-7/8" clean out BHA and tubing into pipe shed. Strap and caliper same. M/U and run in hole Vacs clean out assembly. 24h Summary Circulate surface to surface. Rotate and reciprocate drill string F/4,292 to 4,275'. POOH F/4'292' to fishing assembly. Lay down BHA. Make up BHA # 18, run #1. Chevron burn shoe, Reversing junk basket with catcher in-between the 2 joints of wash pipe. RIH to 4,219' and Break circulation @ 4,219'. Drop ball and get working parameters; Work assembly down from 4,219' to 4,275'. Pump 30 Bbl 65 Vis sweep. and chase with 5.5 BPM with 1,875 Psi. PJSM and remove ESP and Control line sheaves from derrick. POOH with BHA. Remove BHA components from rig floor. Operation at 07.00 Running in hole with Vacs clean out assembly. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 W.O. L 7 P Circulate surface to surface at 10 BPM with 594 Psi. Rotate and reciprocate drill string with 60 RPM and 4-5K TQ. Pick up Wt=98K and down Wt=85K. 01:00 04:00 3.00 4.00 W.O. L 4 P POOH F/4'292' to fishing assembly. Filling hole from trip tank. 04:00 08:30 4.50 8.50 W.O. L 5 P Lay down jars and pull up to inspect Chevron shoe and wash pipe. Make up BHA #18, Run #1. Chevron burn shoe, reversing junk basket with catcher in-between the 2 joints of wash pipe. 08:30 12:00 3.50 12.00 W.O. L 4 P Run in hole to 4,219' @ 40' per minute due to pipe U-tubing. 12:00 14:00 2.00 14.00 W.O. L 13 P Break circulation @ 4,219'. Drop ball and get working parameters; Rotating up weight=98K, rotating down weight=92K. Rotate at 10 RPM with 3.5K free rotating weight. Pump at 5.5 BPM with 1,810 Psi. Work assembly down from 4,219' to 4,275'. 14:00 16:00 2.00 16.00 W.O. L 7 P At 4,275' Pump 30 Bbl 65 Vis sweep at 3 BPM with 605 Psi. Chase with 5.5 BPM with 1,875 Psi. Rotate and reciprocate drill string from 4,275' to 4,219'. After sweep was out of hole pumped another bottoms up. 16:00 17:30 1.50 17.50 W.O. L 20 P PJSM and remove ESP and control line sheaves from derrick. Blow down top drive and circulating lines. 17:30 20:30 3.00 20.50 W.O. L 4 P POOH with BHA #18, Run #1 from 4,275 to BHA. 20:30 23:30 3.00 23.50 W.O. L 20 P Lay down BHA #18. Break and lay down bumper, jars, wash pipe and burn shoe. Recovered small amount of cable clamp pieces. 23:30 00:00 0.50 24.00 W.O. L 20 P Remove BHA components from rig floor. Straighten/organize various fishing components on the floor in pipe shed to prevent possible tripping hazards. Position Contact Name Company Title Email Office Mobile Eni representative Stefano Pierfelici Eni Manager Stefano.Pierfelici@eni.com 907-685-0710 Eni representative Nelson Carbalo Eni Superintendent Nelson.Carbarlo@eni.com 907-685-0710 Eni representative David Smith ASRC Energy Services Co. Man David.Smith@external.eni.com 907-685-0710 Eni representative Mark Ashley ASRC Energy Services Co. Man OPPdiilling@eni.com 907-685-0710 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 3/9/2023 Report #: 16 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Clear Temperature (°F) -10.5 Wind WSW @ 16 MPH Days LTI (days) 2,010.00 Days RI (days) POB 38.0 24h Forecast Make up Baker BHA #13 and run in hole and enter into the 4.5" tubing at 4238'. Wash and ream down with a minimum of 1600 psi for cleaning. Tag up on the XN nipple at 4321' and work Vacs up and down. Pull out of hole and clean out Vacs assembly. 24h Summary Remove Baker fishing tools from rig and organize Baker Vacs tool assembly. Make up Baker Vacs tool assembly and run in hole to 2850'. Pull out of hole and add LBS (lubricated bumper sub), XO's and oil jars. Run in hole to 4211' and begin circulation and obtain parameters for wash and ream. Tag stump at 4238' and fill at 4276'. Increase pump rate from 3 bpm to 7.5 bpm with 1918 psi. Tag up with 8k at 4299', bottom of XO. Pull out of hole and break down Vacs tool. Minimal debris in Vacs except brine. The 2 7/8" PH6 was plugged with pieces of clamps, stainless cap line and fines. Make up 3 joints of 2 7/8" PH6 for BHA #13. Operation at 07.00 Performing 2-7/8" Vacs clean out inside 4-1/2" tubing. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 04:30 4.50 4.50 W.O. L 20 P PJSM Remove all Baker fishing tools from pipe shed and rig floor. Organize Baker cleanout tools. Pick up 2-7/8" mule shoe and 2 joints of 2-7/8" PH6. Bring Doyon casing pallet of equipment to rig floor for die change. Strap and tally BHA #12, cleanout run. Rig up Doyon power tongs. Install 2-7/8" elevators. 04:30 05:30 1.00 5.50 W.O. L 5 P PJSM Make up BHA #12; 2-7/8" mule shoe, 2 joints of 2 7/8" PH6 and Vacs tool assembly. PJSM Rig down Doyon equipment and change out elevators. 05:30 07:00 1.50 7.00 W.O. L 4 P PJSM Run in hole with Vacs tool to 2850' at 90 fpm due to U-tubing. Record displacements. 07:00 11:00 4.00 11.00 W.O. L 4 P PJSM Pull out of hole from 2850' to 102'. Had BHA change. Gather XO's and make new BHA tally. Pick up jars, bumper sub and XO's. BHA #12; 2-7/8" mule shoe, 2 joints of 2-7/8" PH6, XO, Vacs tool, 3-1/2" pup, XO, pump out circ sub, 5" drill pipe pup, 6-1/4" LBS (lubricated bumper sub), 6 1/4" Oil Jars, XO, 15 stands of 4" drill pipe, 31 joints of 4" HWDP. Total length of 2511.68'. 11:00 15:00 4.00 15.00 W.O. L 4 P PJSM Run in hole to 4211' PUW 90k, SOW 90k. Monitor displacement. 15:00 17:30 2.50 17.50 W.O. L 4 P PJSM Break circulation at 4211', 3 bpm, 615 psi. Get parameters at 15 rpm, 3.8k TQ, Rotsow 93k, Rotpuw 94k. Tag stump at 4238'. Wash down and tag fill at 4276'. Pump at 4.4 bpm, 700 psi, 14 rpm, 4.2k TQ. Increase to 5 bpm, 870 psi, and wash down to 4299'. Tag down with 8k at 4299'. Increase pump to 7.5 bpm, 1918 psi for 10 minutes. 17:30 20:00 2.50 20.00 W.O. L 4 P PJSM Pull out of hole from 4299' to 4211' racking back drill pipe. Blow down top drive and surface lines. Loading 4.5" tubing to pipe shed and process. Continue pull out of hole with Vacs tool assembly from 4211' to 63', PUW 102k, SOW 90k. 20:00 23:30 3.50 23.50 W.O. L 5 P PJSM Rig up Doyon power tongs. Lay down cleanout assembly BHA #12. Minimal debris in vac tool, but filled with fluid. 2-7/8" was clogged with and packed off with pieces of clamps, stainless cap line and fine sand/ rust. 23:30 00:00 0.50 24.00 W.O. L 5 P PJSM Making up BHA #13 with 3 joints of 2-7/8" PH6 and mule shoe. Position Contact Name Company Title Email Office Mobile Eni representative David Smith ASRC Energy Services Co. Man David.Smith@external.eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Tool Push Kyle Karsten Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Tool Push Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 3/10/2023 Report #: 17 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Clear Temperature (°F) -13.5 Wind E @ 23 MPH Days LTI (days) 2,011.00 Days RI (days) POB 38.0 24h Forecast Run in hole and sting into nipple reducer at 4309'. Pull out of hole and lay down nipple reducer and BHA #14. Plan forward will be discussed. BOPE testing to be done. 24h Summary Make up BHA #13 run #2 with Vacs tool assembly and run in hole to 4328'. Circulate and enter stump at 4328'. Perform cleanout from 4240' to 4309' at 8 bpm 2150 psi, 30 rpm, 5-7k TQ. Lost partial returns during cleanout. Pull out of hole and break down Vacs tool and 2 7/8" and no debris seen. Mule shoe was damaged with end swedged inward. MJobilize next BHA. Breakout XO's from BHA #13. Make up BHA #14 with GS spear and 3.13" G-force jars. Run in hole to 1582'. Operation at 07.00 Rigging up to test BOPs. 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 5 P PJSM Make up 2-7/8" PH6/ Vacs tool with Doyon. Rig down Doyon power tongs. Make up Baker LBS (lubricated bumper sub) and oil jars. 01:00 03:00 2.00 3.00 W.O. M 4 P PJSM Run in hole to 4328' MD. 03:00 04:30 1.50 4.50 W.O. M 19 P PJSM Circulate bottoms up at 7.5 bpm, 1600 psi. Tag stump at 4328' and rotated 1/2 turn and entered 4.5" stump. Continue to circulate bottoms up at 4240'. 04:30 10:00 5.50 10.00 W.O. M 7 P PJSM Perform cleanout from 4240' to 4309' at 8 bpm, 2150 psi, 30 rpm, 5-7k TQ. Lost partial returns during cleanout. 10:00 12:00 2.00 12.00 W.O. M 4 P PJSM Pull out of hole from 4309' to BHA. Hole fill taking double displacement. 12:00 14:00 2.00 14.00 W.O. M 5 P PJSM Break down and lay down BHA #13 run #2. Rig up power tongs and break down Vacs tool and 2-7/8" PH6. No debris seen. Inspected mule shoe and had damaged end that was out of gauge. Hole taking 18 bph. 14:00 16:30 2.50 16.50 W.O. M 20 P Discuss plan forward, Constant hole fill with trip tank. Take mule to shop for modifications. Load 2-7/8" PH6 to pipe shed and process. 16:30 21:00 4.50 21.00 W.O. M 5 P PJSM Offload 4.5" work string from pipe shed. Organize and secure Baker tools, test joints and 4" drill pipe. Mobilizing next BHA assembly from DeadHorse. Pick up and breakout XO's from BHA #13. Lay down same. 10 bph hole fill. General housekeeping and organizing rig floor and BOPE enclosure. Load BHA #14 into pipe shed. 21:00 22:30 1.50 22.50 W.O. M 4 P PJSM Make up BHA #14 as per Baker, (4" GS spear, 3.13" G-force jars, XO, XO, 3 joints of 2 7/8" PH6, XO, XO, 15 stands of 4" drill pipe, 31 joints of 4" HWDP). Total length 2482.97'. Rig down Doyon power tongs. 22:30 00:00 1.50 24.00 W.O. M 4 P PJSA-Run in hole W/ GS retrieval tool & jars. F/101'--T/1582' DNWT. 60K Position Contact Name Company Title Email Office Mobile Eni representative David Smith ASRC Energy Services Co. Man David.Smith@external.eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 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 Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 3/11/2023 Report #: 18 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Partly Cloudy Temperature (°F) 6.1 Wind WNW @ 10 MPH Days LTI (days) 2,012.00 Days RI (days) POB 37.0 24h Forecast Complete run in hole with casing scraper run to 4218' ( 20' above stump). Pull out of hole and lay down BHA #14. Make up BHA #15. Test packer. Run in hole and set test packer at 4218' and test 9 5/8" casing to 2000 psi for 30 charted minutes. Unseat test packer and pull of hole and lay down. 24h Summary Run in hole with GS retrieval assembly and enter stump at 4238'. Tag nipple reducer at 4311' and latch in. Pull out of hole and recovered just the collar from the nipple reducer. Perform BOPE testing as per AOGCC specs. Witnessed waived by Kam St. John. Perform injectivity test at 6 bpm, 760 psi for 30 minutes with 8.9 ppg brine (180 bbls). Bleed off was at 8 minutes and 10 seconds. Make up Baker BHA #14, casing scraper run. Run in hole to 2817'. Operation at 07.00 Pulling out of hole with casing scraper. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 W.O. M 4 P PJSM Service handling equipment and iron roughneck for run in hole. Run in hole with GS retrieval tool and oil jars from 1582' to 4200'. 02:00 02:30 0.50 2.50 W.O. M 19 P PJSM Make up top drive and enter stump at 4238'. Tag nipple reducer at 4311' and set down 11k. Got indication of tool snap in. PUW 95k, SOW 81k. 02:30 05:00 2.50 5.00 W.O. M 4 P PJSM Pull out of hole from 4311' to 102'. 05:00 06:30 1.50 6.50 W.O. M 5 P PJSM Lay down Baker fishing assembly. GS latched into nipple reducer and brought out only the latch collar. Clean and organize rig floor and pipe shed. Prep for BOPE testing. 06:30 07:00 0.50 7.00 W.O. C 5 P Vault pulled wear bushing and set test plug with 4.5" test joint.Vault pulled wear bushing and set test plug with 4.5" test joint. 07:00 08:30 1.50 8.50 W.O. C 1 P Set up for testing, fluid pack system and call security for all call high pressure testing of lines. 08:30 15:30 7.00 15.50 W.O. C 12 P PJSM Test BOPE as per AOGCC specs to 250/ 3500 psi with 4.5" and 4" test joints. Gas alarms and PVT tests completed. Witness waived by Kam St. John. All tests good. 15:30 16:30 1.00 16.50 W.O. C 5 P PJSM Vault pulled test plug and installed wear bushing. Run in lock down screws. 16:30 18:00 1.50 18.00 W.O. M 9 P PJSM Perform injectivity test at 6 bpm, 760 psi with 180 bbls of 8.9 ppg brine for 30 minutes. Good test. Shut down pumping and bleed to 0 in 8 minutes and 10 seconds. 18:00 20:00 2.00 20.00 W.O. M 20 P PJSM Clean and organize mud manifold room. Bring brine to pits. Break out Vacs tool assembly. 20:00 21:30 1.50 21.50 W.O. M 5 P PJSM Make up Baker BHA #14,(Bull nose, String mill, Razor back, 2-Magnets, LBS, Oil jars, XO, 15 stands of 4" DP, 31 joints HWDP) Total length 2439.72'. 21:30 00:00 2.50 24.00 W.O. M 4 P PJSM Run in hole from 60' to 2817' at 60fpm. SOW 70k. Position Contact Name Company Title Email Office Mobile Eni representative David Smith ASRC Energy Services Co. Man David.Smith@external.eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 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 Richard Twedt Nordic Toolpusher rigmanager.rig4@nordic-calista.com 907-685-1470 Safety Representative Jim Beverage Nordic HSE Jim.beverage@nordic-calista.com 907-685-8603 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 3/12/2023 Report #: 19 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Clear Temperature (°F) -25.0 Wind SW @ 10 MPH Days LTI (days) 2,013.00 Days RI (days) POB 38.0 24h Forecast Complete make up of BHA #17 and run in hole to 4.5" stump at 4238'. Dress stump as per plan. Pull out of hole laying down 4" drill pipe. Lay down BHA #17. Load 4.5" tubing in pipe shed and process. Bring in completion equipment and organize for completion run. 24h Summary Run in hole with BHA #15, casing scraper/magnets, and scrape from 4150' to 4218'. Pull out of hole and make up BHA #16, Baker test packer. Run in hole and set test packer at 4210' center of element. Perform 9 5/8" casing test to 2000 psi for 45 minutes, good test. Pull out of hole and lay down test packer assembly. Making up BHA #17 with 8.5" dress off mill/magnets. Operation at 07.00 Pulling out of hole laying down drill pipe. 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 25 P PJSM Inspect equipment. Change out tong dies and grease iron roughneck. 00:30 01:30 1.00 1.50 W.O. M 4 P PJSM Run in hole with cleanout BHA #15 from 2817' to 4045' at 60 fpm. 01:30 05:00 3.50 5.00 W.O. M 19 P PJSM Scrape from 4045' to 4218' at 6 bpm, 375 psi, 15 rpm, 3/4TQ, PUW 101k, SOW 88k. ROTW 93k. Got returns at 75 strokes with diesel. Sent fluid to cuttings box, 115 bbls. Changed screens to 180 mesh. Work last stand 3 times up and down. Load Baker test packer to pipe shed. Day light saving; 1 hour forward. 05:00 08:00 3.00 8.00 W.O. M 4 P PJSM Blow down top drive. Pull out of hole from 4218' to jars. Fill hole with 10 bph and displacement. 08:00 09:30 1.50 9.50 W.O. M 20 P PJSM Lay down BHA #15 scraper assembly and clean magnets, minimal metal on magnets. 09:30 10:30 1.00 10.50 W.O. M 12 P PJSM Organize Baker tools in pipe shed. Strap 4" drill pipe pup and test packer and make running tally. Good test. Make up BHA #16 Baker test packer assembly, (Bull nose, BTM T/COE Packer, XO, 4" pup jt, 15 stands of 4" DP, 31 joints of 4" HWDP. 10:30 14:30 4.00 14.50 W.O. M 4 P PJSM Run in hole with test pack at 60 fpm to 4201'. Loading 4.5" tubing to pipe shed. 14:30 16:00 1.50 16.00 W.O. M 5 P PJSM Make up 4" drill pipe pups to set packer on depth. Make up top drive and space out for setting depth. Pick up to neutral weight, rotate 2 turns to the left and set down with 29k. Packer set at 4210' center of element. 16:00 18:00 2.00 18.00 W.O. M 12 P PJSM Fluid pack Annulus A and choke manifold. Perform casing test on 9 5/8" staging up 500 psi increments to 2000 psi. for 45 min. charted, good. 18:00 22:00 4.00 22.00 W.O. M 4 P PJSM Release test packer as per plan. Break out and lay down 4" pup joints. Pull out of hole with test packer from 4218', PUW 95k, to 64'. 22:00 23:00 1.00 23.00 W.O. M 5 P PJSM Lay down BHA #16 test packer assembly. Move and set up Baker tools for BHA #17. 23:00 00:00 1.00 24.00 W.O. M 5 P PJSM Making up BHA #17, 8.5" dress off mill assembly as per plan. Position Contact Name Company Title Email Office Mobile Eni representative David Smith ASRC Energy Services Co. Man David.Smith@external.eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 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 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 3/13/2023 Report #: 20 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Overcast Temperature (°F) -19.8 Wind SW @ 14 MPH Days LTI (days) 2,014.00 Days RI (days) POB 38.0 24h Forecast Bring in and process 4.5" completion tubing and pup joints. Bring Schlumberger, Halliburton and Baker tools to pipe shed and organize. Complete Completion running order tally sheet. 24h Summary Make up Baker BHA #17 and run in hole to top of stump at 4238'. Pick up and break circulation. Set parameter and set down on stump with 3k with 3 bpm, 115 psi, 50 rpm, 4/6k TQ. Dress off stump from 4238' to 4244'. Pick up with no rotation and set down twice with 5k and seen 35 psi pressure increase both times. Pull out of hole laying down 4" drill pipe to 68' and lay down BHA #17. Held lift meeting and craned Schlumberger spools, job box and Doyon power tongs to rig floor. Clean out Baker tools from pipe shed and bringing in 4.5" completion tubing and process. Operation at 07.00 Processes tubing in pipe shed. 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 5 P PJSM Complete make up of BHA #17, dress off mill assembly, (8.5" dress off mill, 8 1/8" W/O extension, 6.375" X 3.875" inner mill, 8 1/8" W/O boot basket, LBS, Oil jars, 2 Magnostar magnets, XO, 4" pup joint, 15 stands of 4" DP, 31 Jts 4" HWDP) 2445.44'. 01:00 03:30 2.50 3.50 W.O. M 4 P PJSM Run in hole to and tag 4.5" stump at 4238'. Pick up and break circulation at 3 bpm, 78 psi, PUW 100k, SOW 89k, ROTW 95k. Establish returns at 28 bbls pumped. 03:30 05:00 1.50 5.00 W.O. M 19 P PJSM Tag stump at 4238', 50 rpm, 4/6k TQ, 3 bpm, 115 psi. Dress off stump from 4238' to 4244'. WOB 3k and drill off to free ROTW. Pick up with no rotation and perform 2X 5k tags with 35 psi pump increase each time. 05:00 09:00 4.00 9.00 W.O. M 5 P PJSM Blow down top drive. Install FOSV. Kick out all Baker fishing tools and test packer. Prep pipe shed for laying down drill pipe. Offload 2 7/8" PH6 and well control equipment. 09:00 13:30 4.50 13.50 W.O. M 4 P PJSM Pull out of hole laying down 4" drill pipe from 4244' to 68'. 13:30 20:30 7.00 20.50 W.O. M 20 P PJSM Loading 4.5" 563 tubing on off drillers side, drift, strap and tally. Offloading 4" drill pipe from driller side. Held lift plan meeting with all involved. Lifted Schlumberger spoolers/ job box and Doyon power tongs to rig floor. 20:30 22:30 2.00 22.50 W.O. M 5 P PJSM Lay down BHA #17, Clean magnets, inspect dress mill and dump boot basket, minimal debris recovered. Install bridge arm ram on elevator. 22:30 00:00 1.50 24.00 W.O. K 20 P Offload BHA #17 from pipe shed. Continue to load and process 4.5" completion tubing. Position Contact Name Company Title Email Office Mobile Eni representative David Smith ASRC Energy Services Co. Man David.Smith@external.eni.com 907-685-0710 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 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 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 3/14/2023 Report #: 21 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Clear Temperature (°F) -20.1 Wind W @ 8 MPH Days LTI (days) 2,015.00 Days RI (days) POB 45.0 24h Forecast Run completion tubing and sting over stump at 4238'. Mark tubing and pull up and install proper tubing pups to allow stinging over stump and landing tubing hanger. Finish completion termination as per well plan. 24h Summary Load 4.5" tubing and process. Rig up sheaves in derrick. Vault pulled wear bushing and rig hands loaded completion tools to pipe shed. Run lines through sheaves and Schlumberger tested cap line, good. PJSM and make up bottom completion to 153'. Schlumberger pressure tested Gauge mandrel to 500/ 5000', good. Run in hole with completion to 1880'. Operation at 07.00 Running 4.5" completion as per tally. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 12:00 12.00 12.00 W.O. M 20 P PJSM Load 4.5" completion tubing to pipe shed and process. Strap all tubing pups and make final tally. Clean dog house, rig floor, break room, back splash of stairs, iron roughneck, draw works and pipe shed. Install completion sheaves in derrick. Remove old comm line from service loop. Remove Baker tools from pipe shed. 12:00 14:30 2.50 14.50 W.O. M 1 P Clean and organize around rig. Inventory parts connex. 14:30 17:00 2.50 17.00 W.O. K 5 P PJSM Vault pulled wear bushing. Load tubing hanger and completion tools into pipe shed. Rig up Doyon power tongs and equipment. Run Schlumberger lines through sheaves. 17:00 19:30 2.50 19.50 W.O. K 12 P Pressure test Schlumberger cap line, good. 19:30 22:30 3.00 22.50 W.O. K 4 P PJSM for running completion with all personnel. Run in hole with 4,5" completion to 153'. Schlumberger pressure test Gauge mandrel to 500/ 5000 psi, good. 22:30 00:00 1.50 24.00 W.O. K 4 P Continue to run in hole from 153' to 1880', PUW 52k, SOW 50k. Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0726 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 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 Drilling Engineer Amjad Chaudhry Eni Drilling engineer amjad.chaudhry@eni.com 907-346-0591 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 3/15/2023 Report #: 22 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Clear Temperature (°F) -31.9 Wind SW @ 15 MPH Days LTI (days) 2,016.00 Days RI (days) POB 64.0 24h Forecast Close SSSV with pressure on tubing and bleed down pressure above to 2000 psi. Charted for 30 minutes for inflow test. Test 9 5/8" casing to 2000 psi for 30 charted minutes. Pressure down tubing and sheared Mirage plug at 4350 psi. Bleed pressures. Lay down landing joint and set BPV. Nipple down stack and nipple up christmas tree. 24h Summary Run in hole with 4.5" completion as per program to 4202'. Pick up joint #100 and tag stump at 4238' and set down to No Go at 4240'. Mark pipe for space out and make up Vault hanger. Terminate Schlumberger at hanger. Mix 300 bbls of 9.4 ppg packer fluid and pump down Annulus A. Land tubing hanger and run in lock down screws. Test hanger seals to 5000 psi for 10 minutes, good. PJSM with Operations and Production and they pumped 125 bbls of diesel down Annulus A and returns up tubing through Auto Fill Sub. Close Auto Fill Sub with 1350 psi for 5 minutes. Attempt to perform 9 5/8" casing test which failed. Pump down tubing and set PHL packer at 2100 psi and continue to pressure to 3500 psi for tubing integrity test. Charted for 30 minutes, good. Operation at 07.00 Nippling down BOPs. Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. K 4 P PJSM Run in hole with 4.5" completion from 1180' to 2122'. 01:30 03:30 2.00 3.50 W.O. K 5 P PJSM Install Schlumberger SSSV valve and cap line. Function test valve and test line to 8500 psi. good. 03:30 06:30 3.00 6.50 W.O. K 4 P PJSM Run in with 4.5" completion from 2122' to 4202'. Install FOSV. 06:30 12:00 5.50 12.00 W.O. K 20 P PJSM Prep tubing hanger and landing joint. Superior thread hand inspected make up graph for 4.5" tubing torquing. Send results in for approval. Remove collar from hanger pup. Make up XO, head pin, block valve to 2" circ hose. 12:00 13:30 1.50 13.50 W.O. K 4 P PJSM Pick up joint #100 and tag stump at 4238', NO GO at 4240' with 10k down weight. PUW 78k, SOW 74k. 13:30 18:00 4.50 18.00 W.O. K 20 P Lay down joint #100 and #99. Pick up 9.28' spacer pup and joint #99. Make up hanger. Assist Schlumberger to terminate cap line at hanger. Orient hanger as per Vault. Take on 300 bbls of brine and mix packer fluid to 9.4 ppg as per MI engineer. Pump 300 bbls of packer fluid down Annulus A at 4 bpm, 10/20 psi. 18:00 19:00 1.00 19.00 W.O. K 12 P PJSM Vault set hanger and run in lock down screws. Bottom of upper completion string at 4,240' MD. Test upper and lower hanger seal to 5000 psi for 10 minutes. Good test. 19:00 22:00 3.00 22.00 W.O. K 9 P PJSM with production for pumping diesel down Annulus A. Production pump 125 bbls of diesel at .5 bpm taking returns out tubing through Auto Fill Sub. Pump down tubing to shut Auto Fill Sub by pressuring up to 1350 psi. Hold for 5 minutes. 22:00 23:00 1.00 23.00 W.O. K 12 P PJSM Set up to test casing by pressuring up on Annulus A with tubing open to possum belly. Could not gain pressure while pumping and no returns seen, failed test. 23:00 00:00 1.00 24.00 W.O. K 12 P PJSM Pump down tubing and set PHL 9 5/8" packer at 2100 psi. Continue to pressure up to 3500 psi and chart for 30 minutes for tubing integrity test, good test. Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0726 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 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 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 Well Name: OI07-04 OR Wellbore Name: OI07-04 Well Code: 25118 Job: WORKOVER WCEI: N/A Daily Report Date: 3/16/2023 Report #: 23 Page: 1 of 1 Permit/Concession N° ADL-388583 Operator ENI US OPERATING CO.INC. Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code WATER INJECTION WELL Rotary Table Elevation (ft) 41.12 Ground Level (ft) 12.20 First Flange (ft) 4.14 RKB - Base Flange (ft) 36.98 RKB - Tubing Spool (ft) 33.26 Rig Name RIG 4 Contractor NORDIC CALISTA Rig Type LAND RIG Rig Num 0981 Weather Clear Temperature (°F) -33.3 Wind S @ 10 MPH Days LTI (days) 2,017.00 Days RI (days) POB 39.0 24h Forecast No further well work. Move off well OI07 and move to OP03. 24h Summary Perform SSSV inflow test- Good. Annulus A tested to 2000 psi for 30 charted minutes, good. Sheared Mirage plug at 4350 psi. Vault lay down landing joint and install BPV. Rig off Hi-line and on generator power. Nipple down BOPs and nipple up tree. Test void to 5000 psi. good. Perform Passport testing as per Vault for 30 minutes each at 1700 psi. good tests. Schlumberger completed termination on well head and tested SSSV to 8500 psi, good. Rigging down and prepping for rig move. Released rig at 24:00 hrs. Operation at 07.00 Rig move. 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. K 12 P PJSM Close SSSV with 3500 psi on tubing and bleed off above valve to 2000 psi. Perform SSSV inflow test for 30 charted minutes. Pressure tubing to 3500 psi to equal pressure and open SSSV valve. Good test. 01:00 02:00 1.00 2.00 W.O. K 12 P PJSM Perform Annulus A test to 2000 psi for 30 charted minutes, good test. 02:00 02:30 0.50 2.50 W.O. K 9 P PJSM Pump 1.5 bbls down tubing and shear Mirage plug at 4350 psi. 02:30 04:00 1.50 4.00 W.O. K 5 P PJSM Vault back out and lay down landing joint. Vault install BPV. Blow down choke, kill and top drive. 04:00 06:00 2.00 6.00 W.O. C 5 P PJSM Remove riser and nipple down BOP stack. 06:00 07:30 1.50 7.50 W.O. K 5 P PJSM Vault obtained well bay permit. Take rig off Hi-Line power and on rig generator at 1916 hr. 07:30 08:00 0.50 8.00 W.O. C 5 P PJSM Rig down Hi-pressure riser. 08:00 10:00 2.00 10.00 W.O. K 5 P PJSM Schlumberger terminated lines to well head. Blow down pumps and removing fluids from pits. Start to clean pits. Offload extra tubing from pipe shed. Pull mouse hole and secure with working joints in pipe shed. Top off nitrogen bottles to 1000 psi. 10:00 11:00 1.00 11.00 W.O. C 5 P PJSM Install tree and torque GrayLoc clamp. 11:00 12:00 1.00 12.00 W.O. K 12 P PJSM Schlumberger installed electrical line. Pressure tested SSSV to 8500 psi. Vault test void to 5000 psi for 10 minutes- Good. 12:00 17:30 5.50 17.50 W.O. C 12 P PJSM Rig up test pump and perform Passport testing as per Vault to 1700 psi for 30 charted minutes each. Good tests. 17:30 00:00 6.50 24.00 W.O. K 20 P PJSM Take down berming around rig. Move cuttings box. Disconnect Hi-line as per ENI electrician and move away from rig. Move Hi-line shack. Install well bay hatch. Disconnect Geronimo line and coil up on landing. Completed cleaning pits. Grease walker feet. Rig release from OI07-04 3-16-2023 24:00. Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0726 Eni representative Russ Wimmer ASRC Energy Services Co. Man Russ.Wimmer@external.eni.com 907-685-0710 Eni representative Yelyzaveta Saprykina ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative David Rush ASRC Energy Services HSE David.Rush@external.eni.com 970-685-6622 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 Eni representative Amjad Chaudhry Eni Drilling engineer amjad.chaudhry@eni.com 907-346-0591 Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 5 3/4 L80 5,425.3 12,315.0 3,924.4 1/16/2011 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:4 DATE:3/11/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2101530 Sundry #322-683 Operation:Drilling:Workover:x Explor.: Test:Initial:Weekly:x Bi-Weekly:Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:1132 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 Hydril 13 5/8 P Pit Level Indicators P P #1 Rams 1 13 5/8" BSR P Flow Indicator P P #2 Rams 1 2 7/8"x 5 1/2" vbr P Meth Gas Detector P P #3 Rams 1 2 7/8"x 5 1/2" vbr P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"P System Pressure (psi)3000 P Kill Line Valves 1 3 1/8"P Pressure After Closure (psi)2100 P Check Valve 0 NA 200 psi Attained (sec)21 P BOP Misc 0 NA Full Pressure Attained (sec)69 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4@2925 P No. Valves 14 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 11 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0 NA #3 Rams 4 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:6.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/11/23 1600 Waived By Test Start Date/Time:3/11/2023 8:30 (date)(time)Witness Test Finish Date/Time:3/11/2023 15:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Nordic Kyle Karsten / George Orloff ENI David Smith / Russ Wimmer Test Pressure (psi): igmanager.rig4@nordic-calista.co OPPdrilling@eni.com Nikaitchuq OI07-04 Tested with 4" & 4-1/2" Test JT. Gas Alarms Tested. PVT alarms tested. Precharge bottles 18@1000 psi Form 10-424 (Revised 08/2022)2023-0311_BOP_Nordic4_Nikaitchuq_OI07-04 J. Regg; 6/14/2023 1 Regg, James B (OGC) From:Nordic Calista Rig 4 Tool <Rigmanager.rig4@nordic-calista.com> Sent:Sunday, March 5, 2023 5:17 PM To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay Subject:Nordic Rig 4 Attachments:Nordic 4 BOPE Test 3-3-23.xlsx Let me know if I missed anything. Thanks Richard Twedt Rig Manager Nordic 4 907‐685‐1470 Office 605‐999‐7262 Cell This information is intended only for the use of the individual (s) or entity (ies) named above and may contain confidential or privileged information. Any unauthorized disclosure, copying, distribution or the taking of any action in reliance on the contents of this transmitted information is strictly prohibited. If you are not the intended recipient or have received this transmission in error, please immediately delete it and any attachments from your system and send me an email confirming that you have not disclosed, copied, or distributed this message and that you have deleted this message and any attachments from your system. 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. Nikaitchuq OI07-04PTD 2101530 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:4 DATE:3/3/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2101530 Sundry #322-683 Operation:Drilling:Workover:x Explor.: Test:Initial:Weekly:x Bi-Weekly:Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:1132 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 Hydril 13 5/8 P Pit Level Indicators P P #1 Rams 1 13 5/8" BSR P Flow Indicator P P #2 Rams 1 2 7/8"x 5 1/2" vbr P Meth Gas Detector P P #3 Rams 1 2 7/8"x 5 1/2" vbr P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"P System Pressure (psi)2950 P Kill Line Valves 1 3 1/8"P Pressure After Closure (psi)2000 P Check Valve 0 NA 200 psi Attained (sec)22 P BOP Misc 0 NA Full Pressure Attained (sec)74 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 @ 2787 P No. Valves 14 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 13 P #1 Rams 8 P Coiled Tubing Only:#2 Rams 4 P Inside Reel valves 0 NA #3 Rams 4 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.5 hrs HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/1/23 17:00 Waived By Test Start Date/Time:3/3/2023 21:30 (date)(time)Witness Test Finish Date/Time:3/4/2023 3:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Nordic Richard Twedt / George Orloff ENI Paul Dillion/ Mark Ashley Test Pressure (psi): igmanager.rig4@nordic-calista.co OPPdrilling@eni.com Nikaitchuq OI07-04 Tested with 4" & 4-1/2" Test JT. Gas Alarms Tested. PVT alarms tested. Form 10-424 (Revised 08/2022)2023-0303_BOP_Nordic4_Nikaitchuq_OI07-04 J. Regg; 6/13/2023 1 Regg, James B (OGC) From:Chaudhry Amjad <Amjad.Chaudhry@eni.com> Sent:Tuesday, February 28, 2023 11:31 AM To:AOGCC Reporting (CED sponsored); McLellan, Bryan J (OGC); Regg, James B (OGC) Cc:Pierfelici Stefano; Carballo Nelson; Enipetroleum OPPDrilling; Dillon Paul; Cornell Jody; DOA AOGCC Prudhoe Bay Subject:Annular use on Nordic Calista 4 , Well OI07-04 PTD:210-153 Sundry: 322-683 Please see below information as per industry guidance Bulletin 10‐003A Report Contents Date, Time of BOPE Use February 28th, 2023/01:15 A.M. Well/Location/PTD Number OI07‐04/Oliktok Point/210‐153 Rig Name Nordic Calista 4 Operator Contact 907‐685‐0710 Operations Summary, including events leading up to BOPE use BOPE Used Pumping 10 bbl per/hour to keep the Annulus full of 8.9# Brine. Well accepted 8 bbls & was full. Shut down pumps and drill pipe displaced 3 bbls of fluid to the pits with a majority of the fluid coming back as diesel. Shut HCR & Annular bag and prepare to bullhead well. Bull headed 6 bbls and monitored well for an hour no pressure observed, well static. Reason for BOPE Use Driller felt it was the safest step to take to secure the well & prepare for bullheading operations. Actions Taken/To Be Taken Submit request for BOPE test, Test Annular bag to 2500 psi & HCR to 3500 psi. Previous test date was 2/24/2023. Date Used BOPE Retested 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. Nikaitchuq OI07-04PTD 2101530 jbr 2 Test date=February 28th, 2023 Amjad Chaudhry P.Eng Sr. Drilling Engineer Eni US Operating Co. Inc. 3700 Centerpoint Dr., Suite 500 Anchorage, AK 99503 : 907‐865‐3379 D : 907‐346‐0591 M E.mail: amjad.chaudhry@eni.com This document and any files or e‐mail messages attached to it contain data or information that is confidential, privileged or otherwise restricted from disclosure. If you are not the intended recipient, be aware that any disclosure, copying, distribution or use of any of the data or information contained herein or in any of the attachments is strictly prohibited. If you have received this document or transmission in error, please immediately notify the sender and destroy, delete or erase this document and all attachments. ---------------------------------------------------------------------------------------------------------------------------------------------------- -------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ From:McLellan, Bryan J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OI07-04 (PTD 210-153) Nordic 4 BOP use and testing Date:Tuesday, February 28, 2023 11:21:44 AM Include this email in the wellfile. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: McLellan, Bryan J (OGC) Sent: Tuesday, February 28, 2023 9:25 AM To: Chaudhry Amjad <Amjad.Chaudhry@eni.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Nordic 4 BOP use and testing Amjad, Following up on our conversation, ENI should submit the BOP usage form per Industry Guidance Bulletin 10-003. https://www.commerce.alaska.gov/web/Portals/18/pub/StatutesAndRegulations/Industry%20Guida nce%20Bulletin%2010-03.pdf Also, the Equipment used to control the well, including Annular and HCR must be tested prior to re- entry. Also submit the BOP test notification per normal protocol. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:4 DATE:2/24/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2101530 Sundry #322-683 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:1132 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 Hydril 13 5/8 P Pit Level Indicators P P #1 Rams 1 13 5/8" BSR P Flow Indicator P P #2 Rams 1 2 7/8"x 5 1/2" vbr P Meth Gas Detector P P #3 Rams 1 2 7/8"x 5 1/2" vbr P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 1 3 1/8"P System Pressure (psi)3050 P Kill Line Valves 1 3 1/8"P Pressure After Closure (psi)2150 P Check Valve 0 NA 200 psi Attained (sec)23 P BOP Misc 1 FP Full Pressure Attained (sec)70 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 @ 2950 P No. Valves 14 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 11 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0 NA #3 Rams 6 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:4.5 hrs HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2/22/23 09:14 Waived By Test Start Date/Time:2/24/2023 2:00 (date)(time)Witness Test Finish Date/Time:2/24/2023 10:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nordic Tested with 4" & 4-1/2" Test JT. Gas Alarms Tested. PVT alarms tested. Fail/Pass on upper ram door seal Kyle Karsten / Richard Twedt ENI Jody Cornell / Mark Ashley Nikaitchuq OI07-04 Test Pressure (psi): igmanager.rig4@nordic-calista.co OPPdrilling@eni.com Form 10-424 (Revised 08/2022)2023-0224_BOP_Nordic4_Nikaitchuq_OI07-04 UPR door seal J. Regg; 6/13/2023 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: Change injection packer 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: Nikaitchuq Schrader Bluff Schrader bluff 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12,325 N/A Casing Collapse Structural Conductor N/A Surface 2260 Intermediate 4760 Production Liner Slotted 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:amjad.chaudhry@eni.com Contact Phone: 907-865-3379 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 5,601'-12,325' 5-1/2" 3,678'-3,925' 5,372'-12,313'6941 4.5" 3,563'-3,924' 20" 13-3/8" 160 2315 Perforation Depth MD (ft): 9-5/8"5601 MD 6870 N/A 5020 160' 2192 3678 160' 2315 5601 Length Size Proposed Pools: TVD Burst 3,925 12,313 3,924 1132 N/A PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 355024, 373301, 390616 210-153 3700 Centerpoint Dr, Ste.500, Anchorage, AK, 99503 50-029-23435-00-00 Eni US Operating Co. Inc N/A OI07-04 Slotted Tubing Grade: Tubing MD (ft): 4,305' MD/3,471' TVD Perforation Depth TVD (ft): Tubing Size: L-80 4,265 12/20/2022 HES AHR 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 Well Operations Project Manager 12/1/2022 Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov BOPtestto2500psi. DSR-12/1/22 X Provide 48 hrs notice for AOGCC opportunity to witness pressure test of 4-1/2" x 9-5/8" annulus to 1500 psi after the well has been put on injection and reached stable conditions. Setting injection packer >200' above injection zone is allowed per AIO 36, Rule 2. Packer will be set below top of confining zone and more than 300' below TOC. BJM 12/13/22 DLB 12/01/2022 X 10-404 GCW 12/13/22 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.12.13 16:16:59 -09'00' RBDMS JSB 121522 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 Email: Stefano.pierfelici@eni.com December 01, 2022 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OI07-04 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OI07-05. ENI Petroleum at Oliktok Point completed OI07-05 in March 2011 as a Schrader bluff injector. In May 2021 it was noticed that possible communication between tubing and 9-5/8 casing It was decided to run Tx IA communication diagnostic on OI07-04 and then possible setting the tubing patch. On May 12 and 13th 2022, a rig less job was performed for leak investigation with a caliper log/ACX and ACX data shows TxIA communications and it confirmed leak in the injection tubing at 2,47 2,482 patch was then set and MIT was performed and it was failed, a combo test was performed and it showed integrity of the production casing, Eni applied administrative approval per AIO 36, Rule 6 to keep well on injection with the proposed operating and monitoring plan that well will meet criteria of 20-AAC 25.412 for continued enhanced recovery operations, Approval was granted on October 6 th, 2022 . Well is on injection since then. Plan is to remove upper completion and run back new completion with injection packer. Estimated start of the operations is December 20th, 2022 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 OI07-05 Workover Summary Page PTD#:210-153 Status Well OI07-05 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 (3,678 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: Attempted to performed MIT in May 2022, failed due to suspected tubing leak. A Combo MIT was performed in June 2022 and it passed. Well type: Injector Estimated start date: December 20th, 2022 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 3%KCL/NaCl brine through tree. 2. Ensure well is killed. Set BPV. 3. MIRU Nordic-4. 4. ND tree and NU BOP and test. 5. Cut tubing above packer 6. Circ through tubing cut location displacing 4--with 3% KCL/NaCl brine 7. POOH with 4- Note: 4-ompletion string below packer well remain in hole 8. Set packer above the original packer and test 9-2000 psi. 9. Contingent casing investigation may be performed based on the well condition. 10. MU new 4- sting and RIH to setting depth. Note: New completion will include 4- x 9-- tubing overshot below. Overshot will swallow 4- from original completion. 11. Circ freeze protection and corrosion inhibited 3%KCL/NaCl brine completion fluid to 4-- 12. Land tubing hanger and overshot 13. Set 4-- 14. Pressure test 4- 15. Pressure test 4--000 psi, charted 16. Install BPV and nipple down BOP. 17. NU tubing adapter and tree. 18. Pull BPV, install test plug and test tree. 19. RDMO. Provide 48 hrs notice for AOGCC opportunity to witness pressure test of 4-1/2" x 9-5/8" annulus to 1500 psi after the well has been put on injection and reached stable conditions. -bjm Sonic Log shows TOC around 2300' MD. Below the current schematic of the well: Proposed Schematic Nordic 4 BOP 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: OI07-04 AA Request (PTD#210-153) Date:Wednesday, November 9, 2022 2:25:08 PM Attachments:image001.png From: Lopez Keith <Keith.Lopez@eni.com> Sent: Wednesday, November 9, 2022 1:48 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Hart David <David.Hart@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Pitzalis Francesco <Francesco.Pitzalis@eni.com>; Buchert Brad <Brad.Buchert@external.eni.com>; McDonald Mike <Mike.Mcdonald@external.eni.com>; Hendrickson Keith <keith.hendrickson@eni.com>; Lopez Keith <Keith.Lopez@eni.com> Subject: RE: OI07-04 AA Request (PTD#210-153) Mr. Wallace, The tubing by inner annulus leak on OI07-04 continues to be inactive. The IA pressure continues to pressure up over 1,000 psi due to thermal effects (current tubing pressure is 40 psi). We have conducted 5 inner annular bleeds to manage the pressure within the sustained limit with very small volumes returned. A log of these bleeds will be provided with the monthly report required by the AA. Unless the AOGCC objects, ENI plans to go forward managing the IA pressure under the following guidelines: Always discuss bleeding with the Production Engineer before conducting. Only bleed when the IA exceeds 1,500 psi. Always stop bleeding if more than 1 bbl (42 gals) is returned. We will review and discuss the plan forward at that time. Always document any bleeds on the IA Bleed Log. 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 Sent: Monday, October 10, 2022 9:28 AM To: jim.regg@alaska.gov; Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Hart David <David.Hart@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Pitzalis Francesco <Francesco.Pitzalis@eni.com>; Buchert Brad <Brad.Buchert@external.eni.com>; McDonald Mike <Mike.Mcdonald@external.eni.com>; Hendrickson Keith <Keith.Hendrickson@eni.com>; Lopez Keith <Keith.Lopez@eni.com> Subject: RE: OI07-04 AA Request (PTD#210-153) Mr. Wallace, ENI received the approved Area Injection Order 36.008. On 10/07/22, OI07 was brought back on injection at minimum rate. The tubing is on a vacuum but the IA quickly pressured up to ~1,500 psi. It does not look as though the TxIA pressure communication is active and the pressure is due to temperature increases in the trapped inner annulus string. We conducted 3 short IA bleeds using caution in the event the bleeds activated the pressure communication. For now the strings do not seem to be in communication. We plan to bleed off the IA pressure to the normal operating pressure of ~100 psi. These bleeds will be noted in the monthly report required by the AA. 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, September 23, 2022 2:15 PM To: jim.regg@alaska.gov; Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Hart David <David.Hart@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Pierfelici Stefano <Stefano.Pierfelici@eni.com>; Province Robert <Robert.Province@eni.com>; Rupert Stephanie <Stephanie.Rupert@eni.com>; Lopez Keith <Keith.Lopez@eni.com>; Tamara Maddox <maddox@aoga.org> Subject: OI07-04 AA Request (PTD#210-153) Dear AOGCC: ENI is requesting per AIO 36, Rule 6 Administrative Approval to allow Nikaitchuq Schrader Bluff injection well OI07-04 (PTD 210-153) to remain in water injection service with known tubing by inner annulus communication. With the proposed operating and monitoring plan the well will meet the criteria of 20 AAC 25.412 for continued enhanced recovery operations. Should you have any additional questions or require any additional information, please contact me at 907-865-3300. 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: OI07-04 AA Request (PTD#210-153) Date:Tuesday, October 11, 2022 9:22:24 AM Attachments:image001.png EXTERNAL AOGCC_Public_Notices Area Injection Order 36.008 (Nikaitchuq Unit).msg From: Lopez Keith <Keith.Lopez@eni.com> Sent: Monday, October 10, 2022 9:29 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Hart David <David.Hart@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Pitzalis Francesco <Francesco.Pitzalis@eni.com>; Buchert Brad <Brad.Buchert@external.eni.com>; McDonald Mike <Mike.Mcdonald@external.eni.com>; Hendrickson Keith <keith.hendrickson@eni.com>; Lopez Keith <Keith.Lopez@eni.com> Subject: RE: OI07-04 AA Request (PTD#210-153) Mr. Wallace, ENI received the approved Area Injection Order 36.008. On 10/07/22, OI07 was brought back on injection at minimum rate. The tubing is on a vacuum but the IA quickly pressured up to ~1,500 psi. It does not look as though the TxIA pressure communication is active and the pressure is due to temperature increases in the trapped inner annulus string. We conducted 3 short IA bleeds using caution in the event the bleeds activated the pressure communication. For now the strings do not seem to be in communication. We plan to bleed off the IA pressure to the normal operating pressure of ~100 psi. These bleeds will be noted in the monthly report required by the AA. 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, September 23, 2022 2:15 PM To: jim.regg@alaska.gov; Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Hart David <David.Hart@eni.com>; Burgess Larry <Larry.Burgess@eni.com>; Morgan Michael <Mike.Morgan@eni.com>; Zuber Joshua <Joshua.Zuber@eni.com>; Pierfelici Stefano <Stefano.Pierfelici@eni.com>; Province Robert <Robert.Province@eni.com>; Rupert Stephanie <Stephanie.Rupert@eni.com>; Lopez Keith <Keith.Lopez@eni.com>; Tamara Maddox <maddox@aoga.org> Subject: OI07-04 AA Request (PTD#210-153) Dear AOGCC: ENI is requesting per AIO 36, Rule 6 Administrative Approval to allow Nikaitchuq Schrader Bluff injection well OI07-04 (PTD 210-153) to remain in water injection service with known tubing by inner annulus communication. With the proposed operating and monitoring plan the well will meet the criteria of 20 AAC 25.412 for continued enhanced recovery operations. Should you have any additional questions or require any additional information, please contact me at 907-865-3300. 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/ 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov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¶VUHTXHVWIRUDGPLQLVWUDWLYHDSSURYDOWR FRQWLQXHZDWHULQMHFWLRQLQWKHVXEMHFWZHOO 2Q -XO\ WKH ZHOO H[SHULHQFHG VORZ WXELQJ E\ LQQHU DQQXOXV 7[,$ SUHVVXUH FRPPXQLFDWLRQ DQGZDVUHSRUWHGWR$2*&& (QLKDGFRPSOHWHGDZRUNRYHULQ-XQH LQVWDOOLQJDQHZWXELQJSDWFK(QLSHUIRUPHGDSDVVLQJVWDWHZLWQHVVHG0,7RIWKHLQQHUDQQXOXV RQ-XQH ZKLFKFRQILUPVLQWHJULW\ RIWKH ´FDVLQJWRWKHSDFNHUDWIW0' IW 79' $2*&& EHOLHYHV (QL FDQ VDIHO\ PDQDJH WKH 7[,$ ZLWK SHULRGLF SUHVVXUH EOHHGV $FFRUGLQJO\WKH$2*&&EHOLHYHVWKDWWKHZHOO¶VFRQGLWLRQGRHVQRWFRPSURPLVHRYHUDOOZHOO LQWHJULW\VRDVWRWKUHDWHQKXPDQVDIHW\RUWKHHQYLURQPHQW $2*&&¶VDSSURYDOWRFRQWLQXHZDWHU LQMHFWLRQ LQ 2,LVFRQGLWLRQHGXSRQWKHIROORZLQJ (QLVKDOOUHFRUGZHOOKHDGSUHVVXUHVDQGLQMHFWLRQUDWHGDLO\ (QLVKDOOVXEPLWWRWKH$2*&&DPRQWKO\UHSRUWRIZHOOSUHVVXUHVLQMHFWLRQUDWHVDQG SUHVVXUHEOHHGVIRUDOODQQXOL%OHHGVWREHIODJJHGRQWKHUHSRUW (QLVKDOOSHUIRUPDFRPELQDWLRQ0,7 RIWKHWXELQJDQGLQQHUDQQXOXVHYHU\WZR\HDUVWR WKHJUHDWHURIWKHPD[LPXPDQWLFLSDWHGLQMHFWLRQSUHVVXUHRU[SDFNHU79'EXWQRW OHVVWKDQSVL 7KHDSSOLFDWLRQDVNHGIRUDQDGPLQLVWUDWLYHDSSURYDOXQGHU5XOHRI$,2ZKLFKJUDQWHGWKH$2*&&WKH DXWKRULW\WRDGPLQLVWUDWLYHO\DPHQGWKHRUGHU7KLVUXOHZDVPDGHREVROHWHRQ)HEUXDU\ZKHQ $$& G EHFDPHHIIHFWLYHDQGDXWKRUL]HGWKH$2*&&WRDGPLQLVWUDWLYHO\DPHQGDQ\RUGHULWKDVLVVXHG $,2 2FWREHU 3DJH RI (QL VKDOOOLPLWWKHZHOO¶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regory Wilson Digitally signed by Gregory Wilson Date: 2022.10.06 15:45:45 -08'00' Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.10.06 16:49:21 -08'00' 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: OI07-04 (PTD# 210-153) TxIA Communication Date:Tuesday, July 26, 2022 3:49:55 PM Attachments:image006.png From: Lopez Keith <Keith.Lopez@eni.com> Sent: Tuesday, July 26, 2022 11:19 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>; Hanson Samuel <Sam.Hanson@eni.com>; Tredway Tommy <Tommy.Tredway@eni.com>; Lopez Keith <Keith.Lopez@eni.com> Subject: RE: OI07-04 (PTD# 210-153) TxIA Communication Mr. Wallace, OI07-04 recently had a tubing patch set and passed an AOGCC witnessed MIT on 6/19/22. On 7/18/22, we observed the IA pressure increase to ~430 psi over a 2 day period. On 7/22/22, we bled the IA pressure to 0 psi and again observed the pressure rise over a 2 day period. We have shut in the injector and it will remain so until further diagnostics can be conducted. Please let me know of 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: Wednesday, June 8, 2022 2:59 PM 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: RE: OI07-04 (PTD# 210-153) TxIA Communication Mr. Wallace, OI07 recently had a tubing patch installed that appears to have fixed the TxIA communication. We returned the well to minimum injection on 5/21/22 to begin getting the well thermally stable. On 6/2/22, we conducted an ENI internal MIT to 1,000 psi that passed. We were unable to test to the AOGCC required 1,500 psi due to a shear valve that is currently installed in the GLM. To date, we have not been able to free up a slickline crew to change out the shear valve for a dummy due to other operations. This will be required to conduct the state witnessed MIT. We do not have a definite timeline for when we will be able to conduct the work but the annulus remains stable at ~115 psi while the tubing pressure is ~5 psi. Will the AOGCC allow us to continue to inject at minimum rates until slickline can change the valve and conduct the witnessed MIT or prefer that the well is shut in? 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: Wednesday, May 11, 2022 11:32 AM To: chris.wallace@alaska.gov; Regg, James B (CED) <jim.regg@alaska.gov>; grace.salazar@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: OI07-04 (PTD# 210-153) TxIA Communication Mr. Wallace, Today (05-11-22), ENI noticed a concern with tubing by inner annulus communication on OI07-04. The IA pressure increased from -5 psi to 513 psi over a 10 minute 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. OI07-04 last passed it’s 4-year MIT on 03/21/21. 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/ Security Warning: This email originated from outside of the organization. Do not click links or open attachments unless you have verified the sender’s email address and know the content is safe. 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: [EXTERNAL] RE: OI07-04 (PTD# 210-153) TxIA Communication Date:Tuesday, June 21, 2022 3:20:04 PM Attachments:image001.png MIT NIK OI07-04 06-19-22.xlsx OI07-04 As Completed 5-20-2022.pdf From: Lopez Keith <Keith.Lopez@eni.com> Sent: Monday, June 20, 2022 1:44 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL] RE: OI07-04 (PTD# 210-153) TxIA Communication Mr. Wallace, You probably saw the MIT test sheet come through but wanted to follow up that this issues has been resolved. 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 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Wednesday, June 8, 2022 6:56 PM To: Lopez Keith <Keith.Lopez@eni.com>; 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> Subject: [EXTERNAL] RE: OI07-04 (PTD# 210-153) TxIA Communication Keith, Thank you for the email and follow up telephone call just now. AOGCC will authorize continued injection at the minimum rate for up to 2 weeks to facilitate a quicker stabilized witnessed MIT and return back to full injection. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Lopez Keith <Keith.Lopez@eni.com> Sent: Wednesday, June 8, 2022 2:59 PM 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: RE: OI07-04 (PTD# 210-153) TxIA Communication Mr. Wallace, OI07 recently had a tubing patch installed that appears to have fixed the TxIA communication. We returned the well to minimum injection on 5/21/22 to begin getting the well thermally stable. On 6/2/22, we conducted an ENI internal MIT to 1,000 psi that passed. We were unable to test to the AOGCC required 1,500 psi due to a shear valve that is currently installed in the GLM. To date, we have not been able to free up a slickline crew to change out the shear valve for a dummy due to other operations. This will be required to conduct the state witnessed MIT. We do not have a definite timeline for when we will be able to conduct the work but the annulus remains stable at ~115 psi while the tubing pressure is ~5 psi. Will the AOGCC allow us to continue to inject at minimum rates until slickline can change the valve and conduct the witnessed MIT or prefer that the well is shut in? 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: Wednesday, May 11, 2022 11:32 AM To: chris.wallace@alaska.gov; Regg, James B (CED) <jim.regg@alaska.gov>; grace.salazar@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: OI07-04 (PTD# 210-153) TxIA Communication Mr. Wallace, Today (05-11-22), ENI noticed a concern with tubing by inner annulus communication on OI07-04. The IA pressure increased from -5 psi to 513 psi over a 10 minute 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. OI07-04 last passed it’s 4-year MIT on 03/21/21. 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/ Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2101530 Type Inj W Tubing 4 4 4 4 Type Test P Packer TVD 3471 BBL Pump 1.8 IA 181 1629 1539 1527 Interval V Test psi 1500 BBL Return 1.7 OA 175 300 300 300 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Eni US Operating Co Inc Nikaitchuq - OPP Adam Earl Brad Buchert 06/19/22 Notes:MIT after tubing patch set. Notes: Notes: Notes: OI07-04 Form 10-426 (Revised 01/2017)MIT NIK OI07-04 06-19-22 (002) 13-3/8" 68 ppf Casing, 2,315' MD, 2,192 TVD, 34º Inc9-5/8" 47 ppf IntermediateCasing, 5,601' MD, 3,678' TVD, 85º Inc4-½” 12.6 ppf Production Tubing5-½” 17 ppfSlotted Liner,Alt. blank/slot 12,313' MD, 3,924' TVD, 89ºInc(drifted to 15.50#)3-1/2" 9.2 ppf Inner String, 12,085' MD, 3,918' TVD, 87º IncZonal Isolation PackersInjection Control DevicesAHR Retr. Packer with 2 Feed-Thrus, 4,305' MD, 3,471 TVD, 72º Inc4-½” Poly cable clampsSingle ¼” Stainless Steel Encapsulated Line with Double End DTS Fiber and Electric for Toe P/T gaugeConfidentialACOI07-04 Injector With Fiber/Electric MonitoringNikaitchuq Field – Oliktok Point PadSingle ¼” Stainless Steel Encapsulated TEC Line for Heel P/T gauge2,208' MD, 2,102' TVD, 32º Inc - 4-½” x 1" KBMG GLM, with 2,000 psi A-to-T shear valve2,308' MD, 2,190' TVD, 34º Inc - 3.81" X-nipple for possible injection valve4,321' MD, 3,475' TVD, 72º Inc - 3.725" XN (Inserted Nipple reducer 2-7/8" 6.4# XN style Nipple with 2.205" NoGo XN profile 2-7/8" 6.4# Hydril 511 Box x Full mule Shoe down4,291' MD, 3,450' TVD, 72º Inc - 3.81" X-nipple 12,071' MD,3,917' TVD - Gauge Carrier, P/T at Toe As CompletedMay 20th, 20225,372' MD, 3,653' TVD, 84º Inc – SLZXP Liner Hgr/Pkr Tubing Patch = TOPE= 2,460' , BOPE=2,492', Patch ID=2.992"5,302' MD/3,647' TVD Gauge Carrier -for P,T at Heel 3-½” Cable Clamps MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Eni US Operating Co. Inc. OI07-04 NIKAITCHUQ OI07-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/20/2022 OI07-04 50-029-23435-00-00 210-153-0 W SPT 3471 2101530 1500 4 4 4 4 175 300 300 300 OTHER P Adam Earl 6/19/2022 Post patch install. MIT-IA 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 OI07-04 Inspection Date: Tubing OA Packer Depth 181 1629 1539 1527IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220622075742 BBL Pumped:1.8 BBL Returned:1.7 Wednesday, July 20, 2022 Page 1 of 1 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: OI07-04 (PTD# 210-153) TxIA Communication Date:Thursday, June 9, 2022 9:35:45 AM Attachments:image005.png From: Wallace, Chris D (OGC) Sent: Wednesday, June 8, 2022 6:56 PM To: Lopez Keith <Keith.Lopez@eni.com>; 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> Subject: RE: OI07-04 (PTD# 210-153) TxIA Communication Keith, Thank you for the email and follow up telephone call just now. AOGCC will authorize continued injection at the minimum rate for up to 2 weeks to facilitate a quicker stabilized witnessed MIT and return back to full injection. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Lopez Keith <Keith.Lopez@eni.com> Sent: Wednesday, June 8, 2022 2:59 PM 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: RE: OI07-04 (PTD# 210-153) TxIA Communication Mr. Wallace, OI07 recently had a tubing patch installed that appears to have fixed the TxIA communication. We returned the well to minimum injection on 5/21/22 to begin getting the well thermally stable. On 6/2/22, we conducted an ENI internal MIT to 1,000 psi that passed. We were unable to test to the AOGCC required 1,500 psi due to a shear valve that is currently installed in the GLM. To date, we have not been able to free up a slickline crew to change out the shear valve for a dummy due to other operations. This will be required to conduct the state witnessed MIT. We do not have a definite timeline for when we will be able to conduct the work but the annulus remains stable at ~115 psi while the tubing pressure is ~5 psi. Will the AOGCC allow us to continue to inject at minimum rates until slickline can change the valve and conduct the witnessed MIT or prefer that the well is shut in? 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: Wednesday, May 11, 2022 11:32 AM To: chris.wallace@alaska.gov; Regg, James B (CED) <jim.regg@alaska.gov>; grace.salazar@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: OI07-04 (PTD# 210-153) TxIA Communication Mr. Wallace, Today (05-11-22), ENI noticed a concern with tubing by inner annulus communication on OI07-04. The IA pressure increased from -5 psi to 513 psi over a 10 minute 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. OI07-04 last passed it’s 4-year MIT on 03/21/21. 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: OI07-04 (PTD# 210-153) TxIA Communication Date:Thursday, May 12, 2022 11:30:28 AM Attachments:image001.png From: Lopez Keith <Keith.Lopez@eni.com> Sent: Wednesday, May 11, 2022 11:32 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; grace.salazar@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: OI07-04 (PTD# 210-153) TxIA Communication Mr. Wallace, Today (05-11-22), ENI noticed a concern with tubing by inner annulus communication on OI07-04. The IA pressure increased from -5 psi to 513 psi over a 10 minute 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. OI07-04 last passed it’s 4-year MIT on 03/21/21. 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/ MEMORANDUM TO: JimRegg ' f 4bz-(ZM P.I. Supervisor \� FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, April 2, 2021 SUBJECT: Mechanical Integrity Tests Ent US OpemUng Company Inc. 0107-04 NIXACfCHUQ 0107-04 See: Inspector Reviewed By: P.I. Sup" ,TNT— Comm T —Comm Well Name NIKAITCHUQ 0107-04 API Well Number 50-029-23435-00-00 Inspector Name: Matt Herrera Permit Number: 210-153-0 Inspection Date: 3/2112021 IeSp Num: mitMFH210323071602 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 0107-04 - Type Inj I w - TVD 3471- Tubing 489 489 - 489 489 - PTD 2101530 Type Test SPT' Test psi 1500 IA 3 1730 1690 - 1676 " BBL Pumped: 4.3 BBL Returned: zs _ OA las 340 340 - 330 Iaterval 4YRTST px - Notes: MIT -IA Pressure tested to 1700 PSI per Operator for minimum test pressure / {sj-d.UE� IZ�?.lr-LO Friday, April 2, 2021 Pagc I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,December 28,2016 TO: Jim Regg ( J Z 1 j1/cv P.I.Supervisory—e�j j' :t SUBJECT: Mechanical Integrity Tests ENI US OPERATING CO INC 0I07-04 FROM: Jeff Jones NIKAITCI-IUQ 0107-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ 0107-04 API Well Number 50-029-23435-00-00 Inspector Name: Jeff Jones Permit Number: 210-153-0 Inspection Date: 12/9/2016 Insp Num: mitJJ161212101640 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 0107-04 (Type Inj W'TVD 3471 • Tubing 244 242 241 - 241 PTD 2101530 (Type Test SPT Test psi 1500 , IA 823 1650 - 1623 - 1615 - Interval 4YRTST P/F P OA 200 280 . 280 - 280 - Notes: 1.1 barrels diesel pumped. I well inspected,no exceptions noted. 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. J 0 - ( 5'3 Well History File Identifier Organizing(done) ❑ Two-sided III 111111 I II Iliii ❑ Rescan Needed II 1111111 1 111 111 RES N DIGITAL DATA OVERSIZED (Scannable) C for Items: ❑ Diskettes, No. ❑ M ps: Greyscale Items: ❑ Other, No/Type: o Other Items Scannable by �, a Large Scanner ro ( i Oi1� ❑ Poor Quality Originals: j ®� OVERSIZED (Non-Scannable) ''` ❑ Other: ❑ Logs of various kinds: NOTES: r ❑ Other:: BY: Maria Date: 57 / /s/ rYF l P Project Proofing 111111111111011111 BY: Maria Date: 5/0 l'" lsl rip Scanning Preparation 7 x 30 = L I O + = TOTAL PAGES a fo (Count does not include cover sheet) vvj � BY: Maria Date: 5////11- /s/ Production Scanning II 1111111111 IIIII Stage 1 Page Count from Scanned File: a 1 I (Count does include cover sheet) Page Count Matches Number in Scann' g Preparation: YES NO BY: CP Date: S //114- /s/ Imp Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 1111111111111111111 ReScanned 111111111111011111 BY: Maria Date: /s/ Comments about this file: Quality Checked 111111111111 IIIIII o I c — f0 — ct N o m a) m m m co a m N 4 O O6 .0 C N 'O(n 'O CO a co = F. O O U a) a) O) co O � � FLDE) 0LL 0 0 £ Eg E .5 g ° > m _ p O) a) N"O a) _ c a) .- 'Ll O) I N I a)otS a3 a)ata fa a3 a C O O J ,O >. C a3 rp CGpN 3 N N app appa .4 '� o o p cUt cc - ucn Ucn I�WC�LL� II 19: ICI o )° O U cC -o co > rn.- > rn > c 2 o .N Z a p U C o a) 2 W C O a) 2 a)LL 0 > 0 > 0 0 c N LL c H c s •0 0 a) > ii00LL0 ii000 0E- 2 F- 2 F 2 2 0Ua c°nci <0a '>ao 2 a m co o v 0 o m c- -) Cl) clo N 0 0 0 0 0 0 0 N N N N Z I N �, o N N N N N N N N N N N N N o J c‘ V V a V V V' V V e n N N NNNNNNN N N N E U j O` -- C C C C C C C C a) O C C C ZTo "- a) a) a) a) a) a) a) a) N Nco a) a) a) — A/ U• -c- • 2 coli o a. cn LO co co Lc-) cn co in L o U •a- 0 O Z j Ca O M M M M M M M M M coco M M M ,-- Om ~F U N N N N N N N N N t W Ce dC O O O O O O M_ O o O oO O 2 0 0 (O CO (O CO O O )n co co coco N cn co co w = -') V W Z n C < mz 0 J c. mco O 65 o 1 01'° I O O O O O O O O O G12. T co zI ....1 2 U U U U U U 0 0 0 Na) N N 0 a a) i": OI 2 J N NNNNNN 10 U) N V o 01 E JV. I U) a H 4 • o CO2 o N W _O I 1 =• O ~ p U z Z o 0 c a oI CC CC w w Q zl co Z p W a) a>) o .0 '5 > d 0 o > is is v) .y E J Cr m To c> ? y 0 c c IY cCZ c) I' it LE o) rn 0) 0) 0) 0) W W c c JJJJ y 'O OJ J C E O O o N CO ao) O. > > 0 a s 0 0E) aa)) E v v' MCC cC 2 2 2 2 2 2 U 0 to c c N O) .r M p to I 0 I• J Y y d co 0)) co O I- a) y .2 E co O O z w o W O Z N N N 2 O O O H Ca w i Iv ES \\Ud 2 ` `� \ \ \U 'al• p III W I a a —y 0 iv a) co, a o 0 0 0 0 o 0 o o 0 o d 2 I x I 0 F- J 0 H,-- w J J J J J J W J J W J r o o o in a •Unv (-M ..II nNU in CD o = O c O 1 U) (7) O y 0 O z R a lAO.I `` IIN N N �"'T c of N E 6 Z aci aci aci i II 0 0 0 0 �o 0 Ce U Cl) to v o 0 z = I° in ° ! co Cl) N ? iI a g U ,_ ,_ � EoeN p Ill cego o y E, V t w nZ > j V zw U Z 0 Ce o a I- ra Qm . c I N_ 0 J a 2 _ .7 O o 0 0 C >, E 1000 On E N (n Lr) ' / � r O V O 0 O. N I Tr $ 4 0 R N O N Z o OCI N w I _ S U Cl) 2 o ICC , A...4,1 C E -- w w Z o > '> '> 0 Cl) U w in in Eco N N N • 11 IZ CL CL CL c c c y O O O N77 7 C 0) CO MC C R Z E Ali ao p t m 0 dN d I Q E °' c 'zv > . :-.\-\\ \ g U O U >.? E a Cl) U o 0 0 1 a> O �' . c Cl) E 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday,June 04,2012 TO: Jim Regg „....77 // P.I.Supervisor if f 4711.41 v SUBJECT:Mechanical Integrity Tests ENI US OPERATING CO INC 0107-04 FROM: John Crisp NIKAITCHUQ 0107-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J-ems NON-CONFIDENTIAL Comm Well Name NIKAITCHUQ 0I07-04 API Well Number 50-029-23435-00-00 Inspector Name: John Crisp Permit Number: 210-153-0 Inspection Date: 5/22/2012 Insp Num: mitJCr120525074459 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 0107-04 ' Type Inj W iTVD 3471 •1 IA 10281721 1692 1686 • PTD 2101530 - ;Type Testi SPT';Test psi 1500 - OA 220 • 280 270 270 Interval OTHER P/F P Tubing 277 • I 277 277 277 - Notes: .9 bbl pumped for test.I arrived at the well&there was 1600 psi test pressure on the IA.I attempted to explain that they could fluid pack or even run their own test but the well should be in NOC when Inspector first observes the well pre-test.Explanation of AOGCC MIT Guidance Document followed.This well was bled from 1600 psi to 998 psi&pressure stabilized at 1028 psi for pre-test pressure. Monday,June 04,2012 Page 1 of 1 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission 1 DATE: Wednesday,May 18,2011 TO: Jim Regg P e 512_3111 P.I.Supervisor SUBJECT:Mechanical Integrity Tests ENI US OPERATING CO INC 0I07-04 FROM: Matt Herrera NIKAITCHUQ 0107-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry -W4---- NON-CONFIDENTIAL --- NON-CONFIDENTIAL Comm Well Name: NIKAITCHUQ 0I07-04 API Well Number: 50-029-23435-00-00 Inspector Name: Matt Herrera Insp Num: mitMFH110517194828 Permit Number: 210-153-0 Inspection Date: 5/17/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 10107-04 '(Type Inj. W) TVD 3471 . I IA 0 2520 • 2470 2460 2460 -1 P.T.D 2101530' TypeTest SPT Test psi 1 1500 • OA 325 400 400 390 390 Interval INITAL p� P - Tubing 439 439 439 L439 439 Notes: Initial MIT performed.Test pressure was taken to 2500 psi due to not having well schematic with packer TVD to determine minimum pressure until after test was completed. Wednesday,May 18,2011 Page 1 of 1 Page 1 of 2 Regg, James B (DOA) From: Regg, James B (DOA) -V 3 Z1 P !J 01015- 0 Sent: Monday, March 21, 2011 9:02 AMl ` 11 kii (4-c,L 1� T c7-c 4 To: Lockhart Brent Cc: DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA) Subject: RE: Pre Injection MIT-IA for Eni 0107-04 Brent- Looking over the test chart, it shows 1400psi test; MIT Form indicates 1500 psi test. Please explain. Jim Regg AOGCC 333 W.7th Avenue,Suite 100 Anchorage,AK 99501 907-793-1236 From: Regg, James B (DOA) Sent: Friday, March 18, 2011 3:49 PM To: 'Lockhart Brent' Cc: DOA AOGCC Prudhoe Bay; Brooks,phoebe L(DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA) Subject: RE: Pre Injection MIT-IA for Eni 0I07-04 Brent- Thank you for the details of the MIT. For the Commission's witnessed MIT(post initial injection; stabilized injection), the final pressure during test may not drop below the required test pressure (1500psi). Refer to Guidance Bulletin 10-002 (attached; page 2, "Test Pressure"). Do you have an updated well schematic that you could provide? Jim Regg AOGCC 333 W.7th Avenue,Suite 100 Anchorage,AK 99501 907-793-1236 From: Lockhart Brent [mailto:Brent.Lockhart@enipetroleum.com] Sent: Friday, March 18, 2011 3:09 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA) Cc: Schwartz, Guy L(DOA) Subject: Pre Injection MIT-IA for Eni 0I07-04 Jim, Please find attached the appropriate paperwork for the pre-injection MIT-IA on 0107-04. If you have any questions, please let me know Brent Lockhart Sr. Production Engineer Eni Petroleum -Alaska 907 865 3339 n inI inns I Page 2 of 2 Message for the recipient only, if received in error, please notify the sender and read http://www.eni.it/disclaimer/ 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. .1)iic4eLa O67 -OA- %----------A5 14 � 2-10153o ---...,111,0-sliviimpria, N:ti.. Jr,, ,, ,, 00011.m.";,,.. 441,41,1&%.._ W.Iiirom„,,,,„•,,,,,I1. 7=iirnAVI,007,w41,,4%•••,„ , mr%.,,, ,,, .."', w".%41: N4 '4,.* 16'ilt W/•'1° ..ws i P° 1"m..(76(T is..`Il LI a mm 4 1 ft••ft a,A WA b 4 I Nti 4,4 / ti / °I1 sl 1.1101:113=larapp,AW Poini/1.1-7=17=INAW NN‘ 010•7=MramisloraW, 0106111Ellaiiim.111M01/AI\ IOW MON=Allir 4111011014, / friiii �0/�f� 000 rearvi.14,16444V ������ o009 mii, 0°WM Rai ilk 00 011111.111/lest P�o �jilleir#1164114, � �, IG`.1+'att DECKFq ���; � tl `�` 1,�� 01.10.11.7014k 1, NI �1� Nliiu a;'' - �-'Y�i���\1111N:1�NI II lulitttk ��ItloN����.pN�� � ,� a 4VA �IIII'11II p�..'..' N�o�. ul�� /h/Nil Ma% �``Aar �\�\\H��\��\�� goo_ :� l=�SSO.�..�i//� 4///4 y .. • R) 2lc I ' MECHANICAL INTEGRITY TEST (MIT) FORM WELL NO.: 0io7-04 DATE: 3-11-1l WELL TYPE: INJECTOR i,e,: Prod, Prod NL, MI, SWI, PWI MIT TEST TYPE: IA i.e., Tbg, IA/9-5/8", OA/ 13-3/8", T x IA combo, etc. REQUIRED TEST PRESSURE: 1500 psi. Note: Please consult the PWS if there's any question @ 7224, pager 909. FLUID TYPE(S) USED TO PRESSURE TEST: DIESEL Record all Wellhead Pressures before and during Test. PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T START TIME: 1512 PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** FAIL S TUBING 110 110110 7 T IA/9-5/8" 300 1500 1445 01440 PASS OA/13-3/8" 240 24O "� 240 r ` 1 COMMENTS: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T START TIME: PRESSURES PRESSURES PRESSURES PRESSURES OR '31161" ;.I1`1 (I E (PSI) (PSI) (PSI)* (PSI)** FAIL S TUBING T IA/9-5/8" OA/13-3/8" 2 COMMENTS: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T START TIME: PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI) (PSI) FAIL S TUBING T IA/9-5/8" OA I 13-3/8" 3 COMMENTS: MISC COMMENTS: .9 BBLS INITIAL PUMPING LOST 55 PSI FIRST 15.MIN LOST 5 PSI SECOND 15 MIN. * Start the MIT over if press loss is=5%@ 15 minutes. **Repeat the MIT if press loss is= 10%@ 30 minutes. Note:Test must exhibit pressure stabilization-press loss second 15 min<50% press loss first 15 min FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. -- NOTIFY DSO OF TEST RESULTS,VOLUMES PUMPED AND STATUS OF WELL. Witness: 3f/r/( cc: PWS 6/3/00 __ _ __ . . . ? / Z Z./o -/S, 1'fpC:iAh7 CAL INTEGRITY RfliORT - FUD DA__ . : —12 51/O OPER E FIELD - .CJI Nik a ,..f"c ILA4r RIG RL'S..Sr.SZ . • YZ1 /Zola _ Val. NUMBER _..6_1". 0 7_ ر- vrtLL DATA 1.1.D 1 /2 3X5.7 .. 3qz..5 TVD ; FIT3) : LL 3'3 ?a) 3 12 ct vr) Sa.r Casing : '3 k �G :.. 23/St� a��L ? ) ; DV -3 TVD r-A- .,i cr. : '� 4 Sb0e . _5601.Mp .32_8 TvD ; _Q ? : p' Mb ,._ _______T`;D 'Ubi.^.g L .� Ptckc_- _.. M' _._.. __•DTD ; Set: at • . :ole S4:,e ® .-) andi, ; Pel-57's 401 to /Z3r3 . S,5 " .SLa?rEA L!iv6►'L- 1 Cp. riC1-I11 C `rI - PART ;1 . 7 i/ I� AnnuJ,v.. ?ri ::-..1a-____00 ss rest: ; 15 min_ ; 30 min. • r ass d C ova cn t$ • • 2 60 f., ..6„:0)... o k. .��.._. (244Ao • mf,cuirickt, IIIT .CRIT"£' - PART ?2 Cement Volumes r, Amt. L -ter • Geu_ 2 ; Cmt scat to cover perfs `-ID 81565 . _...... a,.�_,..�, .a_Tar=_ wits. . - --,.....oome.mosma, .. _ s___.-'—`...,-*f se,o� TheorecicL.l TOC a1L2_t N+D w so7• IT Sarum t!l Cement Bond Log (.s or No), y"--3—L_,; In. AOGCC File ' CBL cva1uLtion, :.one above perfs ___,_42±÷,...__..-t-- l.ra-____ _6-v--9 • ._yo C- Ate- ;,,....,,,,..2....._3_,-. 2... n,,i. O2 /..e... ..-e Production Log: Type 00 ; Evalu&tion id '0t'Q - CONCLUSIONS _X,.,„...„„ Gri''''::-.) 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C ap � > L. -0 LO, 7 OC\ ,- -o n 1:1 re w CD O - V 1 1 = N Cr) N LL , \ L I_ co Ce i a O7 r" = CV O 00 c-- N Q C N CD STATE OF ALASKA RECEiVED • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND La$$ ?ons20�� 1a.Well Status: Oil❑ Gas 111Plugged ElAbandoned ❑ Suspended ❑ 1b.Wel aVii�{ 20AAC 25.105 20AAC 25.110 Development •(oratory[ On GINJD WINJ0 WDSPL❑ WAG❑ Other No.of Completions: Service ❑ Straligr-:r'I ggst❑ 2. Operator Name: 5. Date Comp.,Susp.,or 12. Permit to Drill Number: ENI US Operating Co Inc Aband.: 1/21/2011 • 210-153 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Suite 300,Anchorage AK 99503 12/29/2010 • 50-029-23435-00-00 4a. Location of Well(Governmental Section): 7. Date TD R hed: 14.Well Name and Number: Surface: 3201.2 FSL 1568.9 FEL S5 T13N R9E UM • 1/1 11 1.13 ZDI 4 yijf 1(0107-04 Top of Productive Horizon: 8. (ft above MSL): 3.2 15. Field/Pool(s): 863 FSL 381 FEL 32 T14N R9EUM Ground(ft MSL): 12 Nikaitchuq Mi.rI¢Y'8A4i Total Depth: 9. Plug Back Depth(MD+TVD): Oa P00(,n(�o. 2290 FSL 302 FEL 29 T14N R9EUM 12325 MD/3925 TVD / y.2s•// 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 6036554.42• y- 516711.03 • Zone- 4 .12325 MD/3925 TVD • ADL 355024,373301,390616 TPI: x- 6039497.97 y- 517883.55 Zone- 4 11. SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 6046204.92 y- 517927.00 Zone- 4 none ADL 417493 18. Directional Survey: Yes ❑ No ❑ 19.Water Depth, if Offshore: 20.Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1783 . 21. Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES/Sonic. 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 20" 178.89 X-65 SURFACE 150 SURFACE 150 30 Cement to Surface 13-3/8" 68 L-80 SURFACE 2315 SURFACE 2192 16 495 bbls 10.7#ASL,81 bbls 12.5#Crete 9-5/8" 47 L-80 SURFACE 5601 SURFACE 3678 12.25 252 bbls 12.5#Deeperete 5.5" 17 L-80 5372 12313 3563 3924 8.5 slotted liner 23. Open to production or injection? Yes El No If Yes, list each 24. TUBING RECORD interval open(MD+TVD of Top&Bottom; Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD) slotted liner with 3-1/2"inner string inside for water 4.5/3.5 12085 4305 injection distribution. MITIA to 2500 PSI. 25. ACID, FRACTURE,CEMENT SQUEEZE, ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: NA NA Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate 27. CORE DATA Conventional Core(s)Acquired? Yes❑ No 0 . Sidewall Cores Acquired? Yes ❑ No El • 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. GO:4P.LEi IGt ?/ i 1441 I RBDMS MAR 012011 1-orm 1U-4U/ Kevisea 1/NU/ CONTINUED ON KtvtN5E 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form, if Permafrost-Top surf surf needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1846 1783 OA sand top 5531 3671 Formation at total depth: OA sand 12325 3924 30. List of Attachments: Summary of Daily ops, Directional survey,wellbore schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Brink @ 907-865-3321 Printed Name: Js_f\on Brink Title: Senior Drilling Engineer // Signature: ,k1/1:1A-- (lap., Phone: Date: ?/a �/ INSTRUCTIONS IITIA to 2500 PSI. 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 Item 1 a: 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 prod 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 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 in Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump, Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: 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 29: 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. 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Q o N(A(ANNNN 0) LL tit-5151515Z U y m rp t))• 111 1�I C O W c9FIM P W Z ZO O ml.:cacci Aadadad > mmmmmmmmmm t 2 N y 0 p �pp pm p 0 N op fC 8EQSPE'48N0 FCRmOAOENNO Of0N1p..OpVwp�V ONN CI)0 W OAWww NNNN 2 QONO N)0 VNM N N N N ui m o ..E—8 8p N N 8 I I U) .J 0 O E `"O 7 M f� N N lT `LL O AN Ot��tOtfp�p�V N .O. 0 022 Q m N N N N d `o I- W2 c d i 7 P [ ,. 1011* Eni E&P Division (Well Name:0107-04 Eni US Operating Co Daily Report Well Code:25118 Inc Field Name:Nikatchuq • APIIUWI:50-029-23435-00-00 2^ Date:12/25/2010 - Report#: 1 li i' page 1 of 1 Wellbore name: 0107-04 Well Header PermittConcession N° Operator ENI Share)%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 3.6.98 33.26 Rig Information Ill Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12400.0 12,165.00 83.51 145.7 --- -3.77 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 0.0 81.0 Daily summary operation 24h Summary Freeze protect well with 360 bbls diesel.N/D BOP.N/U tree,Test tree and tubing hanger void to 5.000 psi 10 minutes-good.Prepare rig to move to slot#7. Operation at 07.00 24h Forecast Skid to slot#7 R/U,install Vetco starter head,drilling riser.flowline&seal off well bay/cellar area.P/U 5"drill pipe. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 12:00 00.00 12.00 12.00 MOB A 2 P Finish cleaning and flushing active&raw pits with fresh water.Rig down and prep for move.Blow down mud lines and centrifugal pumps&lines,disconnect service lines.swap power on utility to 353 genset,disconnect electrical lines,blow down steam and water lines,disconnect inner-connects.Jack up utility module and set on crib blocks,move utility module to the East,jack up sub module and set on crib blocks,move sub module to the West.Remove ng mats&old liner,lay new liner and mats.prep to move and spot sub module over#0107-04. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.Ddg.Spvr. 907-685-1227 907-440-0606 Drilling Supt. Scott Beauchamp Eni Petroleum Sr.Ddg.Spin. Scott.Beauchamp@enipetroleum.com 907-670-8623 907-841-8759 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) ill ffil* Eni E&P Division (Well Name:0107-04 Eni US Operating Co Daily Report Well Code:25118 Inc Field Name:Nikatchuq • API/11WI:50-029-23435-00-00 2^ Date:12/26/2010 - Report#: 2 " I' page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12.400.0 12.165.00 83,51 145.7 -2.77 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(f/hr) POB Temperature(°F) Weather Wind 0.0 81.0 _ Daily summary operation _ — Q24h Summary Spot and set ng and utility modules over 0107-04 wellbore center. R/U interconnects between same. N/U and test Vetco starter head to 500 psi. Prep mud pits for spud mud. Perform various R/U activities. Operation at 07.00 Picking up 5"drill pipe. 24h Forecast Finish sealing off well bay and cellar.P/U 5"doll pipe,mix spud mud.Finish rigging up CCB's and MI Swaco test CCB lines to 150 PSI. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 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 MOB A 2 P Spot drill module over well center&set on mats,shim&level ng.Move and mate up utility module,shim and level.Set on mats. 04:00 11:00 7.00 11.00'MOB A 2 P R/U innerconnects,put steam and air on-line throughout rig.Secure walkways/doorways.Lower cellar box and curtains. Secure Lamson curtains.Assemble mud pumps caps&valves. 11:00 15:00 4.00 15.00'MOB A 2 P N/U Vetco starter head&dolling riser.Test Vetco starter head to 500 psi 5 min. V 15:00 19:00 4.00 19.00'MOB A 2 I P Install hole fill&bleeder lines,install aluminum hatch and drip liner around riser.Install catch can and curtain around user. Rinse out mud pits,prep pits for building spud mud.Calibrate and test gas alarms. 19:00 00:00 5.00 24.00'MOB A 2 P Rig up and assist in spotting skid pan and CCBs,spot cuttings tank,thaw out cuttings tank and heat coil.Service Topdnve crown and block shieves.drawworks.Load drill pipe into shed(6000')strap and dolt same.Calibrate Canrig block height. Hang ng tongs,install elevators.install mouse hole in rotary table to pick up drill pipe and rack in derrick.Prep ng floor to pick up doll pipe. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Dolling Supt. Frank Cormier Eni Petroleum -Sr.Ddg.Spvr. 907-685-1227 907-440-0806 Dolling Supt. Scott Beauchamp Eni Petroleum Sr.Ddg.Spvr. Scott.Beauchamp@enipetroleum.com 907-670-8623 907-841-8759 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(f1KB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) IP* Eni E&P Division I Well Name:0107-04 Eni US Operating Co Daily Report Well Code:25118 Inc Field Name:Nikatchuq •2^n Date:12127/2010 - Report#: 3 API/UWI:50-029-23435-00-00 'l II ii page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.1.2 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA_ ____ NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth)TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12.400.0 12,165.00 83.51 145.7 -1.77 Daily Information — End Depth)RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours)hr) Avg ROP(ft/hr) FOB ._._ Temperature(°F) Weather Wind 0.0 81.0 Daily summary operation 24h Summary FINISH LOADING AND STRAPPING 5"DRILL PIPE IN PIPESHED.6000'(63 STANDS)PICK UP DRILL PIPE AND RACK BACK IN DERRICK.CONTINUE TO BUILD SPUD MUD 690 BBLS 8.7+PPG/ 100 VISC.MI.CONTINUE RIG UP CCB&LINES.LOAD 57 JOINTS 13-3/8"CASING INTO PIPESHED.LOAD BHA INTO PIPESHED.PREP RIG FLOOR FOR BHA. Operation at 07.00 RIGGING UP CCB&LINES,CLEANING OUT SLOP TANK AND THAWING OUT RAW MUD TANKS. EXTREME COLD TEMPERATURES MAKING ALL TASKS DIFFICULT. TEMP RANGE 45 TO 55 • BELOW ZERO. 24h Forecast -- - - - FINISH RIG UP CCB&LINES,TEST LINES TO 150 PSI,FINISH CLEANING OUT SLOP TANK.MAKE UP BHA#1 CLEAN-OUT ASSEMBLY(BIT,MUD MOTOR,X-OVER,STAND HWDP). CIRCULATE CONDUCTOR&CHECK FOR LEAKS,CLEAN OUT CONDUCTOR TO+160'CIRCULATE HOLE CLEAN,POOH AND RACK BACK HWDP,MAKE UP DIRECTIONAL.HOLD PRE-SPUD MEETING,SURFACE TEST DIRECTIONAL TOOLS,SPUD WELL AND DRILL SURFACE. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 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 MOB A '2 P FINISH LOADING IN 5"DRILL PIPE TO PIPESHED,STRAP&TALLY SAME. • 0200 12:00 10.00 12.00 MOB A *2 P PICK UP 5"DRILL PIPE AND RACK BACK IN DERRICK(DRIFTED).MIX 300 BBLS SPUD MUD.LOAD IN&STRAP 14 JOINTS 5"HWDP&JAR. 1200 -14:00 2.00 14.00 MOB A 2 P CONTINUE PICK UP 5"DRILL PIPE AND RACK BACK IN DERRICK(63 TOTAL STANDS)TAGGED BOTTOM AT 103' 1400 20:30 6.50 20.50 MOB A -2 P FINISH MIXING SPUD MUD 690 BBLS TOTAL 8.7+PPG,CONTINUE THAW OUT SLOP TANK,LOAD 57 JOINTS 13- t/ 3/8"CASING INTO SHED,LOAD IN BHA,PREP RIG FLOOR FOR BHA. 20:30 00:00 3.50 24.00 MOB A *2 P MI CONTINUE RIG UP CCB&LINES,RIG ELECTRICIAN TROUBLESHOOT CCB PLUG IN,REPAIR BLOWER ON#4 SCR,PICK UP&STAND BACK HWDP IN DERRICK,PICK UP BHA TOOLS TO RIG FLOOR. Daily Contacts Position Contact Name • Company Title E-mail Office Mobile Drilling Supt. Frank Cormier *Eni Petroleum 'Sr.Drig.Spvr. 907-685-1227 907-440-0806 Drilling Supt. Scott Beauchamp Eni Petroleum •Sr.DrIg.Spvr. Scott.Beauchamp@enipetroleum.com 907-670-8623 907-841-8759 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Michael Seward Eni Petroleum Project Advisor Eni representative Dan Lee Eni Petroleum Materials Coordinate 907-685-1226 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date Last Leakoff Test Depth)ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) Eni E&P Division I Well Name:0107-04 Off* Eni US Operating Co Daily Report Well Code:25118 Inc Field Name: Nikatchuq • • APIIUW1:50-029-23435-00-00 2^ Date:12/28/2010 - Report#: 4 II i page 1 of 1 wellbore name: 0107-04 Well Header PermiVConcession N° Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Dale Target Depth(f1KB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12,400.0 12,165.00 83.51 145.7 -0.77 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(oF) Weather Wind 0.0 90.0 -47.0 Ice Fog.WC-66 270`W @ 4.6 mph Daily summary operation 24h Summary Continue cleaning out cuttings slop tank with hot water and super-sucker trucks,build new steam loop in cuttings tank-OK.Pick up mud motor and make up Hughes MX1 tricone bit,fill stack and circulate across top of hole and check for leaks-OK.MI continue ng up CCBs and lines.work on heat tracing for lines.Cut and slip 75'of drilling line.Calibrate Canrig and Schlumberger block height.Work on 13- 3/8"casing in pipeshed removing protectors,drifting and tally same.EXTREME COLD TEMPRATURES OF-50'/-43"BELOW ZERO,MAKING ALL TASKS DIFFICULT.WAIT ON AMBIENT TEMPRATURE TO WARM UP TO-40"BELOW ZERO BEFORE SPUDDING WELL. Operation at 07.00 EXTREME COLD TEMPRATURES OF-50'/-43'BELOW ZERO.MAKING ALL TASKS DIFFICULT.WAIT ON AMBIENT TEMPRATURE TO WARM UP TO-40' BELOW ZERO BEFORE SPUDDING WELL. 24h Forecast Finish heat tracing on CCB lines,test CCB lines to 150 PSI,finish tally&drift 13-3/8"casing in pipeshed,wait for ambient temperature to come down to-40 below zero before spudding.EXTREME COLD TEMPRATURES OF-50`/-43`BELOW ZERO.MAKING ALL TASKS DIFFICULT.WAIT ON AMBIENT TEMPRATURE TO WARM UP TO-40'BELOW ZERO BEFORE SPUDDING WELL. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 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 MOB A 1 P Pic up lift subs,stabilizers and stage on rig floor.Pick up stand of monel drill collars and rack back in derrick.Continue rig up CCBs,and work on heat tracing. 02.00 06.00 4.00 6.00 MOB A 1 P Finish berming and securing CCB modules.Offload hot 160`water into cuttings slop tank and thaw-out same,suck out with super-sucker trucks and haul over to ENI WIF and unload.Load in 100 bbls hot 160'water to raw pits and thaw out ice, suck out same.Continue ng up CCB lines,and work on heat tracing. 06.00 07.30 1.50 7.50 MOB -A 1 P Pick up mud motor and make up 16"Hughes MX1 tricone bit,x-over,and hwdp.Continue rig up CCB lines,and work on heat tracing. 07:30 09:00 1.50 9.00 MOB A 1 P Continue work on cuttings slop tank,add hot water and super-sucker suck out thawed cuttings.Check out vents to all rig tanks&deice same.Secure curtains around lampsons.Continue rig up CCB lines and work on heat tracing. 09:00 12:00 3.00 12.00 MOB A 1 P Fill hole with spud mud.check for leaks-OK,circulate across top of hole-No leaks.Continue thawing cuttings slop tank.and V suck out thawed cuttings with super-sucker trucks.Continue rig up CCB lines and hook up heat tracing. 12:00 16:00 4.00 16.00 MOB A 1 P Continue to thaw out cuttings slop tank and suck out cuttings with super-sucker trucks-OK empty.Work on finishing up ng up CCBs,and work on heat tracing,hook up air.Schlumberger calibrate block height. 16:00 18:00 2,00 18.00 MOB A 1 P PJSM-Cut and slip 75'of dolling line. 18-00 21-00 3.00 21.00 MOB A 1 P Continue rig up CCBs,install new steam loop into cuttings slop tank,calibrate Canrig&Schlumberger block height.Work on 13-3/8"casing in pipeshed taking off protectors,drifting and strapping same. 21:00 00-00 3.00 24.00 MOB A 1 P MI Swaco Continue rig up CCBs,Clean out suctions on mud pumps,change oil in#1 genset,replace bad hoses on vac system.change out jerk lines on drawworks catheads. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum 'Sr.Ddg.Spvr. 907-685-1227 907-440-0806 Drilling Supt. Scott Beauchamp Eni Petroleum Sr.Ddg.Spvr. Scott.Beauchamp@enipetroleum.com 907-670-8623 907-841-8759 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Michael Seward Eni Petroleum Project Advisor Eni representative Dan Lee Eni Petroleum Materials Coordinato 907-685-1226 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) • $1* Eni E&P Division I Well Name:0107-04 Eni US Operating Co Daily Report Well Code:25118 Inc Field Name:Nikatchuq • API/UWI:50-029-23435-00-00 2^ Date:12/29/2010 - Report#: 5 i i page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(it) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12,400.0 12,165.00 83.51 145.7 0.23 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 505.0 505.0 345.00 2.67 129.2 89.0 Daily summary operation 24h Summary Finish heat tracing on CCB lines,test CCB lines to 150 PSI.finish tally&drift 13-3/8"casing in pipeshed,wait for ambient temperature to come down to-40 below zero before spudding.EXTREME COLD TEMPRATURES OF-50'/-43'BELOW ZERO.MAKING ALL TASKS DIFFICULT.WAIT ON AMBIENT TEMPRATURE TO WARM UP TO-40°BELOW ZERO BEFORE SPUDDING WELL.MAKE UP CLEAN-OUT ASSEMBLY AND CLEAN OUT CONDUCTOR TO 160'CBU,POOH RACK BACK HWDP.WAIT ON EXTREME COLD WEATHER.MAKE UP DIRECTIONAL BHA,DRILL FROM 160'TO 505' Operation at 07.00 DIRECTIONAL DRILLING AHEAD 24h Forecast DIRECTIONAL DRILL AHEAD FROM 505' Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 8.80 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 MOB A 1 U STAND BY WAITING ON EXTREME COLD WEATHER TO BREAK-43'BELOW ZERO.CONTINUE WORK ON CCB HEAT TRACING&GEN SET AT WIF. 04.30 06:30 2.00 6.50 MOB E 28 P PICK UP MUD MOTOR&MAKE UP BIT,MAKE UP X-OVER&HWDP-CLEAN OUT CONDUCTOR FROM 56'TO 160' GPM=450,WOB=2K-5K,RPM=25,PU=51K,50=51K,ROT=5IK,TQ=900,PS1=500,CBU AND POH. 06.30 12:00 5.50 12.00 MOB A 1 U CONTINUE TO WAIT ON EXTREME COLD WEATHER-42°BELOW ZERO.WORK ON CASING IN PIPESHED,MISC. ITEMS,WORK ON HEAT TRACING FOR CCB LINES. 12.00 15:30 3.50 15.50 MOB A 1 U CONTINUE WORK ON CCB LINE HEAT TRACING-OK.FINISH DRIFTING&STRAPPING 13-3/8"CASING IN PIPESHED.WORK ON CCB CONTAINMENT-OK.REPAIR GENSET AT WIF.PRE-SPUD MEETING WITH ALL PERSONNEL. 15:30 17:30 2.00 17,50 DRILL E 4 P PICK UP BHA#2 AND MAKE UP DIRECTIONAL TOOLS. 17.30 18:30 1.00 18.50 DRILL E 12 P CIRCULATE&CONDITION,CHECK ALL CIRCULATING EQUIPMENT,BRING ON MUD PUMPS,SHALLOW TEST ✓ DIRECTIONAL TOOLS-OK.TAKE GYROPULSE SURVEY-OK. 18.30 00:00 5.50 24.00 DRILL E 3 P DIRECTIONAL DRILL AHEAD FROM 160'TO 505'PU WT=80K,SO WT=80K,ROT WT=80K,RPM=40,TO ON=2200,TQ OFF=1700,GPM=570,WOB=10K-30K,ECD=9.05,PSI ON=690,PSI OFF=550,DIFFERENTIAL PS1=140. GYROPULSE SURVEY BEFORE CONNECTIONS. Daily Contacts • Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.DrIg.Spvr. 907-685-1227 907-440-0806 Dulling Supt. Scott Beauchamp Eni Petroleum Sr.Ddg.Spvr. Scott.Beauchamp©enipetroleum.com 907-670-8623 907-841-8759 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Dan Lee Eni Petroleum Materials Coordinato 907-685-1226 Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) Eni E&P Division I Well Name:0107-04 Eni US Operating Co Daily Report Well Code:25118 IncField Name: Nikatchuq • APIIUWI:50-029-23435-00-00 MI* 2^�I II • Date:12/30/2010 - Report#: 6 II npage 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12,400.0 12,165.00 83.51 145.7 1.23 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 1.849.0 1,785.8 1.344.00 13.10 102.6 93.0 -24.5 CLEAR,WINTER 55`NE @ 6.7 MPH COLD,WC-40 Daily summary operation 24h Summary DIRECTIONAL DRILL AHEAD FROM 505'TO 1849' @20:30 HOURS THE TOPDRIVE ENCODER MALFUNCTIONED AND WAS TORQING UP.POOH&RACK BACK 2 STANDS, FROM 1849'TO 1735'INSTALLED HEAD-PIN&HOSE.CIRCULATED HOLE WITH 100 GPM,140 PSI,OCCASIONALLY WORKING PIPE.RIG ELECTRICIAN CHANGE OUT DECODER ON TDS&TEST SAME-OK. R/D HEAD-PIN&HOSE,BLOW DOWN SAME,RIH TO 1835'WASH/REAM WITH DRILLING PARAMETERS TO BTM.@1849' Operation at 07.00 BACKREAMING OUT OF HOLE,DEPTH @ 0400 HOURS 2184'MD 24h Forecast FINISH DIRECTIONAL DRILLING SURFACE HOLE SECTION TO 2290'MD,PUMP SWEEP&CBU UNTIL CLEAN.BACKREAM OUT OF HOLE FROM 2290'MD,TO HWDP.CBU AGAIN UNTIL CLEAN WHILE SLOWLY RAISING STRING,POOH&LID BHA.RIG UP&RUN 13-3/8"CASING,CEMENT SAME. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.10 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 1200 1200 12,00 DRILL E 3 P Directional Drill ahead rotating and sliding from 505'to 1185'gpm=550 rpm=40,tq on=3500,tq off=1000,psi on btm= 750,psi off btm=700.differential psi=50,web=15k-25k,spm=120,up wt=85k,do wt=85k,rot wl=85k,gyro survey every connection. ADT=7.87 hrs/AST=5.1 hrs/ART=2.73 hrs 12.00 20:30 8.50 20,50 DRILL A 3 P Directional Drill ahead rotating and sliding from 1185'to 1849'gpm=635,rpm=40,tq on=5000,tq off=3000,psi on btm= 1225,psi off btm=1110,differential psi=115,web=10k-30k,up wt=105k,do wl=100k,rot wt=100k.gyro survey every connection.All slide drilling done with 20L toolface.Mud wl=9.3 ppg,vis=157,ECD=9.89 ADT=5.23 hrs/AST=2.60 hrs/ART=2.63 hrs 20.30 00.00 3.50 24,00 DRILL E 25 U Topdrive Encoder malfunctioned-Torqing up,had to use Torque boost to break out of stand right after connection.Rack back stand.Pulled out of hole 2 stands from 1849'to 1738'installed head-pin&circulating hose,circulate at 100 gpm with 140 psi,occasionally moving pipe.Rig electrician change out encoder,test topdrive-OK.Rig down head-pin&circulating tfl hose,blow down same.Run back in hole from 1735'to 1835'wash/ream from 1835'to btm.@1849'with drilling parameters. Daily Contacts Position Contact Name Company _ Title E-mail Office Mobile Dolling Supt. Frank Cormier Eni Petroleum Sr.Dug.Spvr. 907-685-1227 '907-440-0806 Drilling Supt. Scott Beauchamp Eni Petroleum Sr.Ddg.Spvr. Scott.Beauchamp@enipetroleum.com 907-670-8623 907-841-8759 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Dan Lee Eni Petroleum Materials Coordinate 907-685-1226 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) f Iffif* Eni E&P Division I Well Name:0107-04 Eni US Operating Co Daily Report Well Code:25118 • Inc Field Name:Nikatchuq 2^,t Date:12/3112010 - Report#: 7 ii API/UWI:50-029-23435-00-00 ti II page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share W.) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) r. 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(fUhr) DFS(days) 0107-04 DRILLING 12/29/2010 12.400.0 12,165.00 83.51 145.7 2.23 Daily Information End Depth(ftKB) End Depth(TVD)(L. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,330.0 2,203.3 481.00 3.32 144.9 91.0 -15.7 Partly Cloudy,WC- 55"NE @ 2.2 mph 22.2" Daily summary operation 24h Summary Finish directional dnlling surface hole section to 2330'\Pump sweep&CBU(3x)until clean\Back ream out of hole 1/2330'-1/585'@ HWDP\CBU until clean(reciprocate sting)\Continue POOH 8 LID SLB BHA\Perform dummy run w/13 3/8"hanger\R/U&run 13 3/8"csg. Operation at 07.00 Run 13 3/8"csg.68#L-80 BTC\Break circulation @ 1860'with no problems-2.3 bpm @ 210 psi. 24h Forecast Run 13 3/8"surface casing 68#L-80 BTC\Circulate and condition mud for cement job-L/D GBR Franks tool&R/U Schlumberger cement head&lines./PJSM and Schlumberger pump cement& displace with mud pumps./N/D drilling raiser&N/U 13 5/8"BOP stack&test-Bob Noble with AOGCC waived witness of test on 12/31/2010 @ 1725 hrs. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.10 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 DRILL E 3 P Drill Slide/Rotate(/1849'-1/2185'(Slide as needed for directional)\pump rate 650 gpm with 1200 psi./40 RPM @ 3-4K ft/lbs torque\WOB 15-25K\Up w1 105K-Dn wt.100K-Rot w1.100K./Back ream&wash 30'up/down before connection. 04:30 07:00 2.50 7.00 DRILL E 25 XR04 Rig Downtime-Top Drive encoder failure-circulated thought 2"hose with rate of 2 bpm @ 140 psi.-while electrician changed out. 07.00 09:00 2.00 9.00 DRILL E 3 P Drill Slide/Rotate 1/2185'-02330'TD for surface-pump rate 650 gpm @ 1250 psi.\40 RPM @ 3-5K ft/lbs torque 1 WOB 20- /1�1 30K\Up wt 110K-Dn wt.103K-Rot vA.105K./Back ream 30'up/down before connection.\9.1 ppg Mud wt.\ECD=9.92 X11 �/ (' ppg @ 2206 TVD. L Total ADT=19.09 hrs. ! """��� Total AST=9.71 hrs. J Total ART=9.38 hrs. Total Jar=19.09 hrs. 09:00 11:00 2.00 11.00 DRILL E 7 P Circulate bottoms-up(3x)until clean(Pumped 40 bbls.Hi-vis sweep)-reciprocated string with pump rate @ 650 gpm with 1170 psi.\40 RPM @ 2.8K torque. 11:00 17:00 ' 6.00 17.00 DRILL E 4 P Back ream(/2330'-0585'pump rate @ 635 gpm @ 1050 psi.\40 RPM @ 2.5-4.5K torque./with no problems. 17:00 17.30 0.50 17.50 DRILL E 7 P Circulate until clean-pump rate 600 gpm @ 720 psi.\Reciprocated string to the high side f/585'-0500'.Called AOGCC for up coming BOP test @ 1715 hrs.left a message-Bob Noble retumed call @ 1725 hrs.and waived witness of test. 17:30 21 00 3.50 21.00 DRILL E 4 P POOH on elevators f/585'-1/124'\L/D Schlumberger BHA assembly#2-down load data&remove Gyro Data from collar./ Clean&clear floor 21:00 21 30 0.50 21.50 DRILL G 1 P Perform dummy run with 13 3/8"csg.hanger on landing with Vetco Gray-good. 21:30 00.00 2.50 24.00 DRILL G 1 P Held PJSM with GBR to R/U 13 3/8"casing equipment&Franks tool./P/U first joint of 13 3/8"csg.68#L-80 BTC with shoe. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.Ddg.Spvr. 907-685-1227 907-440-0806 Dolling Supt. David Smith Eni Petroleum Ddg.Spvr. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Dan Lee Eni Petroleum Materials Coordinate 907-685-1226 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date Last Leakoff Test Depth(11KB) TVD(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) ffi* Eni E&P Division (Well Name:0107-04 • Eni US Operating Co Daily Report Well Code:25118 Inc Field Name: Nikatchuq •2^,fDate: - Report APIIUWI:50-029-23435-00-00 1/1/2011 8 Rt# If II page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12,400.0 12,165.00 83.51 145.7 3.23 Daily Information End Depth(ftKB) End Depth(TVD)(1..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2,330.0 2,203.3 0.00 88.0 -11.0 Blowing Snow.WC- 45"NE @ 33 mph 36.3' Daily summary operation 24h Summary -- P/U 13 3/8'684 L-80 BTC csg.f/40'-112315'\Circulate&condition mud for cement job.\Schlumberger pumped 100 bbls Mudpush-495 bbls.Lead slurry 10.7 ppg-81 bbls.Tail slurry @ 12.5 ppg.\Bump plug&cement in place @ 1215 hrs.-total on 264 bbls.back to surface.\R/D SLB cement/GBR equipment I UD landing joint&flush stack\N/U Vetco Gray Multi-bowl,riser and BOP stack./R/U and performed dummy run to set emergency slip with Vetco Gray rep.-Seat BOP stack&nser back down on well head./Clean pits. Operation at 07.00 N/U BOP-Flow&choke lines,install flow line and Ketch Kan on bell nipple./Clean active pits. 24h Forecast Finish N/U 13 5/8"BOP stack./R/U and test to AOGCC requirement 250 psi.Low/3500 psi.High-(Bob Noble with AOGCC waived witness).P/U BHA#3 to drill Intermediate section as per well plan.\ RIH above shoe track&test csg to 2500 psi for 30 mins.(chart)/Drill out shoe track&20'=new hole./Perform LOT/FIT on 13.3/8"csg.shoe.12 ppg EMW.\Perform PWD baseline test./Drill ahead. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 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 G 4 P Held PJSM\P/U 13 3/8"csg,688 L-80 BTC surface casing 840'-1/2315'1 Up wt.=175K-Dn wt.=105K\Check flow equipment\Fill every joint with Franks tool and break circulation @ 1880'with 84 gpm @ 230 psi./Centralizers per well plan\f/1175'-111400'string was taken weight-P/U string with no problem braking over,work down through sections./P/U landing joint&18.19 x 13 3/8"MB 247 mandrel casing hanger./Proper fluid displacement. 05:00 07:00 2.00 7.00 DRILL G 7 P Break circulation with GBR Franks Took Stage rate to 212 gpm @ 160 psi./Reciprocate while condition mud for cement job./Up wt.=170K-Dn wt.150K\ENI rep.witness loading of plugs into SLB cement head./No fluid losses. 07:00 08:00 1.00 8.00 DRILL H 5 P R/D GBR Franks tool-blow down Top Drive./R/U Schlumberger cement head&lines. 08:00 12.30 4.50 12.50 DRILL H 7 P Hold PJSM w/all personnel involved with cement job.SLB pump 5 bbls H2O&test lines to 4000/psi-OK\SLB pump 100 ../..bbls Mudpush II @ 10.1 ppg.-Pump rate of 5.2 bpm @ 380 psi./Shut-down drop bottom plug.\SLB mix&pump Lead M t slurry 495 bbls.@ 10.7 ppg.\Class A\1174 sks.[2.33 Yield.mix water at 10.367 gal/ski-Pump rate of 5.1 bpm @ 470 G psi./SLB mix and pump Tail slurry 81 bbls.@ 12.5 ppg.\Class A\319 sks.[1.54 Yield,mix H2O at 5.177 gal/sk.1-Pump rate of 3.8 bpm @ 328 psi./Shut down&drop top plug-SLB pump 10 bbls H2O and wash up./Displace with 321 bbls.@ 9.3 ppg mud with ng pump at 6.5 bpm w/580 psi,at 309 bbls away slow pump to 3.5 bpm with 350/psi.FCP\Bump plug to 500/psi,over FCP to 850/psi.-Hold for 5 minutes and bleed off-check floats are holding-Good./Cement in place @ 1215 hrs.with a total of 264 bbls.cement returns to surface. 12:30 15:00 2.50 15.00 DRILL H 5 P Rig down SLB cement lines.\R/D GBR csg.elevators./Rise out&lay down landing joint.\Flush out drill riser and flow line with 50 bbls.retarder pill\L/D GBR equipment off rig floor.Transfer mud to WIF for injection. 15:00 18:00 3.00 18.00 DRILL E 5 P N/D dnlling riser and Vetco Gray start head./Pit cleaning. 18:00 22.00 4.00 22.00 DRILL E 5 P N/U Vetco Gray Multi-bowl and well head valves with Vetco Gray Rep.\Test seals to 5000 psi for 10 minutes.\N/U nser and stack-install bell nipple.Cleaning rig pits&prep for new mud. 22:00 00.00 2.00 24.00 DRILL E 5 P R/U lifting ram cylinders for picking-up BOP stack.\Perform dummy run on emergency slip procedure-confirmed 27" • clearance between riser and well head for slip installation,also measure length for secondary safety cables/Lower BOP stack back down.Cleaning active pit&shakers, Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.Ddg.Spur. 907-685-1227 907-440-0806 Drilling Supt. David Smith Eni Petroleum DrIg.Spur. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Dan Lee Eni Petroleum Materials Coordinato 907-685-1226 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 0.0 2,315.1 1/1/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) Eni E&P Division [Well Name:0107-04 011111* Eni US Operating Co Daily Report Well Code:25118 Inc Field Name:Nikatchuq • API/UWI:50-029-23435-00-00 2�II II, Date:1/2/2011 - Report#: 9 page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL RotaryTable Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12,400.0 12,165.00 83.51 145.7 4.23 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) 'Drilling Hours)hr) Avg ROP(ft/hr) FOB Temperature(°F) Weather Wind 2.330.0 2,203.3 0.00 98.0 -2.0 Cloudy,Light Blowing 90`E @ 30 mph Snow WC-27° Daily summary operation 24h Summary Finish N/U 13 5/8"BOP stack./R/U to test BOPE\Waiting on weather,Phase 3 condition and suspended rig operation.Test BOPE to AOGCC requirement 250 psi.Low/3500 psi.High-(Bob Noble with AOGCC waived witness). Operation at 07.00 P/U BHA#3 and off load and building new LSND mud system. 24h Forecast Finishing testing BOPE(bottom rams.accum test&blinds).\R/D test equipment and install wear bushing.\P/U BHA#3&ghost reamer for intermediate hole section./RIH to above float equipment&test surface casing to 2500 psi for 30 mins.(chart record)\Drill out shoe track&20'new hole(2350')./Displace hole to new LSND mud./Perform LOT/FIT on 13 3/8"csg.shoe./Perform PWD baseline test./ Drill ahead as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9,30 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. • 00:00 05.30 I 5.50 5.50 DRILL C 5 •P N/U BOP stack to well head and removal of one lifting cylinder-install choke&kill lines,flow line,bleeder&fill-up lines, install turn buckles-thaw out sump and install mouse hole. 05:30 06.30 1.00 6.50 DRILL E 1 .P M/U test joint and install test plug-R/U test equipment, 06:30 20.00 13.50 20.00 DRILL E 22 'XWO1 Waiting on weather Phase 3 condition called @ 0630 hrs.-Rig operation suspended./Check with security and weather condition Phase 2 @ 2000 hrs.-started ng operation. 20-00 00:00 ' 4.00 24.00 DRILL C 12 P Test BOPE to AOGCC requirements 250 psi.Low/3500 psi.High-Annular,Rams&mud cross valves,choke manifold. � floor and Top Drive valves./Chart record(5 minutes each).CH2MHILL Vac trucks on location @ 2300 hrs.with LSND • 1✓.0 concentrate mud. � • Daily Contacts `v1 Position Contact Name Company Title E-mail Office Mobile Drilling Supt. 'Frank Cormier Eni Petroleum Sr.Ddg.Spvr. 907-685-1227 907-440-0806 Drilling Supt. David Smith Eni Petroleum Ddg,Spvr. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Dan Lee Eni Petroleum Materials Coordinate 907-685-1226 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 13 3/8 12.415 L80 0.0 2.315.1 1/1/2011 Last Leakoff Test Depth(RKB) TVD(11KB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.315,0 2,191.25 Spud mud 9.30 310.0 12.02 1,368.6 Eni E&P Division I Well Name:0107-04 011* Eni US Operating Co Daily Report Well Code:25118 Inc Field Name:Nikatchuq • API/UWI:50-029-23435-00-00 2^II Date:1/3/2011 - Report#: 10 f' page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00.HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12,400.0 12,165.00 83.51 145.7 5.23 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 2.955.0 2,703.5 625.00 3.58 174.6 98.0 -2.0 Partly Cloudy.WC- 90`S @ 14 mph 20- Daily summary operation 24h Summary Finished testing BOPE to AOGCC requirement 250 psi.Low/3500 psi.High.\Pull test plug&install wear bushing.\P/U BHA#3(surface test Power Drive 5X)-finish P/U Schlumberger tool string./RIH to 2330'(tag w/8K)-POOH 8/2189'\CBU\Test 13 3/8"csg 02500 psi for 30 mins.(chart record).\Drill out shoe track&20'new hole 5/2350'\Circulate to equal mud wt.9.3 ppg.\Perform FIT to 12 ppg EMW \Displace well to new LSND mud.\Drill ahead Rotary Steerable(/2350'-$12955'as per well plan. Operation at 07.00 Drill ahead Rotary Steerable at 3,337'MD as per well plan. _ 24h Forecast Drill Rotary Steerable(/2955'as per directional of well plan.\Prep 9 5/8"csg. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 8.90 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 C 12 P Test BOPE to AOGCC requirements 250 psi.Low/3500 psi.High-Bottom rams.accum draw down test and blind rams.\ Chart record(5 minutes each). 02:00 03.00 1.00 3.00 DRILL C 1 P Pull test plug-install wear bushing(12"OD). R/D test equipment-blow down choke manifold. 03:00 04:00 1.00 4.00 DRILL E 1 P Pull Schlumberger tools(stab&sub)to rig floor-Install Katch-Kan on bell nipple @ BOP stack. • 04:00 09.00 5.00 9.00 DRILL E 4 P Held PJSM w/Schlumberger-P/U BHA#3.1 Surface test Power Drive 5X @ 94'w/pump rate 650 gpm @ 660 psi.(Visual on pad operation).Continue P/U Schlumberger tool string,RIH with 5"HWDP&DP-P/U ghost reamer.1/94'-1/1040'. 09:00 09.30 0.50 9.50 DRILL E 4 P RIH f/1040'-02230'\tagged with 8K weight/POOH 02189'. 09:30 10.00 0.50 10.00 DRILL E 7 P Circulate bottoms-up pumping 650 gpm @ 1140 psi.\25 rpm @ 34K torque.\Up wt.=110K-Dn w4.=95K-Rot vd.=102K. 10:00 11 00 1.00 11.00 DRILL E 12 P R/U and perform casing test on 13 3/8"68#L-80 to 2500 psi for 30 minutes(chart record)-Good./Blow down kill line. 11:00 14.30 3.50 14.50 DRILL E 3 P Drill float equipment&cement(/2230'-02315'-clean out 1/2315'-112330'\Pump rate @ 550 gpm @ 780 psi.\4orpm @ 4- 5K torque.\WOB=2-6K\Up wt.=115K-Dn w1=100K-Rot wt.=110K\Drilled new hole 1/2330'-1/2350'\750 gpm @ 1450 psi./50 rpm @ 3-5K torque.\WOB=5-10K.\Pull up into shoe. 14:30 15.00 0.50 15.00 DRILL E 7 P Circulate&condition mud until even mud weights in/out 9.3 ppg.\660gpm @ 1150 psi. 15:00 16:00 ' 1.00 16.00 DRILL E 12 P Perform Formation Integrity test(FP)to 12 ppg EMW. 16~ 19.00 3.00 19.00 DRILL E 7 P Change out mud system-displace well bore with new 8.9 ppg LSND mud.\Record SPR for#1 mud pumps./Down link to Schlumberger Powerdrive.\Record PWD data points.\Reduce pump rate 398 gpm @ 350 psi.\Clean pit#7 and shakers-off load new mud from Vac trucks. 1900 00.00 5.00 24.00 DRILL E 3 P Drill Rotary Steerable(/2350'-1/2955'(2706'TVD)\Pump rate 859 gpm @ 1440 psi.\140 RPM @ 4-5K ft/lbs torque\WOB 2-10K\Up wt.=126K-Dn wt.=105K-Rot wt.=115K.\Back ream 30'up/down before connection.\8.8 ppg Mud wt.\ECD= 9.31 ppg. Total ADT=3.58 hrs. Total Jar=22.68 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Drilling Supt. Frank Cormier Eni Petroleum Sr.DrIg.Spur. 907-685-1227 907-440-0806 Drilling Supt. David Smith Eni Petroleum Ddg.Spur. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 • Eni representative Dan Lee Eni Petroleum Materials Coordinato 907-685-1226 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 0.0 2,315.1 1/1/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,315.0 2,191.25 Spud mud 9.30 310.0 12.02 1,368.6 -s Eni E&P Division I Well Name:0107-04 Eni US Operating Co Daily Report Well Code:25118 Inc Field Name:Nikatchuq • 2^n Date:1/4/2011 - Report#: 11 APIIUWI:50-029-23435-00-00 illi II page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 i DRILLING 12/29/2010 12,400.0 12,165.00 83.51 145.7 6.23 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 5,157.0 3,633.0 2.202.00 17.38 126.7 100.0 -1.2 Partly Cloudy.Foggy. 165°SSE @ 1 mph WC-1.2° Daily summary operation 24h Summary Drill ahead Rotary Steerable(/2955'-1/5157'\Prep 9 5/8"csg.in pipe shed.\Tesco reps on location and checked out equipment. Operation at 07.00 Drilling rotary steerable 12 1/4"intermediate section @ 5538' 24h Forecast Drill ahead Rotary Steerable(/5157'to TD of 9 5/8"csg.\Circulate clean-rotate&reciprocate string./POOH back reaming to 13 3/8"csg.shoe @ 2315'\Circulate clean @ shoe\POOH on elevator& • L/D BHA#31 Pull wear bushing and perform dummy csg hanger run./Install test plug&change rams to 9 5/8"and test same 250 psi Low/3500 psi High./R/U Tesco to run 9 5/8"csg\P/U 9 5/8"as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) ii 9.30 Time Log Start End Cum Time Time Dur(hr) Dar(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 12.00 12.00 12.00 DRILL E 3 P Drill Rotary Steerable 62955'-1/4020'(3372'TVD)/Pump rate 855 gpm @ 1675 psi./140 RPM @ 4-5K ft/lbs torque\WOE 5-10K\Up wt.=140K-Dn wt.=108K-Rot wt.=125K.\Back ream 30'up/down before connection./8.9 ppg Mud wt.\ECD= 9.45 ppg.ADT=7.51 hrs.\Total Jar=30.19 hrs. 12.00 0000 12.00 24.00 DRILL E 3 P Drill Rotary Steerable f/4020'-1/5157'(3632'TVD)\Pump rate 850 gpm @ 2030 psi.\120 RPM @ 6-7K ft/bs torque\WOB 10-12K\Up wt.=142K-Dn wt.=100K-Rot wt.=120K./Back ream 30'up/down before connection./9.3 ppg Mud wt.\ ECD=10.01 ppg./ADT=9.3 hrs. Total ADT=20.96 hrs. Total Jam 40.04 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Drilling Supt. Frank Cormier Eni Petroleum Sr.Ddg.Spvr. '907-685-1227 907-440-0806 Drilling Supt. David Smith Eni Petroleum Ddg.Spur. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Dan Lee Eni Petroleum Materials Coordinato 907-685-1226 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 0.0 2,315.1 1/1/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2,315.0 2,191.25,Spud mud 9.30 310.0 12.02 1.368.6 Eni E&P Division I Well Name:0107-04 VII* Eni US Operating Co Daily Report Well Code:25118 Inc Field Name:Nikatchuq • APIIUWI:50-029-23435-00-00 2^r,II Date:1/5/2011 - Report#: 12 If II page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) 0107-04 DRILLING 12/29/2010 12,400.0 12,165.00 83.51 145.7 7.23 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 5,618.0 3.679.6 461.00 3.36 137.2 100.0 7.5 Cloudy,WC-9.0" 63'ENE @ 18 mph Daily summary operation 24h Summary Drill Rotary Steerable f/5157-15618'TD for 9 5/8"csg.\Circulate&condition,CBU 3X until clean-rotate&reciprocate.\POOH back reaming to shoe @ 2315'/Circulate clean @ shoe./POOH on elevator &L/D BHA#31 Pull wear bushing&install test plug./Changes top ram to 9 5/8"csg.&test to 250 psi/3500 psi.\Perform dummy csg hanger run.\R/U Tesco CDS to run 9 5/8"csg. Operation at 07.00 P/U 9 5/8"47#L-80 csg.with Tesco CDS./Floating casing string in the hole./Fill shoe track and floats checked out good. 24h Forecast Finish R/U Tesco equipment./Held PJSM with Tesco reps for Casing Drive System(CDS),discuss responses rf floats or 9 5/8"csg collapse/P/U and run 9 5/8"as per well plan.to shoe @ 5600'1 R1U and fill 9 5/8"csg with mud.\Circulate and condition for cement job./R/U Schlumberger to cement 9 5/8"csg.as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(Iblgal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 0000 05.00 5.00 5.00 DRILL E 3 P Drill Rotary Steerable(/5157'-1/5618'(3682'TVD)\Pump rate 855 gpm @ 2160 psi./120 RPM @ 6-7K fUlbs torque./WOB D 10-14K\Up wt.=138K-On wt.=95K-Rot wt.=110K./Back ream 30'up/down before connection./9.3 ppg mud wt.\ECD= L� 10.3 ppg.\ADT=3.36 hrs.\Highest gas 1322 units @ 5612'. ma()` Total ADT=24.32 hrs. Total Jar-43.40 hrs. 05.00 07:00 2.00 7.00 DRILL E 7 P Circulate&condition-until clean 3X bottoms-up-rotate&reciprocate string-rack back one stand every bottoms-up • 1/5618'-t/5348'./Rot wt.=110K./Pump rate 855 gpm @ 2120 psi./120 rpm @ 5-6K/Monitor well f/10 mins:static. 07.00 14.00 7.00 14.00 DRILL E 4 P POOH back reaming 65348'-U2315'\Pump rate 855 gpm @ 1650 psi./120 rpm @ 3-5K torque./Up wt.=135K-Dn wt.= 85K-Rot wt=120K. 14.00 15:00 1.00 15.00 DRILL E 7 P Circulate bottoms-up-clean./Pump rate 850 gpm @ 1650 psi./75 rpm @ 3K torque./Monitor well-static. 15:00 16.30 1.50 16.50 DRILL E 4 P Pump dry job./POOH on elevators f/2315'-1/223'to BHA#3./L/D ghost reamer. V// 16:30 19:00 2.50 19.00 DRILL E 4 P -L/D Schlumberger tools string with DD/MWD reps./Down load data from tools. 19:00 20.00 1.00 20.00 DRILL. E 5 P Pull wear bushing&install test plug w/9 5/8"test joint(lock screw down in).R/U to test. 20:00 21:00 1.00 21.00 DRILL G 5 P 'Clang;too rams 1/9 5/8"csp, 21:00 21:30 0.50 21.50 DRILL G 12 P Test to 250 psi Low/3500 psi.High./Chart record 5 mins.each test. 21:30 22:30 1.00 22.50 DRILL. G 1 P Pull 9 5/8"test joint&plug.\P/U landing joint/hanger and performed dummy with 9 5/8"csg.hanger verified landed by Vetco Gray rep./UD landing joint. 22:30 00.00 1.50 24.00 DRILL G 1 P Held PJSM w/Tesco reps for Casing Drive System(CDS)\P/U casing running tool-M/U to Top Drive./Load floor with equipment,centralizer,cement head and hydraulic lines. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.Dig.Spur. 907-685-1227 907-440-0806 Drilling Supt. David Smith Eni Petroleum DrIg.Spur. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Cnswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 133/8 12.415 L80 0.0 2,315.1 1/1/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Iblgal) Leak Off Pressure(psi) 2,315.0 2,191.25 Spud mud 9.30 310.0 12.02 1,368.6 011* Eni E&P Division I Well Name:0107-04 Eni US Operating Co Daily Report Well Code:25118 Inc Field Name:Nikatchuq • API/UW1:50-029-23435-00-00 2^ Date:1/612011 - Report#: 13 II II page 1 of 1 Wellbore name: 0107-04 Well Header PermitlConcession N° Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12,400.0 12,165.00 83.51 145.7 8.23 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) •Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 5.618.0 3.679.6 0.00 100.0 5.0 Cloudy,Light Snow, 225`SW @ 7 mph WC-6- Daily summary operation 24h Summary Finish R/U Tesco equipment&function test.\Held PJSM with Tesco reps for Casing Drive System(CDS)\P/U and run 9 5/8"475,L-80,BTCM casing-shoe @ 5600'\R/U-811&bleed 9 5/8"csg with mud./Circulate and condition-reciprocate string\Schlumberger pumped cement 252 bbls.Of 12.5 ppg DeepCrete cement as per well plan. Operation at 07.00 Finishing pumping cement @ 0015hrs.\Shut down&drop top plug-SLB pump 10 bbls H2O and wash up.\Displace with 394 bbls.@ 9.3 ppg mud with ng pump at 6.75 bpm w/850 psi,at 375 bbls away slow pump to 3.0 bpm with 720/psi.FCP\Bump plug to 500/psi,over FCP to 1258/psi.-Hold for 5 minutes and bleed off-Check floats are holding-Good./Cement in place @ 0124 hrs.with full return through out the cement job./Install 9 5/8'pack-off&test to 5000 psi for 10 minutes.\Freeze protect 13 3/8"x 9 5/8"annulus with 145 bbls.diesel pump rate 2.3 bpm @ 1700 psi.with shut down pressure of 925 psi. 24h Forecast Change top rams\P/U 5"drill pipe and rack in derrick\Clean pits&surface equipment./Testing BOPE.\Jeff Jones waived witness of BOP test @ @ 1725 hrs. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.30 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 G 1 P -R/U Tesco equipment and hydraulic lines\Function test system-good 01-30 02.00 0.50- 2.00 DRILL G 1 P Held PJSM w/Tesco Reps for Casing Drive System(CDS)-Review running procedure of 9 5/8"csg.1 Discussed response for float failure or 9 5/8"csg.collapse. 02.00 14.00 12.00 14.00 DRILL G 4 P P/U 9 5/8',47#,L-80,BTCM csq,with Tesco CDS make to 15K torque./Fill&test float equipment-good./Floated in casing 1/128'-1/5600'1 Install 39 Hydroform centralizers.\Check torque reading depths=1082'-10 rpm @ 800 TO/2285'- 10 rpm @ 1800 TO/3328'-10 rpm @ 2100 TQ/4320'-18 rpm @ 3300 TO/5300'-15 rpm @ 4300 TO/5532'-15 rpm @ 4400 TO/P/U Vetco Gray 9 5/8'hanger&landing out. 14:00 1530 1.50 15.50 DRILL G 1 P 'R/D Tesco CDS equipment from Top Drive./R/U Schlumberger cement head to 6119 5/8"csg.1 Blow air through choke/gas • buster to verify open. 15:30 19.00 3.50 19.00 DRILL G 7 F Fill 9 5/8"csg.w/9.3 ppg mud-start pump rate 42 gpm and increase to 106 gpm @ 30 psi. and bleeding air through choke manifold\Total pumped 415 bbls. Shut down pump intervals @ 200 bbls.-300 bbls.-350 bbls.-400 bbs.for 10 minutes to bleeder air off. pa - 19.00 20.00 1.00 20.00 DRILL G 1 P Remove Schlumberger cement-R/U on spiders on bails to work stung\Load cement head with plugs.verified by ENI& ^ U Schlumberger reps.\Install cement head&lines. `� 20.00 22.30 2.50 22.50 DRILL G 7 P •Circulate&condition mud./Stage rate to 300 gpm @ 350 psi.\Reciprocate string.\Up wl.=230K-Dn wt.=145K\Hold •PJSM w/Schlumberger personnel for cement job. 22.30 0000 1.50 24.00 DRILL H 7 P Schlumberger pump 5 bbls.H2O and test lines to 4000/psi.-0K./SLB pump 82 bbls.Mudpush II @ 10.5 ppg.-Pump rate of p 5.3 bpm @ 412 psi.\Shut-down drop bottom plug./SLB mix and pump DeepCrete slurry 252 bbls.@ 12.5 ppg.\919 sks. V [Yield=1.54 ft3/sk,mix water at 5.177 gal/sk.)-Pump rate of 4.4 bpm @ 700 psi./Reciprocate stnng Up wt.=245K-Dn v wt.=155K. Daily Contacts Position _ Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener -Eni Petroleum Sr.Dug.Spur. Jack.Keener@enipetroleum.com 907-670-8623 907-715-6434 Drilling Supt. David Smith Eni Petroleum Dug.Spvr. 907-670-8623 907-632-3058 • Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 0.0 5.600.6 1/6/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.315.0 2,191.25 Spud mud 9.30 310.0 12.02 1,368.6 Eni E&P Division 'Well Name:0107-04 I* Eni US Operating Co Daily Report Well Code:25118 Inc Field Name:Nikatchuq • API/UWI:50-029-23435-00-00 2^n Date:1/7/2011 - Report#: 14 'I I'iI page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12.400.0 12,165.00 83.51 145.7 9.23 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 5,618.0 3,679.6 0.00 99.0 -12.8 Cloudy,WC-23.6" 215'SW @ 3.9 mph Daily summary operation 24h Summary Finished 9 5/8"cement job-CIP @ 0124 hrs.\L/D landing jt.\Install 9 5/8'pack-off&test to 5000 psi for 10 minutes.\Freeze protect 13 3/8"x 9 5/8"annulus with 145 bbls.diesel.\Install wear bushing.\ Change top rams.\Load pipe shed&P/U 5"drill pipe.\Service rig&function test#3 mud pump.\POOH 112745'\P/U 5"(/2745'-1/4214'. Operation at 07.00 Testing BOPE to AOGCC requirement 3 1/2"&5 1/2"tubular size. 24h Forecast Finish P/U 5"doll pipe&clean pits/surface equipment.\Cut drilling line.\Testing BOPE to AOGCC requirements with 3 1/2" &5 1/2"tubular.\P/U BHA#4\RIH-Cement bond logging with Schlumberger Sonic LWD 1/2315'-Vfloat collar.\Test 9 5/8"csg V 3000 psi f/30 mins.(chart record)\Displace to solid free OBM.\Drill out shoe track and(+1-)20'new hole./LOT. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 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 H 7 P Finishing pumping cement @ 0015hrs.\Shut down&drop top plug-SLB pump 10 bbls H2O and wash up.\Displace with 394 bbls.@ 9.3 ppg mud with rig pump at 6.75 bpm w/850 psi,at 375 bbls away slow pump to 3.0 bpm with 720/psi.FCP\ Bump plug to 500/psi,over FCP to 1258/psi.-Hold for 5 minutes and bleed off-Check floats are holding-Good.\Cement V in place @ 0124 hrs.with full retum through out the cement job. 01:30 02.30 1.00 2.50 DRILL H 5 P R/D cement head.\UD landing joint.\Remove spiders from bails and install 5"elevators and latch-on to stand 5"drill pipe.\ Finish removing volume from active&raw mud and transfer to WIF with Vac truck for injection. 0230 03:00 ' 0.50 3.00 DRILL G 5 P Install 9 5/8"csg.pack-off in well head,test to 5000 psi for 10 minutes-good.\R/U Little Red to freeze protect 13 3/8"x 9 5/8"annulus 03:00 04:00 1.00 4.00 DRILL G 7 P Pressure test Little Red lines to 2500 psi\Start injecting diesel down 13 3/8'x 9 5/8'annulus 2.3 bpm @ 1150 psi.\Total 145 bbls.pumped with final injection pressure of 1750 psi @ 2.3 bpm\shut-in @ 925 psi.-Clear floor of cement head& equipment. 04.00 04:30 0.50 4.50 DRILL G 5 P Install wear bushing with Vetco Gray-9 1/8"ID. 04.30 05:30 1.00 5.50 DRILL G 5 P Change top rams from 9 5/8'csg to 4 1/2"x 7"variables. 05.30 11:00 5.50 11.00 DRILL E 1 U Load pipe shed with 5"drill pipe,steam&thaw out blown snow.\Clean pits&surface equipment-solid free OBM. 11 00 18:00 7.00 18.00 DRILL E 4 P P/U 5"drill pipe singles-RIH with mule shoe 115008'\Up wt.=140K-Dn Wt.=90K. 18.00 18:30 0.50 18.50 DRILL E 25 P Service rig-Top Drive,draw-works and blocks. 18.30 19:00 0.50 19.00 DRILL E 7 P Break circulation with#3 MP through bleeder to function test after rebuild with 340 gpm @ 1200 psi.-functioned-OK. 19.00 21:30 2.50 21.50 DRILL E 4 P POOH f/5008'-112745'Up wt.=100K-Dn wt.=75K. 21 30 00:00 2.50 24.00 DRILL E 4 P P/U 5"drill pipe-singles-RIH f/2745'-114214'\prep to POOH-clean floor,install stripping rubber.\R/D pipe skate opening. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener 'Eni Petroleum Sr.Ddg.Spur. 'Jack.Keener@enipetroleum.com 907-670-8623 907-715-6434 Drilling Supt. David Smith Eni Petroleum Ddg.Spur. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 0.0 5,600.6 1/6/2011 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 2.315.0 2,191.25 Spud mud 9.30 310.0 12.02 1.3686 Eni E&P DivisionEni US Operating Co I Well Na0107-04 ' Iff* Daily Report Well Code:me:25118 Inc Field Name:Nikatchuq 2^ Date:1/8/2011 - Report#: 15 API/UWI:50-029-23435-00-00 II II page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information ' Contractor Rig Name Rig Type NABORS ALASKA __ _ NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12,400.0 12,165.00 83,51 145.7 10.23 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 5,618.0 3,679.6 0.00 98.0 -12.8 Cloudy,WC-23.6' 215`SW @ 3.9 mph Daily summary operation 24h Summary POOH(/4214'-V98'\Cut drilling line.\Service ng\POOH remaining 5"DP.\Pull wear bushing-install test plug&5 1/2".1 Test BOPE with 5 1/2"&3 1/2"tubular to 250 psi.low/3500 psi.high-choke&kill valve/manifold components,Top Drive&floor valves.perform Accum test.\13 5/8"Hydril annular failure on 3500 psi.\N/D flow line&flow nipple.\Change element in Hydril annular. Operation at 07.00 Testing annular with 3 1/2"&5 1/2"tubular 250 psi low/3500 psi high. 24h Forecast Finish assembly of annular and flow nipple/line to test.\Complete testing of BOPE with 3 1/2"&5 1/2"tubular on Hydril annular to AOGCC and well plan requirements of 250 psi.low\3500 psi.high.\P/U BHA#4 w/Schlumberger DD/MWD reps.\RIH logging f/2315'-Ufloat collar with Schlumberger Sonic LWD.\Test 9 5/8"csg.47#L-80 1/3000 psi f/30 mins(chart record)\Displace to solid free OBM.\Drill out shoe track and(+/-)20'new hole.\Perform LOT/FIT. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.30 Time Log Start End Cum Time Time Dur(hr) Dur(he) Phase Opr. Act. Plan Oper.Descr. 00:00 0200 2.00 2.00 DRILL E 4 P POOH f/4214'-1/98'.\R/U to cut dnlling line. 02:00 03.00 1.00 3.00 DRILL E 25 P Slip&cut drilling line total 67'. 03:00 03.30 0.50 3.50 DRILL E 25 P Service Top Drive,draw-works,blocks,crown and rails for Top Drive. 03:30 0400 0.50 4.00 DRILL E 4 P POOH remaining 5"doll pipe&remove mule shoe. 04:00 05.30 1.50 5.50 DRILL C 1 P Remove wear bushing.\P/U 5"test joint and install test plug-Vetco Gray rep.\Fill stack&choke manifold with H2O. 0530 13.00 7.50 13.00 DRILL C 12 P Test BOPE to AOGCC requirements&as per well plan with 5 1/2"&3 1/2"tubular.\250 psi Low/3500 psi High.\ • Components tested.annular,variable rams(5 1/2"top&bottom\3 1/2"bottom).choke&kill(stand pipe)valves,choke 30 manifold,TIW and dart valves-perform accum draw-down test,good.Able to get low 250 psi test on annular with 3 1/2" r tubular,but failure accrued on high 3500 psi test.Attempt to re-test several times-Jeff Jones with AOGCC waived witness of test. 13:00 15:00 2.00 15.00 DRILL C 5 XR05 Function Hydril element on 2"pipe,pull and install 3 1/2"test joint and attempt to re-test,failed.\Pull 3 1/2"test joint,drain stack and blow down choke manifold and lines. 15:00 18:00 3.00 18.00 DRILL C 5 XR05 N/D Katch-Kan,flow line,fill-up lines and flow nipple from Hydril annular 18:00 00:00 6.00 24.00 DRILL C 25 XR05 Change-out element in Hydril annular preventer-install new element and inter seals-install cap tighten down. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Ddg.Spot. Jack.Keener@enipetroleum.cow -907-670-8623 907-715-6434 Drilling Supt. David Smith Eni Petroleum Ddg.Spvr. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Caswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(RKB) Run Date CASING 95/8 8.681 L-80 0.0 5,600.6 1/6/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 2,315.0 2,191.25 Spud mud 9.30 310.0 12.02 1,368.6 Eni E&P Division I Well Name:0107-04 Eni US Operating Co Daily Report WellCode:25118 Inc Field Name:Nikatchuq 0111* • APIIUWI:50-029-23435-00-00 2 II n,t Date:1/9/2011 - Report#: 16 II II page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12.400.0 12,165.00 83.51 145.7 11.23 Daily Information End Depth(ftKB) End Depth(TVD)(t.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 5,618.0 3,679.6 0.00 99.0 30.0 Cloudy,WC+20' 200`SSW @ 22 mph Daily summary operation 24h Summary Finishing change element in Hydril annular./N/U flow nipple&line.\Test annular with 3 1/2"&5 1/2"tubular-250 psi.low/3500 psi.high./R/U Katch-Kan on flow nipple./P/U BHA#4 to 579'and test SLB tools./RIH(/579'-5/1890'1 Circulate-SLB send down link./RIH(11890'-2300'1 RIH Schlumberger performed CBL with LWD Sonic-vision tool,f/2300'-5/5496'(tag w/6K)./POOH to 5458'.\Perform 9 5/8"csg test to 3000 psi.for 30 minutes./Bleed off&R/D. Operation at 07.00 Drilling plugs&floats @ 5511'-Pumping 508 gpm @ 1556 psi.)60 rpm @ 4.5K torque.Up w1.123K-Dn wt.91K-Rot wt.108K.1 WOB=4K. 24h Forecast Displace to 9.2 ppg OBM(FazePro)./Drill out shoe track and(+1-)30'new hole./Perform LOT/FIT./Dnll ahead as per well plan. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.10 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 5 XR05 Finish tighten Hydril cap(install locking boh)./N/U flow nipple,flow line,bleeder and fill-up lines. 02:30 06.30 4.00 6.50 DRILL C 12 P P/U 3 1/2"test joint&test plug-test to 250 psi low/3500 psi.high./Change out to 5 1/2"test joint-test to 250 psi low/3500 psi.high./Chart record all test./Pull test plug&L/D test joints. 06:30 07.00 0.50 7.00 DRILL E 5 P Install wear bushing 9 1/8"ID.with Vetco Gray Rep. 07:00 08.30 1,50 8.50 DRILL E 5 P Install Katch-Kan on flow nipple./Load floor with BHA tools. 08:30 12.00 3.50 12.00 DRILL E 4 P Calibrate blocks with Schlumberger and Canrig loggers-P/U BHA#4-Bit,Exceed,Arc,Telescope,NM Stab Sonic-vision. NM stab,Nm Flex DC,HWDP,1/579'.1 Surface test MWD-pumping 508 gpm @ 700 psi.-good. 12:00 13:00 1.00 13.00 DRILL E 4 P RIH 1/579'-1/1890' 13:00 14:00 1.00 14.00 DRILL E 7 P Break circulation pumping 550 gpm @ 1000 psi-send down link to Schlumberger tools 14:00 14:30 0.50 14.50 DRILL E 4 P RIH f/1890'-1/2300'. 14.30 22:00 7.50 22.00 DRILL E 4 P RIH while logging CBL with Schlumberger LWD Sonic-vision tool @ 900 ft./hr:(/2300'-t/5496'./Circulate down 1/4940'- U5496'-Tag with 6K./Pump rate 250 gpm @ 500 psi./POOH to 5458'. 22'.00 22:30 0.50 22.50 DRILL E 5 P R/U head pin and break circulation and fluid pack 5"drill pipe&Kill line. % 2230 23:30 1.00 23.50 DRILL E 12 P Perform 9 5/8"csg.test to 3000 psi for 30 mins.(chart record).\5 bpm rate with total 4.9 bbls.\9.4 ppg mud wt. V 23.30 00:00 0.50 24.00 DRILL E 5 P Bleed off and blow down lines of LSND.\R/D lines. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Ddg.Spur. Jack.Keener@enipetroleum.com 907-670-8623 907-715-6434 Drilling Supt. David Smith Eni Petroleum Drlg.Spvr. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 0.0 5,600.6 1/6/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5,600.6 3,678.27 FazePro OBM 9.20 840.0 13.60 2,597.9 Eni E&P Division I Well Name:0107-04 I 111* Eni US Operating Co Daily Report Well Code:25118 Inc Field Name:Nikatchuq • 2^n Date:1/10/2011 - Report#: 17 API/UWI:50-029-23435-00-00 II II II page 1 of 1 Wellbore name: 0107-04 Well Header • • Permit/Concession N° Operator ENI Share)%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12,400.0 12,165.00 83.51 145.7 12.23 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 7,245.0 3,762.1 1,627.00 7.35 221.4 87.0 7.0 Partly Cloudy.WC 5° 32°NNE @ 1.5 mph Daily summary operation 24h Summary Displace to 9.2 ppg OBM(FazePro).\Clean surface equipment&Pit 97 of LSND mud\Drill out shoe track&25'new hole to 5643'.\Circulate bottoms-up.\Perform LOT to 13.6 EMW.\Drill Rotary Steerable 1/5643'-1/7245'as per well plan. Operation at 07.00 Drilling ahead with Schlumberger Rotary Steerable @ 7,725'as per well plan. 24h Forecast Drill ahead Rotary Steerable 1/7245'-1/12300'proposed new TD.\Prep 3 1/2"&4 1/2"production strings&5 1/2"liner in pipe shed. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) • 9.20 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 7 P Held PJSM-Displace to 9.2 Qpg OBM(FazePro)\Pump rate 475 gpm @ 1470 psi./50 rpm @ 4-5.8K torque.\Wash down -'f/5496'-1/5511'\Rotate&reciprocate string.\Transfer old LSND mud to WIF for injection with Vac trucks.\Up wt.=1406-Dn wt.=90K-Rot wt.=110K. 01 30 03.30 2.00 3.50 DRILL E 1 P Clean surface equipment and Pit#7 of LSND mud./Transfer OBM from raw to active. 0330 07.30 4.00 7.50 DRILL E 3 P D6ll out shoe track and old hole 65511'-1/5618'\Pumping 385 gpm @ 1160 psi./40-60 rpm @ 3.8-5K torque./WOB=2- .12K.\Up wt.=130K-On wt.=100K-Rot wt.=110K. 07.30 08.00 0.50 8.00 DRILL E 3 P Drill rotary steerable 30'new hole 1/5618'-V5643'(3674'TVD)\Pumping 610 gpm @ 2160 psi./60 rpm @ 4-6K torque.\ WOB=6.-8K\Mud wt.=9.2 ppg.\ECD 10.62 ppg.\Up wt.=125K-Dn wt.=95K-Rot wt.=105K.\ADT 0.24 hrs.\Jar total= 72.94 hrs.\Schlumberger made down link outside shoe. 08:00 08:30 0.50 8.50 DRILL E 7 P Circulate bottoms-up\Rotate&reciprocate pipet with 610 gpm @ 2130 psi./60 rpm @ 4K torque.\Rot wt.=110K. t 08:30 09:30 1.00 9.50 DRILL E 12 P R/U and perform LOT-mud mf.@ 9.2 ppg.\Surface pressure @ 940 psi.\Bleed down to 840 psi.and stabilized.\13.6 ma ` EWM. 09:30 12:00 2.50 12.00 DRILL E 3 P Drill Rotary Steerable 1/5643'-1/5841'(3694'TVD)\600 gpm @ 2160 psi.\100 rpm @ 4-6k torque\WOB=6-86\Up wt.= 120K-Dn wt.=90K-Rot wt.=105K\Mud wt.=9.2 ppg\ECD=10.81 ppg.\ADT 0.91 hrs.\Jar total=73.85 hrs. 12:00 00:00 12.00 24.00 DRILL E 3 P Drill Rotary Steerable 1/5841'-1/7245'(3761'TVD)\610 gpm @ 2240 psi.\120 rpm @ 6.2-7K torque\WOB=5-15K\Up wt.= 128K-Dn wt.=82K-Rot wt.=105K\Mud wt.=9.2 ppg\ECD=10.7 ppg.\ADT 6.2 hrs.\Jar total=80.05 hrs. Total ADT=7.35 hrs. Total Jar-80.05 hrs. Daily Contacts Position Contact Name Company Tilte E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Ddg.Spur. 'Jack.Keener@enipetroleum.com 907-670-8623 907-715-6434 Drilling Supt. David Smith Eni Petroleum Ddg.Spur. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Bruce Simonson Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 0.0 5.600.6 1/6/2011 Last Leakoff Test Depth)ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5,600.6 3,678.27 FazePro OBM 9.20 840.0 13.60 2,597.9 YIP* Eni E&P Division I Well Name:0107-04 Eni US Operating Co Daily Report Well Code:25118 IncField Name: Nikatchuq • APIIUWI:50-029-23435-00-00 2^,1 II Date:1/11/2011 - Report#: 18 I' II page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG • Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12,400.0 12.165.00 83.51 145.7 13.23 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 9.765.0 3,862.5 2.520.00 16.11 156.4 88.0 -9.2 Partly Cloudy.WC- 25'NNE @ 2 mph 14.4' Daily summary operation 24h Summary • Drill Rotary Steerable 1/7245'-1/9765'as per well plan.\Increase in mud wt.to 9.4 ppg due scale zone.\Load&prep 3 1/2"completion string&5 1/2"liner in pipe shed. Operation at 07.00 Drilling ahead Rotary Steerable @ 10250'as per well plan to 12400 proposed TD. 24h Forecast Drill ahead Rotary Steerable 1/9765'-512400'TD.\Circulate hole clean-CBU rack back one stand./Back ream to 9 5/8"csg.shoe @ 5600'\Maintain 9.4 ppg mud wt.\Finish prep work on 5 1/2"liner In pipe shed. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 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 Steerable(/7245'-V8611'(3861'TVD)\610 gpm @ 2470 psi\80-120 rpm @ 6.9-9K torque\WOB=8-12K\Up wt.=145K-Dn wt.=75K-Rot wt.=105K\Mud wt.=9.4 ppg\ECD=11.35 ppg.\ADT 8.0 hrs. Jar total=88.05 hrs.\No fluid loses to well bore. 12:00 00.00 12.00 24.00 DRILL E 3 P Drill Rotary Steerable 1/8611'-V9765'(3863'TVD)\610 gpm @ 2580 psi\80-120 rpm @ 7.8-9K torque\WOB=5-20K\Up • wt.=135K-Dn wt.=70K-Rot wt.=104K\Mud wt.=9.4 ppg\ECD=11.4 ppg.\ADT 8.11 hrs.\Jar total=96.16 hrs. Total ADT=23.46 hrs. Total Jar-96.16 hrs Daily Contacts Position Contact Name Company Title E-mail Office Mobile Dulling Supt. Jack Keener Eni Petroleum Sr.Ddg.Spvr. Jack.Keener@enipetroleum.com 907-670-8623 907-715-6434 Drilling Supt. David Smith Eni Petroleum Drlg.Spvr. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat • Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.681 L-80 0.0 5,600.6 1/6/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5.600.6 3,678.27 FazePro OBM 9.20 840.0 13.60 2.597.9 • Eni E&P Division I Well Name:0107-04 J Eni US Operating Co Daily Report Well Code:25118 Inc Field Name: Nikatchuq Date:1/1212011 - Report#: 19• APIIUWI:50-029-23435-00-00 2 i rr ii page 1 of 1 Wellbore name:_0107-04 Well Header Permit/Concession N` Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name •Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12,400.0 12,165.00 83.51 145.7 14.23 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature Cr) Weather Wind 12.254.0 3,923.0 2.489.00 15.98 155.8 88.0 -7.8 Partly Cloudy.WC- 18'NNE @ 2.6 mph 14.8' Daily summary operation 24h Summary Drill Rotary Steerable(/9.765'-812.254'(Shale section 1/10,393'-t/11,114').\maintain mud wt.@ 9.4 ppg\Load&prep 5 1/2"liner in pipe shed. Operation at 07.00 TD well 12,325'@ 0040 hrs.\Circulate hole clean-(reciprocate&rotate string)-set back one stand every bosoms-up 1/12,325'-1/12,075'\Maintain 9.4 ppg mud weight-average 2-3 bbls./hr.loses to well while circulating after TD. 24h Forecast Drill Rotary Steerable(/12,254'-1/12,325'\Circulate hole clean(rotate&reciprocate)-Each CBU rack back one stand.\Back ream to 5600'(9 5/8"csg.shoe)/Circulate hole clean @ 9 5/8"csg shoe.\RIH on elevators to 12,325'TD\Circulate hole clean./Displace well with FazeAway.\Maintain 9.4 ppg mud wt. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 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 Steerable 1/9,765'-1/10,914'(3,901'TVD)\610 gpm @ 2820 psi./80-120 rpm @ 8.4-9K torque\WOB=8-15K\ Up wt.=148K-Dn wt.=60K-Rot wt.=100K\Mud wt.=9.4 ppg\ECD=11.71 ppg.\ADT 8.36 hrs.\Jar total=104.52 hrs. 100 00,00 12.00 24.00 DRILL E 3 ' 2. P Drill Rotary Steerable 1/10,914'-1/12,254'(3.922'TVD)\610 gpm @ 2950 psi.\80-120 wpm @ 8.9-11K torque\WOB=4-20K\ Up wt.=145K-Dn wt=48K-Rot wt.=103K\Mud wt.=9.4 ppg\ECD=11.76 ppg.\ADT=7.62 hrs.\Jar total=112.14 hrs. Shale section 1/10,393'-1/11,114'. V Total ADT=39.44 hrs. Total Jar-112.14 hrs • Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Ddg.Spvr. Jack.Keener@enipetroleum.com '907-670-8623 907-715-6434 Drilling Supt. David Smith Eni Petroleum DrIg.Spar. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Alvin Criswell Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Dulling Tool Pusher 907-670-8539 Eni representative Michael Seward Eni Petroleum Project Advisor 1 Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 9 5/8 8.681 L-80 0.0 5,600.6 1/6/2011 Last Leakoff Test • Depth(fiKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5.600.6 3,678.27 FazePro OEM 9.20 840.0 13.60 2.597.9 Eni E&P Division (Well Name:0107-04 1119* Eni US Operating Co Daily Report Well Code:25116 • Inc Field Name:Nikatchuq 2 II I� Date:1/13/2011 - Report#: 20 API/UWI:50-029-23435-00-00 page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor 'Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) 0107-04 DRILLING 12!29/2010 12,400.0 12.165.00 83.51 145.7 15.23 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ftlhr) POB Temperature(°F) Weather Wind 12.325.0 3,924.7 71.00 0.66 107.6 89.0 -17.3 Partly Cloudy,WC- 85'E @ 1 mph 17.3 Daily summary operation 24h Summary Drill Rotary Steerable f/12,254'-1/12.325'(Shale section f110,393'-1/11,114')\Circulate until clean and rack one stand every CBU(/12,325'-(/11,680'1 Back ream(/11,680'-117630'/Shale section 1/11,114'- 1110,939'no problems back reaming-Shale section(/8,251'-07789'-Back reaming speed reduced due to hole condition causing slight increases in pump pressure.slight fluctuation in torque and increase in cutting size and amount at shakers. Operation at 07.00 POOH back reaming @ 6,468'. 24h Forecast Finish POOH back reaming 7630'-V5600'(9 5/8"csg.shoe)\Circulate hole clean.\POOH to Schlumberger smart BHA&UD same.\P/U 8 112"hole opener,bit sub w/float-RIH w/Flex DC&5"HWDP to 5600'\Cut drilling line&service\RIH to 12,325'TD./Circulate hole clean.\Displace well with FazeAway.\POOH on elevators. Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01-.00 1.00 1.00 DRILL E 3 P Drill Rotary Steerable(/12,254'-(/12,325'(3.925'TVD)/610 gpm @ 3020 psi./120 rpm @ 9-11.2K torque WOB=8-20K/ Up wt.=150K-Dn wt.=0-Rot wt.=103K/Mud wt.=9.4 ppg\ECD=11.71 ppg.\ADT 0.66 hrs.\Jar total=112.8 hrs. Total ADT=40.10 hrs. Total Jam 112.80 hrs h. 01:00 06:30 5.50 6.50 DRILL E 7 IP Circulate until clean 6X,(rotate&reciprocate pipe)\Pumping 610 gpm @ 2800 psi./120-140 rpm @ 8.9-11.3K torque.\ Condition mud and maintain 9.4 ppg weight.\ECD=11.40 ppg.\12 bbls.losses while circulating.\Each CBU rack back one stand f/12,325'-V11,680'\Up wt.=145K-Dn wt.=55K-Rot wt.=104K.1 Fluid losses 12 bbls.\Monitor well for 10 minutes. 06.30 1400 7.50 14.00 DRILL E 4 P POOH back reaming f/11 680'-88367')(Shale(/11,114'-(/10,939'no problems)/Pumping 610 gpm @ 2400 psi./120 rpm @ 7.1K torque.\Mud wt=9.4 ppg\ECD=10.99 ppg.\Rot wt.=130K-Dn wf.=70K-Rot wt=100K.Fluid losses 47 bbls. 14.00 00.00 10.00 24.00 DRILL E 4 P POOH back reaming f/8367'-117630'-(Shale(/8251'-1/7789'-pull speed decreased due to slight pump pressure increase, torque increases and increase in cutting size/amounts at shakers\Pumping 610 gpm @ 2200 psi. 120 rpm @ 6.2K torque.\Mud w1.=9.4 ppg\ECD=10.89 ppg.\Rot wt.=125K-Dn w1=60K-Rot wt.=100K.\Fluid losses 50 bbls.\Total losses 109 bbls for 24 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Ddg.Spur. IIJack.Keener@enipetroleum.com 907-670-8623 I 907-715-6434 Drilling Supt. David Smith Eni Petroleum DrIg.Spur. 907-670-8623 907-632-3058 Eni representative Bernie Leas Eni Petroleum Rig Clerk 907-670-8607 907-575-9427 Eni representative Mike Nelson Eni Petroleum HSE Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 0.0 5,600.6 1/6/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5,600.6 3,678.27 FazePro OBM 9.20 840.0 13.60 2,597.9 St* Eni E&P Division I Well Name:0107-04 Eni US Operating Co Daily Report Well Code:25118 IncField Name: Nikatchuq 2^ Date:1/14/2011 - Report#: 21 APIIUWI:50-029-23435 -00 If II page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12,400.0 12,165.00 83.51 145.7 16.23 Daily Information End Depth(RKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 12,325.0 3,924.7 0.00 91.0 -6.2 Mostly Cloudy,WC- 201"SSW @ 0 mph Daily summary operation 24h Summary Backream out of hole from 7630'to 3640'POOH from 3640'to BHA.lay down smart tools&download same.Change out saver sun&clean rig floor,Make up BHA#5 Hole opener and run in hole to 5453'and cut&slip drilling line. Operation at 07.00 On bottom at 12325'circulating&displacing open hole to 9.5 ppg faze-away break completion fluid. 24h Forecast Tnp in hole to td on elevators with hole opener.circulate hole clean,prepare pits to displace open hole to faze-away completion breaker fluid.displace open hole to faze-away breaker completion fluid, followed by 30 bbl dry job.Flow check and POOH on elevators(Will drop hollow drift rabbit with slickline tail down drill pipe on tnp out for upcoming liner run&SLZXP hanger/packer. Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.40 Time Log Start End Cum Time Time Dur(hr) Dur)hr) Phase Opr. Act. Plan Oper.Descr. 00:00 07:00 7.00 7.00 DRILL E 6 P Continue Backreaming from 7630'to 5554'gpm=610,rpm=120,psi=1920,torque=4800 f/lbs,ecd=10.9 ppg,up w1=118k, dn w1=92k,rot wt=104k,trying to pack-off between 6960'-6952'&6485'-6475' Cont.backream up into 9-5/8"casing shoe. 07:00 08:30 1.50 8.50 DRILL E 7 P Circulate while inside casing shoe @5554'cbu x 4,rotate&recipncate pipe.gpm=610,rpm=80.torque=4500 ft/lbs, psi=1860.up wt=118k.dn w1=92k,rot wt=104k. 08:30 12:00 3.50 12.00 DRILL E 6 P Continue backreaming up inside casing from 5554'to 3927'gpm=610.psi=1680,rpm=80,torque=3000 ft/lbs,up wI=115k, do wt=105k,rot wt--110k 12:00 '13,00 1.00 13.00 DRILL E 6 P Continue backreaming up inside casing from 3927'to 3640'gpm=610.psi=1650,rpm=80,torque=2700 ft/lbs.up wt=115k, do wt=110k,rot wt=110k 13:00 13:30 0.50 13.50 DRILL E 7 P Monitor well-Static(No flow)pump dry job and blow down topdrive&mud line. 13:30 15:00 1.50- 15.00 DRILL E 4 P Trip out of hole from 3640'to bha at 480' 15.00 18:00 3.00 18.00 DRILL E 4 P PJSM-POOH and stand back HWDP&NMDC's,lay down sonic,nm stabilizer,telescope,arc,exceed.break bit.stabilizer out of gauge 1/2"every thing else in gauge-ok. 18:00 19:00 1.00 19.00 DRILL E 4 P Pick up hole opener&bit sub to rig floor,clean rig floor from trip out,change out saver sub on topdrive. 1900 19:30 0.50 19.50 DRILL E 4 P Make up BHA#5 hole opener&bit sub with float,stand of NM DC's,HWDP&jars to 382' 19:30 22:30 3.00 22.50 DRILL E 4 P Run in hole with 5"DP from 382'to 5453'filling pipe&breaking circulation every 25 stands.Up wt=110k,Dn wt=90k, correct pipe displacement on trip in. 22:30 00:00 1.50' 24.00 DRILL E 25 P PJSM-Cut and slip 74'of drilling line,perform rig service. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Ddg.Spot. Jack.Keener@enipetroleum.com 907-670-8623 907-715-6434 Drilling Supt. Scott Beauchamp Eni Petroleum Sr.Ddg.Spvr. Scott.Beauchamp@enipetroleum.com 907-670-8623 907-841-8759 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date CASING 95/8 8.681 L-80 0.0 5,6006 1/6/2011 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5.6006 3,678.27 FazePro OBM 9.20 840.0 13.60 2,597.9 111* Eni E&P Division 'Well Name:0107-04 Eni US Operating Co Daily Report Well Code:25118 Inc Field Name:Nikatchuq •2^n Date:1/1512011 - Report#: 22 ii API/01M:50-029-23435-00-00 i II page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(ND...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12,400.0 12,165.00 83.51 145.7 17.23 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature('F) Weather Wind 12,325.0 3,924.7 0.00 87.0 -17.0 Mostly Cloudy,WC- 341'NNW @ 5 mph 24" Daily summary operation 24h Summary Trip in hole to td on elevators with hole opener,circulate hole clean,prepare pits to displace open hole to faze-away completion breaker fluid,displace open hole to faze-away breaker completion fluid, followed by 30 bbl dry job.Flow check and POOH on elevators(Will drop hollow drift rabbit with slickline tail down drill pipe on trip out for upcoming liner run&SLZXP hanger/packer.. Operation at 07.00 Running 5.5"#17 PPF,L-80,Hydril-521 Slotted Liner _ 24h Forecast-- Finish POOH with BHA and rack back HWDP&Jar,lay down NM Flex DCs&bit sub,hole opener.Clear&dean rig floor,PJSM and rig up to run 5.5"liner,run liner as per tally. Lithology Shows MAASP Pressure(psi) Mud Weight(1b/gall 9.45 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 DRILL E 4 P Trip in hole from 5452'to 12325'bottom,hole in good shape-No tight spots.Fill pipe and break circulation every 20 stands dp. 04:30 12:00 7.50 12.00 DRILL E 7 P Circulate and condition mud while rotate&recipricate pipe at 120 rpm,610 gpm,2400 psi,8.6k torque,until shakers clean- ok.Ciculate at 300 gpm,60 rpm,800 psi.Wait on faze away 9.5 ppg breaker to show up,prep active pits for displacement and work on 5.5"liner in pipeshed. 12:00 1600 4.00 16.00 DRILL E 7 U Continue to wait on faze away breaker from MI mud plant,circulate at 322 gpm with 820 psi.60 rpm,8.4k torque,120k rotate wt.rotate&recipricate pipe. 16:00 17:30 1.50 17.50 DRILL E 9 P Displace to completion fluid faze away breaker 9.5 ppg,pump 510 bbls.262 gpm,480 psi,60 rpm,118k rot wl.9.4k torque. pump 60 bbls faze pro 9.4 ppg.pump 11.4 ppg dry job pill.monitor well. 17:30 00:00 '' 6.50 24.00 DRILL E 4 P POOH on elevators from 12325'to 5600'casing shoe,monitor well at shoe-ok.POOH at 1 minute per stand 165k up wt, 80k do wt,cont.pooh to 2294'hole fluid losses at 8 BPH over pipe displacement.dropped hollow drift at 6850' OD- 2 3/8" Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Ddg.Spvr. 'Jack.Keener@enipetroleum.com 907-670-8623 '907-715-6434 Dolling Supt. Scott Beauchamp Eni Petroleum Sr.DrIg.Spvr. Scott.Beauchamp@enipetroleum.com 907-670-8623 907-841-8759 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(lIKB) Run Date CASING 95/8 8.681 L-80 0.0 5,600.6 1/6/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5,600.6 3,678.27 FazePro OBM 9.20 840.0 13.60 2,597.9 cflif* Eni E&P Division I Well Name:0107-04 Eni US Operating Co Daily Report Well Code:25118 Inc Field Name:Nikatchuq � APIIUWI:50-029-23435-00-00 2^ Date:1/16/2011 - Report#: 23 II II li page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share W.) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) 0107-04 DRILLING 12/29/2010 12 400.0 12.165.00 83.51 145.7 18.23 Daily Information End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Homs(hr) Avg ROP(ft/hr) POB Temperature("F) Weather Wind 12,325.0 3,924.7 0.00 81.0 -4.0 Cloudy,light Snow, 193°SSW @ 3.7 WC-11.8" mph Daily summary operation 24h Summary Finish POOH with BHA and rack back HWDP&Jar,lay down NM Flex DCs&bit sub,hole opener.Clear&clean ng floor.PJSM and ng up to run 5.5"liner,run liner as per tally.Run liner to 6912'make up SLZXP liner hanger/packer.fill tie-back sleeve with pal-mix&wait 30 minutes to set up.run 1 stand dp&circulate 5 bbls to ensure flow paths free-ok,rotate wt=102k,tq=2600 ft.lbs,gpm=182. psi=240,pu wt=112k.so wt=90k,run liner in hole on dp taking rot wt's&tq's every 5 stands,run liner to 10135' Operation at 07.00 Displacing cased hole over to 9.0 PPG inhibited brine. 24h Forecast Finish run liner to bottom at 12325'tag same&pick up 10'to setting depth @12315'circulate dp volume+and then drop ball and pump down,set SLZXP liner hanger I packer as per Baker Rep.test annulus to packer to 1500 psi for 10 minutes on chart recorder.Lay down single&displace cased hole over to inhibited 9.0 ppg brine,flow check and POOH laying down all DP,inspect running tool. Lithotogy Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.45 • 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 P 'Trip out of hole from 2294'to BHA at 382'and flow check-loosing 6 BPH hole fluid losses. 02:00 02:30 0.50 2.50 DRILL E 4 P 'POOH and rack back HWDP and jar,lay down 3 NM flex DCs,bit sub,and hole opener. 02:30 05:30 3.00 5.50 DRILL G 1 P PJSM-Pick up and ng up GBR casing equipment for liner job.Rig up torque-tum equipment. 05:30 06:00 0.50 6.00 DRILL G 4 P Hnld P ICpdwiih al persannel to nm 5 5"Slott d to 06:00 12:00 6.00 12.00'DRILL G 4 P 'Run 5 1/2"#17 PPF,L-80,Hyddl-521 Slotted&Blank Liner.Make up accentric nose guide shoe(bakedock same)Run Liner to 2448'Torque Turn to 12k Tq.Hole fluid losses at 3-5 BPH while running liner. 12:00 20:30 8.50 20.50 DRILL G 4 P Continue run 5 1l2"#17 PPF,L-80,Hydril-521 Liner from 2488'to 6912'Torque-Turn to 12k Tq.Hole fluid losses at 3 BPH while running liner. 20:30 21:30 1.00 21.50 DRILL G 4 P Change elevators and pick up Baker SLZXP liner hanger/packer and make up same.Baker Rep.fill liner tie-back with Pal- mix and wait 30 minutes to set up-OK. • 21 30 00:00 2.50 24.00 DRILL G 4 P Trip in hole 1 stand DP,kelly up and circulate 5 bbls to confirm flow paths free:gpm=182.psi=240,rpm=20,torque=2600 ft/lbs,rotate wt.of liner at 102k,pu wt=112k,so wt=90k.Run liner in on 5"drill pipe taking rotate wt.s and torques every 5 stands dp,and filling up dp every 10 stands.Run dp at 2 minutes per stand slack-off time to reduce surge&fluid losses. Run liner to 10.135' Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. -Jack Keener Eni Petroleum Sr.04g.Spvr. Jack.Keener@enipetroleum.com 907-670-8623 907-715-6434 Drilling Supt. Scott Beauchamp Eni Petroleum Sr.Ddg.Spvr. Scott.Beauchamp@enipetroleum.com 907-670-8623 907-841-8759 • Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Michael Seward I Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 3/4 L80 5.425.3 12,315.0 1/16/2011 Last Leakoff Test Depth(ftKB) TVD(ttKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 5,600.6 3,678.27 FazePro OBM 9.20 840.0 13.60 2,597.9 foeEni E&P Division [Well Name:0107-04 Eni US Operating Co Daily Report Well Code:25118 Inc Field Name: Nikatchuq • API/UWI:50-029-23435-00-00 2 Date:1/17/2011 - Report#: 24 I) II page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL • Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 1220 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(11KB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 DRILLING 12/29/2010 12,400.0 12,165.00 83.51 145.7 19.52 Daily Information • End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 12,325.0 3,924.7 0.00 77.0 -17.9 Mostly clear,blowing 212'SSW @ 10.6 snow,WC-41.1' mph Daily summary operation 24h Summary Finish run liner to bottom at 12325'tag same&pick up to setting depth @12313'circulate dp volume+and then drop ball and pump down.set SLZXP liner hanger/packer as per Baker Rep.test annulus to packer to 1500 psi for 10 minutes on chart recorder. Operation at 07.00 Switch to Completion Phase 24h Forecast Switch to Completion Phase Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.00 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 'G 4 P Trip in hole with 5 1/2"317 ppt.L-80.Hydril-521 slotted liner on 5"drill pipe from 10300'to 12200'taking weight. 01:30 02:00 0.50 2.00 DRILL G 6 P Establish parameters and ream liner in hole from 12200'to bottom at 12325'tag same.Rotate wt=122k,reaming so w1=112k,rpm=25,reaming torque=9500 ft/lbs.pick up off bottom&shut down rotary,slack off&tag bottom.pick up until wt break-over,pick up off bottom to 12313'liner setting depth. 02:00 02:30 0.50 2.50 DRILL G 7 P Circulate dnll pipe volume+(100 bbls)to confirm flow paths free-ok.bpm=5,psi=400.rig up chart recorder, 02:30 03:30 1.00 3.50 DRILL G 7 P Drop ball and pump down at 7 bpm with 500 psi for 63 bbls.slow pump to 2 bpm with 225 psi,land out ball in seat. pressure up to 3000 psi.slack off to 70k weight,and pressure up to 4000 psi.bleed off to zero,close annular preventer and pressure up backside to 1500 psi for 10 minutes on chart recorder.OK,bleed off,pressure up drill pipe to 400 psi and unsting running tool,watch pressure dump to zero-OK.Lay down 2 singles drill pipe. 03.30 07:00 3.50 7.00 DRILL E 9 P PJSM-Displace cased hole over to 9.0 ppg inhibited brine,bpm=7,psi=400,rpm=30,total of 360 bbls displaced.Rotate& recipricate pipe through-out displacement.Clean brine back to surface.Hole fluid losses remain at 2 bph. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum -Sr.DrIg.Spa-. -Jack.Keener@enipetroleum.com 907-670-8623 907-715-6434 V Drilling Supt. Scott Beauchamp Eni Petroleum Sr.Orig.Spvr. Scott.Beauchamp@enipetroleum.com 907-670-8623 907-841-8759 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Dolling Tool Pusher 907-670-8539 Eni representative Michael Seward Eni Petroleum Protect Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date LINER 5 3/4 L80 5.425.3 12,315.0 1/16/2011 Last Leakoff Test -Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(Ib/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 5,600.6 3,678.27 FazePro OBM 9.20 840.0 13.60 2,597.9 l if* Eni E&P Division (Well Name:0107-04 Eni US Operating Co Daily Report Well Code:25118 Inc Field Name: Nikatchuq • 2^„ Date:1117/2011 - Report#: 1 APIIUWI:50-029-23435-00-00 II II II page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(it) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) • 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 COMPLETION 12/29/2010 12.325.0 3.924.7 19.23 Daily Information End Depth(ftKB) End Depth(TVD)(f..,Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 12,325.0 0.0 77.0 -17.9 Mostly clear,blowing 229'SW©13.2 snow.W0-01.1" mph Daily summary operation 24h Summary Lay down 2 singles 8 displace cased hole over to inhibited 9.0 ppg bnne,flow check and POOH laying down all DP,inspect running tool. Operation at 07.00 Rigging up to run completion string. 24h Forecast POOH laying down drill pipe and inspect running tool-OK.Run in hole with drill pipe 8 hwdp/jar from derrick,pooh laying down same.Rig up and run completion, Lithology Shows MAASP Pressure(psi) Mud Weight(lb/gal) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 07:00 12:00 5.00 5.00 DRILL K 4 P Flow check-OK,POOH laying down drill pipe.123 joints layed down 12.00 14:30 2.50 7.50 DRILL K 4 P POoh laying down drill pipe,46 joints layed down,break off running tool 8 inspect same-OK. 14:30 15:00 0.50 8.00 DRILL K 25 P Rig Service 15:00 17:30 2.50 10.50 DRILL K 4 P Trip in hole with drill pipe,hwdp 8 jar to 4400'from derrick,pu wt=125k,so wt=110k 17:30 22.00 4.50 15.00 DRILL K 4 P POOH laying down drill pipe.hwdp.and jar from 4400' '22:00 2330 1.50 16.50 DRILL K 4 P Top in hole with remaining 30 stands drill pipe from derrick to 3128'pu wf=110k,so wt=look 23:30 0000 0.50 17.00 DRILL K 4 P POOH laying down drill pipe from 3128'to 2650' Daily Contacts • Position Contact Name Company Title ' E-mail Office Mobile Drilling Supt. Jack Keener Eni Petroleum Sr.Ddg.Spvr. 'Jack.Keener@enipetroleum.com 907-670-8623 907-715-6434 Drilling Supt. Scott Beauchamp Eni Petroleum Sr.Drig.Spur. Scott.Beauchamp@enipetroleum.com 907-670-8623 907-841-8759 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date LINER 5 3/4 L80 5,425.3 12,315.0 1/16/2011 Last Leakoff Test • Depth(ftKB) TVD(t1KB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5,600.6 3,678.27 FazePro OBM 9.20 840.0 13.60 2,597.9 ilf"4 1 Eni E&P Division I Well Name:0107-04 Eni US Operating Co Daily Report Well Code:25118 Inc Field Name: Nikatchuq • APIIUWI:50-029-23435-00-00 ern„i Date:1/1812011 - Report#: 2 'I ipage 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ftlhr) DFS(days) 0107-04 COMPLETION 12/29/2010 12,325.0 3.924.7 20.23 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 12,325.0 0.0 82.0 -17.0 Partly cloudy,WC- 198"SSW @ 5.9 31.9' mph Daily summary operation 24h Summary POOH laying down drill pipe and inspect running tool-OK.Run in hole with drill pipe&hwdp/jar from derrick,pooh laying down same.Rig up and run completion. Operation at 07.00 Continue running Injection string completion as per ENI running tally,testing fiberoptic cable every 1000' 24h Forecast Continue running Injection string completion as per ENI running tally,testing fiberoptic cable every 1000' Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.00 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 COMP K 4 P Continue to lay down drill pipe 75 joints and 9 joints hwdp&jar.Pull wear-bushing. 0400 °09:00 500 9.00 COMP K 1 P PJSM-Lay down tools from rig floor&clear same.Pick up&rig up SLB Tec and Neon spooler.cables.Pick up and hang shieves in derrick,pick up Halliburton table.Rig up GBR tubing equipment-Slips.elevators.tongs.Pick up and stage iir polyoil clamps.prepare for running injection completion string. i'lit 0900 .10:30 1.50 10.50 COMP K 4 P Pick up and make up bullnose/gauge mandrel,SLB make up gauge to cable. till'.„v� 10'30 12:00 - 1.50 12.00 COMP K 4 P Ryn completion string as per ENI running tally,run in hole with 3 1/2"IBT#9.2 ppf,L-80 tubing with fiberoptic cable, l��-/VJI„ installing clamps on every collar,installing ICD's as per tally. 12:00 00:00 12.00 24.00 COMP K 4 P Continue trip in hole running 3 1/2"#9.2 ppf,L-80 IBT tubing from 150'to 3361'test cable every 1000'taking slack off weights/caliper all clamps&components.Hole fluid losses remain at 1 BPH. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • Drilling Supt. Jack Keener Eni Petroleum Sr.Ddg.Spvr. Jack.Keener@enipetroleum.com 907-670-8623 907-715-6434 Drilling Supt. Scott Beauchamp Eni Petroleum Sr.Drlg.Spvr. Scott.Beauchamp@enipetroleum.com 907-670-8623 907-841-8759 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 • Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dnlling Tool Pusher 907-670-8539 Tool Push Russ Wimmer Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(MB) Run Date LINER 5 3/4 L80 5.425.3 12,315.0 1/16/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gall P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5.600.6 3.678.27 FazePro OBM 9.20 840.0 13.60 2,597.9 Eni E&P Division (Well Name:0107-04 rill* Eni US Operating Co Daily Report Well Code:25118 Inc Field Name: Nikatchuq •2�, Date:1/19/2011 - Report#: 3 APIIUWI:50-029-23435-00-00 I( I� page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 COMPLETION 12/29/2010 12.325.0 3.924.7 21.23 Daily Information End Depth(ftKB) End Depth(TVD)(f.. Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°E) Weather Wind 12.325.0 0.0 85.0 -32.4 Partly cloudy,WC- 192'SSW @ 6.7 50.2' mph Daily summary operation 24h Summary Continue running Injection string completion as per ENI running tally,testing fiberoptic cable every 1000'make up XN nipple.AHR packer,Xprofile nipple.run fiber optic cable through packer,OLE make splice and test to 10.000 psi for 15 minutes,test first ferret to 10,000 psi&second ferrel to 10,000 psi,all test 15 minutes and witnessed by ENI Rep. Operation at 07.00 Continue running Injection string completion as per ENI running tally,testing fiberoptic cable every 1000' 24h Forecast Continue running Injection Completion string as per ENI running tally. Lithology •Shows MAASP Pressure(psi) Mud Weight(lb/gal) 9.00 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 COMP K 4 P Completion-Trip in hole with 3 1/2"#9.2 ppf,L-80,IBT tubing from 3360'to 5472'with fiberoptic cable testing same every • 1000'making up swell packers.ICds,per ENI running tally. 06:00 09.00 3.00 9.00'COMP K 4 P Continue trip in hole with completion string 3 1/2"tubing&fiberoptic cable testing same evey 1000'from 5472' to 6771'PU Wt=72k,DN 1/14=70k 0900 11 00 2.00 11.00 COMP K 4 P Make up gauge carrier,pup joint,x-over to 4 1/2"tubing.run 4 1/2"#12.6 ppf,L-80.IBTM tubing to 7760'with fiberoptic • cable testing same evey 1000' DN Wt=66k,Hole fluid losses remain at 1 BPH. 11'00 13.00 2.00 13.00 COMP K 4 P Make up jewelry-make up XN nipple,AHR packer,X profile nipple with pup joints on same.DN Wt=70k 13.00 23:30 10.50 23.50 COMP K 5 P Run fiberoptic lines through AHR packer&prep for splice,SLB make fiber optic splice on cable,test to 10.000 psi(ENI Rep witness all tests)for 15 minutes.SLB test first ferrel to 10.000 psi&second ferrel to 10,000 psi each test 15 minutes-OK. Three tests total,ENI Rep witness all tests. 23.30 00'00 0.50 24.00 COMP K 4 P Continue trip in hole with 4 1/2"#12.6 ppf,L-80 IBTM tubing to 7922'DN Wt=72k Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Jack Keener 'Eni Petroleum Sr.Dig.Spur. 'Jack.Keener@enipetroleum.com 907-670-8623 907-715-6434 Drilling Supt. Scott Beauchamp Eni Petroleum Sr.Dig.Spur. Scott.Beauchamp@enipetroleum.com 907-670-8623 907-841-8759 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Sach Bowe Eni Petroleum Materals Coordinator 907-685-1226 907-299-0531 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dolling Tool Pusher 907-670-8539 Tool Push Mark Ashley Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 3/4 L80 5.425.3 12,315.0 1/16/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(1b/gal) P Surf Applied(psi) Eq.Mud Weight(lb/gal) Leak Off Pressure(psi) 5.600.6 3,678.27 FazePro OBM 9.20 840.0 13.60 2.597.9 • • k �� Eni E&P Division I Well Name:0107-04 Eni US Operating Co Daily Report Well Code:25118 Inc Field Name:Nikatchuq • Date:1/2012011 - Report#: 4 API/UWI:50-029-23435-00-00 2" " page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%( Well Configuration type 210-153 Eni US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 COMPLETION 12/29/2010 12,325.0 3.924.7 22.23 Daily Information • • End Depth(ftKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 12,325.0 0.0 82.0 -34.8 Partly cloudy,WC- sr E @ 0.1 mph 34.8' Daily summary operation 24h Summary • Continue running Injection Completion string as per ENI running tally,rig up&compensate VIT joints,make up x-over pup and Vetco Gray hanger,install penetrator,terminate fiber-optic cable/gauge lines to hanger.Rig up pump-in-sub to landing joint,drop AHR Halliburton Ball/Rod and land out same,pressure up tubing to 500 psi-OK,pressure up tubing to 2100 psi and acknowledge AHR packer setting,continue pressure up tubing to 4000 psi and hold for 30 minutes on chart recorder-OK,bleed off tubing.Pressure up Inner Annulus to 500 psi on chart recorder and hold for 30 minutes-OK,bleed off annulus.ng down lines.Clear dg floor and lay down tools,GBR equipment,SLB equipment.Blow down choke&kill lines,Nipple down flow nipple,flowline,choke&kill lines. Operation at 07.00 Finish Nippling up Tree and test same to 5000 psi. 24h Forecast Open Lower Pipe Ram doors and remove 3 1/2"x 6"variable rams,open upper pipe ram doors and remove 4 1/2"x 7"variable rams,both sets removed for redressing variable elements.Set back ROPE stack,nipple up Tree and test same.ng up LRS Hotoil truck and pressure up tubing to 2000 psi,swap over and pressure up Inner annulus to 2500 psi,hold on chart recorder for 30 minutes,bleed down tubing and shear-out GLM valve,freeze protect with 152 bbls diesel LRS pumping down Inner annulus taking retums up through tubing through choke to pits.Blow down lines&rig down same and LRS Hotoil truck,RELEASE RIG.RDMO Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.00 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 0730 7.50 7.50 COMP K 4 P Continue trip in hole with 4.5"#12.6 ppf,L-80.IBTM Tubing from 7838'to 11934'with fiber-optic cable testing same every 1000'per ENI running tally,installing clamps on every collar as per SLB.Up Wt=85k.Dn Wt=68k.Hole fluid losses remain at 1 BPH. 07:30 09.30 2.00 9.50 COMP K 4 P PJSM-Rig up GBR compensator,pick up and make up x-over and 4 1/2"x 6"VII Joints(3 each)compensating same, 4400 ftlbs optimum torque,Run in hole to 12042' 09:30 12'00 2.50 12.00 COMP K 4 P Pick up Landing Joint,Vetco Gray Tubing Hanger and x-over pup joint make up same&orient hanger as per VG Rep. Install Penetrator&Terminate fiber-optic cable/Gauge line to hanger as per SLB Rep.Rig up pump-in-sub to landing joint. Up Wt=100k,Dn Wt=65k 12:00 15:00 3.00 15.00 COMP K 8 U Pump through bleed off valve-OBM contaminated mud in system,flush all mud pumps,flush out stack,rig up test lines. 15:00 17:00 2.00 17.00 COMP K 19 P Drop Halliburton AHR Ball/Rod,Pressure Test Lines to 5000 PSI-OK,AHR BaIVRod land out on seat,Pressure up Tubing to 500 PSI-OK.Check equipment-OK,Pressure up Tubing to 2100 PSI and acknowledge Halliburton AHR Packer Setting, t✓ Continue Pressure up Tubing to 4000 PSI.Hold for 30 minutes-OK,charted on recorder.Bleed Tubing off to zero. 17.00 18:00 1.00 18.00 COMP K 19 P Pump down Inner Annulus and pressure up annulus to 500 PSI-OK.Hold for 30 minutes on chart recorder-OK.Bleed off annulus to zero and rig down lines. 18:00 18:30 0.50 18.50 COMP C 5 P Pickup T-Bar and Vetco Gray Rep.Set BPV,Lay down T-Bar. 18:30 2030 2.00 20.50 COMP K 5 P Lay down tools.lay down GBR tubing equipment,lay down SLB equipment.clear ng floor of equipment from completion run. 20:30 00.00 3.50 24.00 COMP C 5 P Blow down choke&kill lines,nipple down flow nipple.flow-line,nipple down choke&kill lines. Daily Contacts Position Contact Name Company Title E-mail Office Mobile • • Drilling Supt. Jack Keener Eni Petroleum Sr.Dug.Spvr. Jack.Keener@enipetroleum.com 907-670-8623 907-715-6434 Drilling Supt. Scott Beauchamp Eni Petroleum Sr.Dng.Spvr. Scott.Beauchamp@enipetroleum.com 907-670-8623 907-841-8759 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Dan Lee Eni Petroleum Materials Coordinate 907-685-1226 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dulling Tool Pusher 907-670-8539 Tool Push Mark Ashley Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(ftKB) Bottom(ftKB) Run Date LINER 5 3/4 L80 5,425.3 12.315.0 1/16/2011 Last Leakoff Test Depth(RKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 5.600.6 3.678.27 FazePro OBM 9.20 840.0 13.60 2,597.9 11511* Eni E&P Division (Well Name:0107-04 Eni US Operating Co Daily Report Well Code:25118 Inc Field Name:Nikatchuq • APIIl1WI:50-029-23435-00-00 2^„ Date:1/21/2011 - Report#: 5 II II II page 1 of 1 Wellbore name: 0107-04 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 210-153 Em US Operating Co Inc 100.00 HORIZONTAL Rotary Table Elevation(ft) Ground Level(ft) Water Depth(ft) RKB-Base Flange(ft) RKB-Tubing Spool(ft) 41.12 12.20 0.00 36.98 33.26 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(ftKB) Target Depth(TVD...Depth Dr.(MD)(ft) Drilling Hours(hr) Avg ROP(ft/hr) DFS(days) 0107-04 COMPLETION 12/29/2010 12.325.0 3.924.7 23.23 Daily Information End Depth(fIKB) End Depth(TVD)(f...Depth Progress(ft) Drilling Hours(hr) Avg ROP(ft/hr) POB Temperature(°F) Weather Wind 12,325.0 0.0 74,0 -33.5 Partly cloudy,WC- 88'E @ 3.5 mph 46.5' Daily summary operation 24h Summary Open Lower Pipe Ram doors and remove 3 1/2"x 6"variable rams.open upper pipe ram doors and remove 4 1/2"x 7"variable rams.both sets removed for redressing variable elements.Set back BOPE stack,nipple up Tree and test same,rig up LRS Hotoil truck and pressure up tubing to 2000 psi,swap over and pressure up Inner annulus to 2500 psi,hold on chart recorder for 30 minutes,bleed down tubing and shear-out GLM valve,freeze protect with 152 bbls diesel LRS pumping down Inner annulus taking retums up through tubing through choke to pits.Blow down lines&rig down same and LRS Hotoil truck,RELEASE RIG.RDMO. Operation at 07.00 Moving Rig Sub&Utility Sub,Spotting Same over#OP10-09 24h Forecast RELEASE RIG AT MIDNIGHT ON 1-21-2011. Finish ng down&move rig modules,pick up mats&old herculite,lay new herculite and mats.spot sub&utility module over#OP10-09 Lithology Shows MAASP Pressure(psi) Mud Weight(Ib/gal) 9.00 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 COMP C 5 P PJSM-Open Upper Ram Doors&remove 4 1/2"x 7"variable pipe rams,open lower ram doors&remove 3 1/2"x 6" variable pipe rams for mechanic to change out element packing on both sets.Clean rams up.shut upper&lower doors. 03:30 05:30 2.00 5.50 COMP C 5 P Nipple down BOPE stack and set back same on stump,secure same.Remove vetco riser as per VG Rep. 05:30 09:00 3.50 9.00 COMP C 5 P Prepare cellar and wellhead.prep hanger.terminate/cap fiber-optic cable/gauge lines to hanger per SLB,Test same-OK. 0900 11:00 2.00 11.00 COMP C 5 P Nipple up Tree,Wing Valve.and Actuator valve,as per Vetco Gray Rep. 11 00 12.00 1.00' 12.00 COMP C 5 P Rig up&Test Tree to 5000 psi for 10 minutes on chart recorder-OK. 12.00 13:30 1,50' 13.50 COMP C 8 P Rig up lines to tubing&inner annulus to u-tube manifold and LRS Hotoil truck. 13.30 15:30 2.00 15.50 COMP K 9 P PJSM-Test lines to 3000 psi-OK,pressure up tubing to 2000 psi&hold same,swap over to annulus and pressure up inner annulus to 2500 psi&hold for 30 minutes on chart recorder-OK,bleed tubing down through rig choke and let GLM valve shear-out at 500 psi-OK,bleed off tubing&annulus to zero. 15:30 17:30 2.00 17.50 COMP K 9 P LRS Hotoil truck pump diesel freeze protect down inner annulus taking returns up through tubing through ng choke line to pits,pump a total of 155 bbls diesel at 1.5 bpm with 650 psi,100%diesel retums to surface,shut in tubing&IA pressures at 175 psi. 17:30 19:00 1.50 19.00 COMP K 5 P Blow down all lines,secure well,rig down all lines, 19:00 '00:00 5.00 24.00 COMP A 2 P Rig Down-Blow down charge pump manifolds and lines,drain charge pumps.blow down sub side H2O lines,raise cellar box.roll up tarp curtains around both modules&lampsons,remove berming around ng,run methanol through ng air system.disconnect mud manifold innerconnect.Disconect flowlines and hole fill lines,swap utility power to 353 cat, disconnect power between modules.Blow down steam on sub side module. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Drilling Supt. Frank Cormier Eni Petroleum Sr.Drig.Spur. 907-685-1227 907-440-0806 Drilling Supt. Scott Beauchamp Eni Petroleum Sr.Ddg.Spur. Scott.Beauchamp@enipetroleum.com 907-670-8623 907-841-8759 Eni representative Tom Norvig Eni Petroleum Rig Clerk 907-670-8607 907-229-6100 Eni representative Jack Potter Eni Petroleum HSE 907-685-1227 907-632-2236 Eni representative Dan Lee Eni Petroleum Materials Coordinato 907-685-1226 Eni representative Greg Parker Eni Petroleum Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher 907-670-8539 Tool Push Mark Ashley Nabors Alaska Drilling Tool Pusher 907-670-8539 Eni representative Michael Seward Eni Petroleum Project Advisor Last Casing seat Cas.Type OD(in) ID(in) Grade Top(RKB) Bottom(ftKB) Run Date LINER 5 3/4 L80 5,425.3 12,315.0 1/16/2011 Last Leakoff Test Depth(ftKB) TVD(ftKB) Fluid Type Fluid Density(lb/gal) P Surf Applied(psi) Eq.Mud Weight(Ib/gal) Leak Off Pressure(psi) 5,600.6 3,678.27 FazePro OBM 9.20 840.0 13.60 2,597.9 F HORIZONTAL-0107-04,22412011 5:46:34 PM TVD MD(ftKB) Incl(') (ftKB) Vertical schematic(actual) Column list(actual) Gamma Ray ,W ,.. �...m,.. _. .... , CC mems Wellbore 37.4 0.0 37.a tern number:1; ^^ Description:Surface Descnption:CASING; 157.8 0.2 157.8 Casing Cement;Depth Depth (M1,5 in;0-2,3 50 1n; � � ', Depth(MD):0.0-2,315.1 (MD).37.0-2,315.0 ftKB; i' ftKB;Length:2,315.07 ft 2,220.8 32.2 2,113.1 Date:1/1/2011 Item number:2; 2,313.3 34.1 2,190.3 z.. MI+' Description:CASING; OD:10 1J4 in;ID:8.681 in; 4,309.1 72.2 3,472.0 Description:DeepCrete; , Depth(MD):0.0-5,600.6 Depth(MD):3,220.0- *; fKB;Length:5,600.59 ft 5,308.1 84.6 3,647.2 5,600.0 ftKB; r., ae.Dms 2msnlaAmsn � asva. Date:116Q011 13.311.SURr*c E CASINO 5,598.1 84.5 3,677.7 5,904.5 88.2 3,691.2 6,204.1 88.1 3,700.5 6,476.7 88.7 3,706.7 6,721.8 85.9 3,718.4 7,009.5 64.1 3,743.3 rulau,Trow^oulIxlob a pi,. b�"p 1ccorca ss ssar INTERMEDIATE CASINO 7,253.0 87.0 3.762.5 7,497.7 86.4 3.776.8 7,740.5 87.8 3,790.6 7,981.6 83.8 3,807.7 8,220.1 84.4 3,834.4 8,521.0 87.4 3,857.5 Rem number:3; 8,827.8 90.1 3,seo.s Description:LINER;OD:5 3/4 in,ID'0,000 in;Depth (MD):5,425.3-12,315.0 9,071.2 91.0 3,859.2 ftKB;Length 6,889.72 ft 9,315.6 89.5 3,859.7 9,557.4 89.0 3,862.7 9,797.6 90.4 3,862.2 10,124.0 88.9 3,859.7 10,368.1 86.2 3,871.2 10,690.3 87.0 3,888.6 10,933.4 86.9 3,900.3 11,176.2 91.5 3,902.2 11,462.9 89.0 3,896.9 11,732.3 88.3 3,905.4 12,016.1 87.7 3,915.3 I 12,078.1 87.7 3,917.8 I 12,313.0 88.8 3,924.4 i IS ' :Ji' 'rgT Drilling &Measurements MWD/LWD Log Product Delivery Customer ENI US Operating Co. Inc.Alaska Dispatched To: Chrisitine Shartzer Well No 0107-04 Date Dispatched 21-Jan-11 Installation/Rig Nabors 245E Dispatched By: Shailesh Prithani Data No Of Prints No of CDs 0107-04-Logs: 1 2inMD 1 2 in TVD 1 R EC D FEB 07 2011 aro-15" k -sit,-,g1 Gac Cao COrritnini0 00 J O —C) Received By: Please sign and return one copy to: D&M,2525 Gambell Street,Suite 400 Anchorage,Alaska 99503 sprithani(&slb.com Shailesh Prithani Fax:907-561-8317 LWD Log Delivery V2.1,03-06-06 �'p c) (4))- tJ IA eni =nil Pketirolleuirn NIKAITCHUQ 0107-04 OLIKTOK POINT,ALASKA SAMPLE MANIFEST From: ENI Petroleum, 01/13/2011 C/O Caruig Drilling Technologies 301 E. 92" Ave. Anchorage AK 99515 To: AOGCC 333 W. 7th Ave; Suite 100 Anchorage AK 99501 Attn: Howard Oakland (907) 739-1235 Total Shipment consists of eight boxes of washed and dried samples taped into two bundles(A and B).im� Samples were taken at 30' intervals. Bundle A: Box 1: Samples from 1,000' —2,500' tox 2: Samples from 2,500' —4,000' fox 3: Samples from 4,000' —5,500' '-Box 4: Samples from 5,500' —7,000' Bundle B: -rim 5: Samples from 7,000' —8,500' fox 6: Samples from 8,500' — 10,000' 4:k )) C ,Z_ )3ox 7: Samples from 10,000' - 11,530' Box 8: Samples from 11,530' - 12,325 TD Please notify sender upon delivery: Canrig(907) 670-8529; ENI(907)670-8530; or Andrew Buchanan(907) 865-3388, Anchorage ENI. See accompanying freight b'll of lading. Expediter signature (__)1 Date cl 36.. 1,1 d; 1a - ism Page 1 of l L Maunder, Thomas E (DOA) From: Quay Walter [Walter.Quay@enipetroleum.com] Sent: Monday, December 27, 2010 10:47 AM To: Maunder, Thomas E (DOA); Keener Jack Cc: DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Subject: Re:AOGCC Notification 0107-04(210-153) Frank, Here is the acknowledgement from the AOGCC. One clarification, the diverter will not be rigged up, as per the waiver on the drilling permit. Walter Sent from my iPad On Dec 27, 2010, at 10:16 AM, "Maunder, Thomas E (DOA)" <tom.maunder@alaska.gov> wrote: Walter, I acknowledge your message. The Inspector will be back on the slope later today. I am waiving witness of the upcoming diverter test. Please have the crew conduct the test as usual and send in the results. Call or message with any questions. Also, please include the permit number in the subject line as have here. Tom Maunder, PE AOGCC From: Quay Walter [mailto:Walter.Quay@enipetroleum.com] Sent: Monday, December 27, 2010 9:18 AM To: Maunder, Thomas E (DOA) Subject: Fwd: AOGCC Notification 0I07-04 Tom, As per our telecom, we are progressing towards spud on 0107-04 well(PTD 210153) Sent from my iPad Begin forwarded message: From: Keener Jack<jack.keener cr enipetroleum,com> Date: December 27, 2010 9:03:19 AM AKST To: Quay Walter<Walter.Quay_u enipetroleum.com> Cc: Longo Joseph <joe,longo@enipetroleum.com> Subject: AOGCC Notification Walter, I called AOGCC on 12-25-10 @ 1720 hrs and left the following information. "Frank Cormier with ENI Petroleum, Nabors 245E intend to spud well 0107-04 on 12-28- PM". Currently the time could move up to 12-28-10 AM. SMITE OTi nLASEA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSIONT ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Maurizio Grandi Well Operation Project Manager ENI US Operating Company Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Nikaitchuq Undefined Oil Pool, 0107-04 ENI US Operating Company Inc. Permit No: 210-153 Surface Location: 3201.2' FSL, 1568.9' FEL, SEC. 5, T13N, R9E, UM Bottomhole Location: 2292' FSL, 307' FEL, SEC. 29, T14N, R9E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced service well. An Area Injection Order must be approved by the Commission prior to any injection operations. 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, Pi Daniel T. Seamount, Jr. Chair DATED this2[ day of October, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) PECEIVEN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OFT 1 ',.?• lO iO PERMIT TO DRILL 20 AAC 25.005 Nage 0i!&Gs CPS COMM* la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj 0 . Single Zone ❑ lc.Spec' s roposed for: Drill ❑ - Redrill 1I1 Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone 111Coalbed Gass Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑✓ Single Well ❑ 11.Well Name and Number: ENI US Operating Co Inc Bond No. RLB0008627 • 0107-04 . 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 _ MD: 12231' TVD: 3884' Nikaitchuq 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 3201.2 FSL 1568.9 FEL S5 T13N R9E UM / ADL 355024,373301,390616. Top of Productive Horizon: ,/7 'F$L ,66,c� 8. Land Use Permit: 13.Approximate Spud Date: 3, F8C3,�5-FEr32 T14N R9EUM f ri7 , /c/( ADL 417493 12/6/2010 Total Depth: 9.Acres in Property: 14.pistance to Nearest Property: 2292 FSL 307 FEL 29 T14N R9EUM 1280 'to unit boundary W!! ...,x'i.5 i •i' ' y,/Z' 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- 516711 . y- 6036554 • Zone- 4 GL Elevation above MSL: 12 feet to Same Pool: 1135'West to OPO4-07 • 16.Deviated wells: Kickoff depth: 500 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 92° degrees Downhole: 1606 psig , Surface: 1205 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 _ 84 36 36 120 120 pre-installed 16" 13-3/8" 68 L-80 BTC 2245 35 35 2280 2173 1195 sx 10.7#ASL,313 sx 12.5#Deeperete 12.25" 9-5/8" 47 L-80 BTCM 5227 33 33 5260 3670 605 sx 12.5#Deeperete 8.5" 5.5" 17 L-80 hydril 521 7171 5060 3656 12231 3884 Slottled 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 Q BOP Sketch U] Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis0 Diverter Sketch❑., Seabed Report ❑ Drilling Fluid Program Q 20 MC 25.050 requirements 2 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Jason Brink @ 907-865-3321 I Printed Name Maurizio/ Grandi Title Well Operation Project Manager Signature ^�„._, -9 64,0-4k- Phone Date 10 7I�D vw+r Commission Use Only 6 Permit to Drill ,+-- API Number: e r-- Permit A r See cover letter for other Number: i-/CD -> 50- L>�7--' ''�-....JD -C �Dater VC> requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce co bed methane,g s hydrates,or gas contained in shales: d, Other: 4, 3500 r s4 eo p fey/- Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ o [e' /_ r_.� (N.�,�•`,H2S measures: Yes ❑ No Q/ Directional svy req'd: Yes ['No ❑ 0- 2,506 ,s ci Alla j44 C; -� M r f wai is eJ 2 0 Al c. Z 5 a 35 C L )(z ) 6144.41t:0' i�,n►..4. _ i1 L) r� ire. Pt L K. a a l_ •. 1"�1. d , APPROVED BY THE COMMISSION /D4///0 DATE: ,COMMISSIONER ` /° 73.,ORIGINAL ' 00 (-_-.; Form 10-401(Revised 7/2009) Thisermit is valid for 24 months from the date of approval pproval(20 AAC 25.005(g)) Submit in Duplicate %Is Oliktok Point Nikaitchuq Field e ' p roll urn 0107-04 (P4) Alaska DIR I LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD MD TVD SIZE SPECS Hazards Cement to Surface 20" Hole Angle X-65 0° 20"Conductor Shoe 160' 160' N/A Welded/Driven N/A 0 GR/Res Surface Csg Dir s 13-3/8" m Base Permafrost 1,909' 1,853' D 68 lbs/ft MW(ppg) Wellbore Stability Mud Motor r- L-80,BTC 8.8-9.5 Lost Circulation Hole Cleaning KOP:400' DLS: 1.5-3.5 deg/100' 13-3/8"Casing Point 2,280' 2,173' 1111116 16" 50°F WBM GR/RES PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Xceed 900 47 lbs/ft MW(ppg) Hole Cleaning L-80,BTC-M 8.8-9.5 Torque&Drag Sail Angles: 1 I 67 degrees 1 z w "N"Sand Top 4,349' 3,479' Injection Packer 4,400' NOTE: Injectors REQUIRE GBL on Intermediate Casing TOL 5,060' 9-5/8"Casing Point t 5,260' 3,670' Ami r 12-1/4" 85"F LSND GR/RES PWD Wellbore Stability Option to run sonic Lost Circulation for int.casing CBL Schrader Bluff Slotted Liner Hole Cleaning Lateral 5-1/2" Torque&Drag 17lbs/ft MW(ppg) Xceed 675 L-80 8.8-9.0 (Geo-Steering) Hydric 521 5-1/2"Slotted Liner TD 15-1/2"Lnr 12,231' 3,884' 8-1/2" 85"F MOBM Davies, Stephen F (DOA) From: Brink Jason (jason.brink c@enipetroleum.com] Sent: Wednesday, October 13, 2010 11:29 AM To: Davies, Stephen F (DOA) Subject: ENI: Correction to 10-401 form for well 0107-04 Steve: I mistakenly put the OA sand top in for"top of productive horizon location". The accurate top would be the 9-5/8" casing shoe. Corrections are as follows: 4a. Location of well: Top of Productive Horizon 612 FSL 360 FEL 32 T14N R9EUM 14. Distance to nearest property: 612'to unit boundary Jason Brink Drilling Engineer ENI Alaska Office: 907-865-3321 Cell: 907-947-3790 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. 1 PECSIVE0 trot• 70in Pr Alaskan Anchlorap 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Maurizio Grandi Phone(907)865-3320 Email: Maurizio.Grandi@enipetroleum.com September 30,2010 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Injector 0107-04 Dear Commissioners, i ✓ ENI US Operating Co. Inc. hereby applies for a Permit to Drill for the onshore injector well 0107-04.The well will be drilled and completed using Nabors rig 245E. The planned spud date is 12/6/2010. Please find 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 Jason Brink at 907-865-3321. Sincerely, 0 C� aurizio Grandi Well Operation Project Manager Em Petrolleum eno Application for Permit to Drill 0107-04 Saved:5-Oct-10 Application for Permit to Drill Document Injector Well 0I07-04 Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Please see Attachment 7: Surface Platt 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005(c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25.005(c)(5) 4 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (extended bentonite) 5 Intermediate Hole Mud Program (LSND) 5 Lateral Mud Program(Ml VersaPro LS Mineral Oil Base) 5 9. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005(c)(9) 5 10.Seismic Analysis 6 Requirements of 20 AAC 25.005(c)(10) 6 11.Seabed Condition Analysis 6 0107-04 PERMIT Document.doc enn EnN � Application for Permit to Drill 0107-04 Saved:5-Oct-10 Requirements of 20 AAC 25.005(c)(11) 6 12.Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 13.Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 14.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 15.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 BOP and Diverter Configuration 7 Attachment 4 Cement Loads and CemCADE Summary 7 Attachment 5 Well Schematic 7 Attachment 6 Formation Integrity And Leak Off Test Procedure 7 Attachment 7 Surface Platt 7 1. Well Name Requirements of 20 AAC 25.005(i) 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: 0I07-04 2. Location Summary Requirements of 20 AAC 25.005(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 3201.2 FSL 1568.9 FEL S5 T13N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 53.2'AMSL • Northings 6036554.420' .Eastings: 516711.030'- Pad Elevation 12'AMSL • Location at Top of Productive Interval 337 FSL 365 FEL 32 T14N R9EUM ("OA"Sand) 0107-04 PERMIT Document.doc Pana 9/)f 7 PetiroOeum E M Application for Permit to Drill 0107-04 Saved:5-Oct-10 ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 4984' Northings: 6038972.080' Eastings:517901.870' Total Vertical Depth, RKB: 3650' Total Vertical Depth, 55: 3598' Location at Total Depth 2292 FSL 307 FEL 29 T14N R9EUM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 12231' Northings: 6046207.000' Eastings: 517922.000 Total Vertical Depth, RKB: 3884' Total Vertical Depth, 55: 3831' Please see Attachment 7: Surface Platt and (0)other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(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 (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 AAC 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 AAC 25.036, or 20 MC 25.037, as applicable; Please see Attachment 3: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 AAC 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: (9)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 0.44 psi/ft, or 8.5 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 = (3650 ft TVD)(0.44 - 0.11 psi/ft) = 1,205 psi (B)data on potential gas zones; 0107-04 PERMIT Document.doc Page 3 of 7 ir.4.041 • inn PetiroHeuim Application for Permit to Drill 0107-04 Saved:5-Oct-10 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 AAC 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 25.030(17; Please see Attachment 6: Formation Integrity And Leak Off Test Procedure 6. Casing and Cementing Program Requirements of 20 AAC 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 Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 178.89 X-65 Welded 120 36/ 36 1207 120' Cemented to surface Cemented to Surface with 1195 sx 10.7#ASLite Lead 13-3/8 16 68 L-80 BTC 2245' 35 / 35 2280'/ 2173' Yield 2.25 cu. Ft./sk, 313 sx 12.5#DeepCRETE Tail Yield 1.54 cu.ft./sk Cement Top planned @ 3349'MD -p c. Cemented w/605 sx 12.5# 9-5/8 12-1/4 47 L-80 BTCM 5227' 33/ 33 5260'/ 3670' DeepCRETE tom• Yield 1.54 cu.ft./sk 8-1/2"OA - 5-1/2 Sand 17 L-80 Hydril 521 7171' 5060'/ 3656' 12231'/ 3884' Slotted Liner-no cement NI Lateral sA') 7. Diverter System Information t ,fo Requirements of 20 AAC 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 MC 25.035. (h). (2). D(` 0107-04 PERMIT Document.doc Page 4 of 7 41 Enft Petirolleuim �11� Application for Permit to Drill 0107-04 Saved:5-Oct-10 8. Drilling Fluid Program Requirements of 20 AAC 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 sl) 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 (LSND) Lateral Mud Program (Ml VersaPro LS Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value Density(ppg) 8.7-9.3 Density(ppg) 8.8 - 9.5 Plastic Viscostiy Funnel Viscosity (CP) 15-25 (seconds) 45 - 60 Yield Point 15-20 Plastic Viscostiy 12 - 18 (Ib/1005 fl (CP) HTHP Fluid loss Yield Point 18-24 (ml/30 min @ <5.0 (lb/100 st) 200psi 8 100°F API Filtrate Oil/Water Ratio 75/25 (cc/30 min)) 4 - 6 Electrical >600 Chlorides (mg/I) <500 Stability pH 9.0- 10.0 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 AAC 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: (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(f); 0107-04 PERMIT Document.doc Pni.n r,of 7 411* enil• Eno PetirolleLuim Application for Permit to Drill 0107-04 Saved:5-Oct-10 Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seismic Analysis Requirements of 20 AAC 25.005(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 25.005(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 ng, 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 25.005(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 25.005(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. 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. PU 12-1/4" bit and directional drilling assembly with MWD, LWD and PWD. f(T 8. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording 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. . r 11. Run and cement 9-5/8", 47# L80, BTC Mod casing. Pump cement and displace with mud, land casing hanger and bump plug. 0107-04 PERMIT Document.doc forios • En Petirolleum 2�lln Application for Permit to Drill 0107-04 Saved:5-Oct-10 12. Install 9-5/8" packoff and test to 5000 psi. 13. Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 14. Pressure test casing to 3000 psi per AOGCC regulations. Record results. SoNtc- 6-r 15. PU 8-1/2" bit and directional drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. 16. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording results. 17. Directionally drill 8-1/2" hole to TD as per directional plan. Pull out of hole backreaming to casing shoe. 18. PU and run 5-1/2"slotted liner to TD. 19. Land liner, set liner hanger with 200' Liner lap inside the 9-5/8" intermediate casing. POOH laying down DP as required. .20. RU E-line and run CBL logging cement bond of Intermediate Casing_ May be able to run LWD sonic in Production hole drilling BHA in place of E-line to log cement bond. • 21. PU Injection packer and 4-1/2"tubing as required and RIH to depth. Set Injection Packer and Land tubing. Set BPV. 22. Nipple down BOP, nipple up tree and test. Pull BPV. 23. Test IA to 2500 PSI and chart for 30 minutes. 24. Freeze protect well with diesel to the base of the permafrost. , 25. Set BPV and 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 AAC 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. 15.Attachments Attachment 1 Directional Plan 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 Attachment 8 Quarter Mile Plot 0107-04 PERMIT Document.doc el 0 C j- Om^b^�bh bmb74bOb 28,'48% ObNb ONb Nb1bO Nb7- NbbEinNb bnnbbEb% bbpb8 8 Ob NI*,,,,S! % .,78 <b N n q mn V . UtOp qNq d0 Mil init. N<nnNh N^n Na bbb 2 a O a- N N8"8', b'On In r:70: b El o b 0 c' ddb, N • OA00 ,'°F. 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N O 0 0 0 0 0 «< 3 (u)0091:(w)1=aleog M >>> 0094 000£ 009E 0 009 L- 000E- 310 0 001/9'1 P18 dON 0 001/91 P18 001/9.0 N� 001/91 5113 •63..9/C-C1 uPu3 009E 009E oourC o4 ^l3 pu3 I00H 00-L010 •63..919.6 000E 001/Z np 000£ 543 pia 001/Z 543 Z 161 00-L010 0011/Z nL3 wr3 Du3 A C161 00•L010• A nL3 pu3 0094 094471u0 ••• 0094 (n ►161 00•L010 2 u3 pu3 N 001/Z N3 II 9161 mL010 001/Z.3 543 pu3 3' 916100-L010 (.71O nLO W3 0009 001/Z ma 0009 L461 ro-L010 Z 0014 n13 543 pu3 V 91611,0-L010 V V n.3 pu3 001/Z 543 6161►0•L010 001/Z/U3 nL3 pu3 OOSL of 161 memo: 009L 543 pu3 001/Z AL3 11161 90-L010 001/Z n13 543 pu3 Z11611,0-L010 543 Pu3 • 0006 •9uz Na t D4 0006 • C11819o-c010 wa3 Pug V4'D' (rd)PO-L010 cu. 00901 00901 00E-O0094 000E 009E 0 0091.- 000E- am.et mou.s LOZ'011.9u1•pK-•Ma (1d150100 tr•(d ZOOMS'S°0.3 0'S Sn9[0111915 '.6u503 05116156.50 �l 15011915 SA .69512 '0.06.5 (lSW•^09•YZ Z51i9.1ti•5N M9 an1 CO40 NIS .1,CZL69Z10 51.3 0,0 sn9001999509 OuNY%Z SOL SOOt OL N 1.1 0102'11 upuauN •u0 •16609 .0 OtOZ 5009 I•PMY snowe9•�uW 1••3 sn'10•u•Z'Iu•y•1*S•K•P/LZa2N *Mtn °'•wW d 5659 1u!Od )loP I!IO bn43i!eA!N (Pd)P0-L010 3.1110(1919 01313 113M oua aaOaaquinlga3 • SdioniM7er 0107-04 (P4) Anti-Collision Summary Report Analysis Date-24hr Time: September 17,2010-10:34 Analysis Method: Normal Plane Client: ENI Reference Trajectory: 0107-04(P4)(Def Plan) Field: Nikaitchuq Depth Interval: Every 10.00 Measured Depth(ft) Structure: Oliktok Point Rule Set: D&M An9Collison Standard Slot: OP07 Min Pts: All local minima indicated. Well: 0107-04 Borehole: 0107-04 • Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Restricted within 40000 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 Del-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 OP08-04(Def Survey) Warning Alert 7.36 4.91 4.03 5.00 238.86 238.86 OSF<5.00 MinPt-O-ADP 1. I 7.27 4.68 3.94 4.42 258.82 258.82 MinPt-CtCt I 7.50 4.49 3.60 3.52 288.75 288.75 MinPt-O-EOU 7.74 4.52 3.53 3.27 298.72 298.72 MinPt-O-ADP 9.53 5.50 4.09 2.961 338.56 338.56 MinPt-0SF 33.26 25.56 22.32 4.95 607.86 607.85 OSFv5.00 Exit Alert 56.68 45.39 40.36111Maini 834.38 833.57 MinPt-O-SF 85.61 68.23 6016]_ ja 1072.15 1067.37 MinPt-O-SF 108.89 86.79 76.3511'' 1192.49 118371 MinPt-O-SF 1315.31 1255.95 1226.76.1En 5304.16 3671.40 MinPt-O-SF 1305.7 1244.08 1213.75 21.51 5646.35 367424 MinPt-CtCt 1305.8 1243.8 1213.38 21.39 5676.35 3674.25 MinPt-O{OU 1306.03 1243.9 1213.36 21.35 5686.34 3674.25 MinPt-O-ADP 133541 1270.02 1237.82 20.7 6195.07 3674.33 MinPt-O-SF 1366.76 1297.71 1263.67 20.01 6741.33 3693.65 MinPt-0-SF L1352.01' 1277.70 1241.03 18.42 7321.00 3732.91 MinPt-CtC1 1352.21 1277.344 1240.36 18.27 7360.91 3736.14 MinPt-0{OU • 1352.63 1277.4 1240.2 18.21 7380.84 3737.76 MinPt-O-ADP 136746 1289.52 1251. 17.761 7599.06 3755.84 MinPt-O-SF 4192.59 4069.05 4007.77 34.20 10190.40 3841.73 TD 0P08-04P61(Def Survey) Wamtng Alert 7.36 4.91 4.03 5.00 238.86 238.86 OSF<5.00 MinPt-O-ADP r 7.27 4.68 3.94 4.42 258.82 258.82 MinPt-CICt 7.50 4:49 3.60 3.52 288.75 288.75 MinPt-O-EOU I 7.74 4.52 3.53 3.27 298.72 298.72 MinPt-O-ADP 9.53 5.50 4.09 2.96) 338.56 338.56 MinPt-0-5F 33.26 25.56 22.32 4.95 607.86 607.85 OSF05.00 Exit Alert 56.68 45.39 40.36® 834.38 833.57 MinPt-O-SF 85.61 6823 60.16'® 1072.15 1067.37 MinPt-O-SF 108.89 86.79 76.351 8 1192.49 1183.71 MinPt-O-SF 1315.31 1255.95 1226.7 lmom- 5304.16 3671.40 MinPt-O-SF 1305.7 1244.08 1213.75 21.51 5646.35 3674.24 MinPt-CtCt 1305 8 1243.89' 1213.38 21.39 5676.35 3674.25 MinPt-O-EOU 1306.03 1243.9•`,11 1213.3 21.35 5686.34 3674.25 MinPt-O-ADP 1335.41 1270.02 1237.81 20.7 6195.07 3674.33 MinPt-O-SF 1386.76 1297.70 1263.6 20. 6741.33 3693.65 MinPt-0-SF 1352.01 1277.69 1241.02 18.42 7321.00 3732.91 MinPt-CtCt 1352.2 1277.331 1240.35 18.27 7360.91 3738.14 MInPt-O-EOU 1352.63 1277.4 1240.2 18.20 7380.84 3737.76 MIeP1-0-ADP 136746 1289.51 1251.0 17.751 7599.06 3755.84 MinPt-O-SF 2163.89 2064.63 2015.49 22.01 8931.54 3842.35 TD OP09-S03(P2)(Del Plan) Warning Alen 16.00 14.78 1268 N/A 0.00 0.00 Surface 15.80 11.62 10.15 4.94 450.00 450.00 OSF<5.00 MinPt-O-ADP ® 8.78 6.90 3.33 619.51 619.49 MinPt-CtCt 14.15 MIKE 6.12 2.85 669.26 669.19 MinPt-0-EOU 15.4• 10 5.54 2.45 719.04 718.85 MinPt-0-EOU 17.26 8.83® 2.23 758.88 758.54 MinPt-O-ADP 20.22 10.0 ®. 212 808.69 808.07 MinPt-O-ADP 25.55 12.55 6 664 878.46 877.23 MinP1-0-SF 32.04 15.76 8.23 ; 948.25 946.09 MinPt•0-SF 4426 22.00 11 481MHZ 1057.93 1053.53 MinPt-O-SF 61.57 30.56 15.68 IIMZE 1187.54 1178.95 MinPt-O-SF 206.29 163.81 143.18 4.97 1980.57 1916.34 OSFv5.00 Exit Alert 1353.01 1266.85 1224.27 15.87 6518.65 368487 MinPt-CtCt 1354.1 1262.71 121747 14.96 6773.42 3695.48 MinPt-O-EOU 1361. 1261.74 1212.18 13.73 7177.07 3722.18 MinPt-0-EOU 1363.46 1261.921644 13.55 7243.18 3726.66 MinPt-O-ADP 1372.48 1264.40 1210.85 12.81 7547.93 3751.29 MinPt-O-ADP 1412.34 1285.13 1222.02 1118 8516.61 3844.36 MinPt-O-ADP 1437.76 1306.81 1241.83 11.061 8754.16 3847.68 MinP1-0-SF 5341.91 5162.70 5073.58 29.97 12231.88 3884.10 TD 0111.01(P6)(Def Plan) Warning Alert 31.99 30.77 28.67 N/A 0.00 0.00 Surface I 31.81 27.31 25.68 9.35 509.91 509.91 MinPl-C1Ct 31.88 27.22 25.50 8.91 539.69 539.69 MinPt-O-EOU 31.95 27.23 25.491 8.79 549.61 549.61 MinPt-O-ADP 64.65 50.66 44.28 4.97 933.01 931.08 OSF<5.00 MinPt-O-ADP 109.83 83.57 71.06 MEE 1134.42 1127.78 MinPt-0-5F Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ttd EOU(ftL Dev.(86)_ Fact. _ MD(ft) 1 TVD(ft) Alert I Minor 1 Major 144.77 114.67 100.23 4.97 1246.74 1235.59 OSI-5 00 Exit Alert 2180.81 2112.0 2078.19 32.17 4979.34 3650.15 MinPt-O-EOU 2183.13 2112. 2077.6 31.31 5115.59 3661.63 MinPt-O-ADP 2635.94 2534.94 2484. 26.3 6746.48 3693.92 MinPt.O-SF 2730.87 2626.09 2574.1 26. 7019.43 3711.75 MinPt-0-SF 5521.64 5372.76 5298.81 37.33 9569.27 3834.68 TD OP10-09(P2)(Det Plan) Warning Alert 2399 22.77 20.87 N/A 0.00 0.00 Surface t 23.30 19.41 18.08 8.26 439.89 439.89 MinPt-CtCt 23.45 19.18 17.66 7.31 479.78 479.78 MinPt-O-EOU 23.91 19.22 17.49 6.55 509.62 509.62 MinPt-O-EOU 24.17 1928 17.441 6.26 519.54 519.54 MinPt-0-ADP 30.12 23.05 20.12 4 94 618.64 618.62 OSF<5.00 MinPt-O-ADP • 34.15 26.12 22.72 MEM 658.22 658,16 MinPt-0SF 4182 32.19 28.09 0.11w 717.56 717.38 MinP40-SF 48.94 38.15 33.37 4 99 766.96 76659 OSF>5.00 Exit Alert 57.13 44.85 39.331 I4: 816.30 81563 MinP1-0SF 82.10 64.67 56.57 4.99 944.13 942.03 OSF45.00 MinPt-O-ADP 148.25 115.49 99.72 MEMO 1185.95 1177.43 MinPt-O-SF 172.09 136.46 119.26 4.97 1252.12 1240.71 OSF>5.00 Exit Alert 2938.10 2869.29 2835.3:magG 5180.03 3665.00 MinPt-O-SF 3061.81 2990.42 2955.2 i --„ 5425.28 3674.20 MinPt-0-SF 3264.67 3188.87 3151.46:MUM�1 6726.37 3674.25 MinPt-O-SF 3587.43 3503.79 3462 47'i 0 6189.83 3674.32 MinPt-0-SF 3977.96 3885.34 3839.531mm 6700.06 3691.83 MinPt-O-SF 4371.47 4268.95 4218.19':.! 7217,84 3724.88 MInPt-O-SF 4622.95 4513.88 4459.83' 7550.17 3751,48 MinPt-0-SF 5742.80 5601.53 5531.39-MEM 9122.57 383427 MinP1-0-SF 6228.25 6073.50 599661! 9742.13 3836.33 MinPt-O-SF 6520.08 6356.30 6274.9r=ED0' 10126.81 3840.27 MinP1-0SF 7785.74 7600.58 7508.50 MUM 11254.51 3890.74 MinPI-0-SF 9283.14 9086.64 8988.89 47.48 12231,88 3884.10 TD 0106-05(P5)(Def Plan) Pass 16.00 14.77 12.67 N/A 0.00 0.00 Surface Man 12.18 10.88 5.69 400.00 400.00 MinPt-C1Ct 16.07 MEC 10.49 5.11 489.99 489.99 MinPt-O£OU 16.09 11.95 mE.: 5.09 49999 499.99 MInPt-O-ADP 16.12 11,96 10. r'' 510.02 510.02 MinPt-0-SF 18.91 14.22 124•IIIMME, 669.95 669.87 MInPt-0-SF 23.35 17.83 15.67.;, 719.40 719.21 MinPt-0-SF 1092.97 1061.46 1046 20'IMEME1 2866.68 2583.10 MinPt-0-SF 1114.28 1082.19 1066 6-MEW 2908.42 2610.13 MinP1-0SF 1156.24 112290 1106.72® 2990.87 2663.52 MinPt-0-SF 1176.94 1143.04 1126 5:IMEEE 3031.49 2689.82 MinPt-0-SF 1350.44 1311.46 1292.46'©- 3351.96 2897.34 MinP1-0SF 1392.15 1352.00 1332.41''. 3424.03 2944.01 MinPt-0SF 3021.81 2927.06 48.29 5292.28 3670.85 MinPt-0-EOU 3021.90 2958.3'MEM 5305.92 3671.48 MinPts 3021.80 2958.2,.111MEM 48.31 5362.95 3673.40 MinPt-0-ADP • 3021.7!ELME 2927.02 48.32 5380.57 3673.76 MinPt-0-EOU MirEW 2958.29 2927.03 48.32 5389.38 3673.90 MInP1-CtCt 2955.52 2922.56 45.83 605145 3674.30 MinPl-CtCt 3022.4 MKZIEE 2921.06 45.13 6181.17 3674.32 MinPt-0-EOU 3022.49 2954.5 4'- r$ 6191.28 3674.32 MinPts 2629.22 2523.96 2471.:.I® 9201.34 3832.02 MinPt-0-SF 2608 0 2500.14 2446.69 24.39 9552.27 3834.52 MinPt-CtCt r 2608 6 2497.87 2442.99 23.76 9708.75 3836.01 MinPt-CICt 2608.71 tr'mum mom 10132.60 3840.35 MinPts 2468.57 239944 18.86 11252.95 3890.72 MinPt-CtC1 2609.11 Magi,NEM mEmo 12231.88 3884.10 MinPts Oliktok Point 1-2PB1(Def Survey) Pass 48.51 47.39 45.18 N/A 0.00 0.00 Surface MOM 47.3'NM= N/A 40.00 40.00 MinPts 45.91 41.84 40.36 15.13 43797 437.97 MinPt-CIC1 46.18 41.55 39.79 12.81 487.65 487.65 MinPt-0£OU 47.15 41.77 3964 10.80 547.69 547.69 MinPt-0-ADP 52.03 45.35 42.57 9.16 657.24 657.18 MinPt-0SF 108.61 98.97 94.70 12.61 916.25 914.56 MinP1-0SF 163.76 149.83 143.42 r- 12.69 1041.68 1037.68 MinPt-0-SF 5185.58 5116.63 508265 76.29 5200.78 3666.09 MinP1-0-SF 5373.98 5302.77 5267 66 76.51 5355.80 3673.22 MinPI-0-SF Oliktok Point 1-2(Def Survey) Pass 48.51 47.39 4518 N/A 0.00 0.00 Surface 48.51 47.39'.1, N/A 40.00 40.00 MinPts 45.91 41.84 40 36 15.13 437.97 437.97 MinPt-C1Ct 46.18 41.55 39.79 12.81 487.65 487.85 MinPt-0-EOU 47.15 41.77 39.64 10.80 547.69 547.69 MinP1-0-ADP 52.03 45.35 4257 9.16 657.24 657.18 MinP1-0-SF 108.61 98.97 94.70 12.61 916.25 914.56 MinPt-0-SF 163.76 149.83 143.42 12.69 1041.68 103768 MinPt-O-SF 5158.33 5089.91 5056.19 76.48 5173.70 3664.67 MinPt-0-SF 5675.47 5601.44 5564.91 77.68 5614.71 3674.24 MinPt-0-SF 6262.95 6179.98 6138.99 76.39 6196.17 3674.33 MinPt-0-SF 6681.60 6590.40 6545.29 74.05 6746.50 3693.92 MinPt-0-SF 7044.59 6944.71 6895.25 71.22 7246.75 3726.93 MinP1-0SE 7348.60 7242.26 7189.59 69.74 7599.62 3755.89 MinP1-0-SF 8708.39 8572.07 8504.40 64.34 9197.32 3832.08 MinPt-0-SF 9307.76 9157.32 9082.60' 62.27 9902.93 3837.98 MinPt-0-SF Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0107-04\0107-04\0107-04(P4) 9/17/2010 1:21 PM Page 2 of 7 • ' 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 • Oliktok Point I.2PB2(Def Survey) Pass 48 51 47.52 45.18 N/A 0.00 0.00 Surface II 47 3•MEE N/A 40.00 40.00 MinPts 1 NOM 41.87 40.41 15.29 437.97 437.97 MinPt-CtCt I 46 18 39.84 12.92 487.65 487.65 MinPt-O-EOU 47.15 41.80 MOM 10.87 547.69 547.69 MinPt-O-ADP 52.03 45.38 42.62=LE 657.24 657.18 MinPt-0-SF 108.61 98.98 94.7 ®i 916.25 914.56 MinPt-O-SF 163.76 149.84 143.,,'x�i.- 1041.68 1037.68 MinPt-O-SF • 5158.33 5089.91 5056.19 117 5173.70 3664.67 MinPt-O-SF 5675.47 5601.44 5564.9240 5614.71 3674.24 MinPt-O-SF 6262.95 6179.99 6139.00 M1310 6196.17 3674.33 MinPt-O-SF 6681.80 6590.40 6545.29® 6746.50 3693.92 MinPt-O-SF 7043.42 6943.54 6894.10®) 7246.12 3726.88 MinPt-O-SF 7345.34 7239.13 7186.52 _69 79i 7601.07 3756.03 MinPt-O-SF 7375.92 7269.39 7216.62 69.88 7633.00 3759.35 TO OP03-P05P61(Del Survey) Pess IIIMIMI 38.60=MD 457.35 68.00 68.00 MinPts MOM 37.791 36 69_I 38.99 243.37 243.37 MinPts 40.16 36 83 30.31 299.00 299.00 MinPt-O-EOU 69.0- 58.991 54 58 7.69 1091.96 1086.63 MinPt-O-EOU 89.81 59 16 i 54 44] 7.28 1133.13 1126.53 MinPt-O-ADP 90.58 73.34 65.33=BM 1448.31 1425.10 MinPt-O-SF 1135.92 1099.02 1081.06 FOR= 3754.64 3158.09 MinPt-O-SF IL 1285 65J 1236.37 1212.22 26.60 4741.13 3607.74 MinPt-CtCt 1285 71 1236.3 1212.08 26.53 4755.38 3611.07 MInPt-O-EOU 128587 1236.3 1212. 26.464769.60 361429 MinPt-O-ADP 1286.41 1236.62 1212.21 26. 4795.34 3619.86 MinPt-O-SF 1330.74 1276.14 1249. 24.81 5209.57 3666.55 MinPt-0-5F 1339.00 1284.13 1257.19 24.83 5288.14 3670.65 TO OP03-P05(Del Survey) Pass 39.91 38.60 36.58 457.35 68.00 68.00 MinPts 4001 37.79E 3669 38.99 243.37 243.37 MinPts 40.16 37 65 36.83 30.31 299.00 299.00 MinPt-O-EOU 69.03 59 99 54.58 7.69 1091.96 1086.63 MinPt-O-EOU 69.81 59.16 54.44 7.28 1133.13 1126.53 MinPt-O-ADP 90.58 73.34 65.33 5.511 1448.31 1425.10 MinPt-O-SF c 113592 1099.02 1081.06 31.5 3754.64 3158.09 MinPt-O-SF 1286.1 M:. 1213.38 26.86 4712.52 3600.77 MinPt-O-EOU 1286.31 1237. IIIIIMEIn1 26.78 4726.81 3604.30 MinPt-O-ADP 1207.93 1144.38 1113.1 r=mg 673967 3693.57 MinPt-O-SF 1207.87 1144. MGM! 19.29 6749.86 3694.10 MinPt-O-ADP 1207.8 �'.rF 1113.06 19.29 6750.77 3694,15 MinPl-O-EOU IMEEM 1144.34 1113.08 19.30 6760.06 3694.67 MinPt-CtCt 1243.29 1174.81 1141.06 mug 7238.70 3726.33 MinPt-O-SF 1267.88 1195.37 1159.61® 7599.42 3755.87 MinPt-O-SF ME 1208.18 1171.90 17.65 7943.78 3806.62 MinPt-CICt 1282.91 mg= 1170.40 17.24 8060.99 3822.61 MinP1-0-EOU 1242.93 1151.15 1105.76 NMI 9203.87 3831.98 MinPt-O-SF 1242.67 1151.0'. 13.70 9232.22 3831.72 MinPt-O-ADP I1210. 1101.63 1047.90 11.25 10485.73 3860.52 MinPt-CtCt 1210.61 1101.07 1046.79 11.14 10545.65 3864.71 MinPt-O-EOU 1218.16 1100.8 1042.61 10.46 10946.52 3883.15 MinPt-O-EOU I 1217.5 1088.54 1024.51 9.50 11533.46 3895.73 MinPl-CtCt 12182 1087.011 1021.911 9.351 11637.44 3897.59 MinPts OP03-P05PB2(Del Survey) Pass Map 38.60 MEM 457.35 68.00 68.00 MinPts MEM 37.79' j 38.99 243.37 243.37 MinPts 40.16=Mal 36.83 30.31 299.00 299.00 MinPt-O-EOU 69.0 i s 54.58 7.69 1091.96 108663 MinPI-0-EOU I 69.81 5916 INEZ= 7.28 1133.13 1126.53 MinPt-O-ADP 90.58 73.34 65.33 MEM 1448.31 1425.10 MinPt-O-SF 1135.92 1099.02 1081.06,. 3754.64 3158.09 MinPt-O-SF 1286.1 IIIME 1213.38 26.86 471252 3600.77 MinPt-O-EOU 1286.31 1237.3•i® 26.78 4726.81 360430 MinPt-O-ADP 1207.93 1144.38 1113.1 r I 1r r1 6739.67 3693.57 MinPt-O-SF 1207.87 1144.3 ..MIDECI 19.29 6749.86 3694.10 MinPt-0-ADP 1207.8 1113.06 19.29 6750.77 3694.15 MinPt-O-EOU MEM 114434 1113.08 19.30 6760.06 3694.67 MinPl-CtCt 1243.29 1174.81 1141..•MEM 7238.70 3726.33 MinPt-O-SF 1267.88 1195.37 1159.61® 7599.42 3755.87 MinPt-O-SF 1281.7 1208.18 1171.90 17.65 7943.78 380662 MinPt-05Ct 128291 1207.5 117040 17.24 8060.99 3822.61 MinP1-0-EOU 1235.0 114310 1097.64 13.5 9294.06 3832.05 MinPts OPO4-07(Def Survey) Pass ® 28.64I� 22.27 278.84 278.84 MinPts 31.32 MEM 27.80 19.64 318.84 318.84 MinPt-O-EOU 31.45 28.59® 18.51 338.84 338.84 MinPt-O-ADP 49.48 42.12 39.0',)1 802.10 801.52 MinPI.O-SF 54.50 46.39 42.95 la1, 852.70 851.72 MinPt-O-SF 61.89 53.02 49.2. 913.21 911.56 MinPt-O-SF 113.22 96.61 88.91 1.111111M 1195.49 1186.59 MinPt-OSF I 1002.61 918.43 876.83 12.04 8574.17 3845.30 MinPt-CtCt 1003.96 917 26 874.40 11.70 8680.46 3847.04 MinPt-O-EOU 1009.12 917 84 87269 11.16 8900.76 3843.65 ' MinPt-O-ADP 1017.98 921.51 874.37 10.70 9122.64 3834.26 MinPt-O-ADP 1020.16 923.11 875.07 10.64 9209.34 3831.91 MinPl-O-SF 1037.01.MOM 879.85 9.95 9743.79 3836.35 MinPl-O-EOU 1040.0 `"1 876.10 9.56 9993.39 3838.90 MinPt-O-EOU I Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0107-04\0107-04\0107-04(P4) 9/17/2010 1:21 PM Page 3 of 7 1 • • 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 1040.79 930 56L 875.931 9 52 10023.38 3839.21 MinPt-0-ADP 1048.06 935 70 880 01 9 4011. 10193.81 3841.85 MinPt-O-SF 1139.0 993 51 921 24 7 87 12231.88 3884.10 MinPts 0PO4-07P81(Def Survey) Pass ® 28.6'11 22.27 278.84 278.84 MinPts 31.32 27.80 19.64 318.84 318.84 MinPI.O-EOU 31.45 28.59 MAE 18.51 338.84 338.84 MinPl-O-ADP 49.48 42.12 39.041 802.10 801.52 MinPt-0SF 54.50 46.39 42.95, 852.70 851.72 MinPt-O-SF 61.89 53.02 49.2.;' . 913.21 911.56 MinPt-0-SF 113.22 96.61 88.911 1195.49 1186.59 MinPI.O-SF 100261 918.45 876.86 12.04 8574.17 3845.30 MInPI-CICt 100396 917.29 874.44 11.70 8680.46 3847.04 MinPt-O-EOU , 1009.12 917.86 872.72] 11.17 8900.76 3843.65 MinPt-0-ADP 1017.98 921 94 87441 10 70 9122.64 3834.26 MinPt-0-ADP 1020.16 923.13 875.111 1061 9209.34 3831.91 MinPt-0-SF 1037.01=MIR 879.89 9.95 9743.79 3836.35 MinPI-0-EOU 1040.0 930 461 876.15 9.57 9993.39 3838.90 MinPt-0-EOU 1040.79 930.51' '.. 9 52 10023.38 3839.21 MinPt-O-ADP 1048.06 935.74 880.06 1. 10193.81 3841.85 MinPt-O-SF 1111. ' 979 611 11411.86 3893.56 MinPts OP15-08(P3)(Def Plan) Pass 80.02 78.79 76.69 N/A 0.00 0.00 Surface 1 77.38 76.67 55.79 250.00 250.00 MinP1-CtCt 80.14® 76.35 46.15 30000 300.00 MinPt-0-EOU 80.26 77.221 43.56 320.00 320.00 MinPt-O-ADP 113.03 103.25 98.97 Mall 691.20 691.09 MinPt-O-SF 320.68 303.08 294.8•®' 1111.42 1105.51 MinPt-O-SF 6628.17 6558.00 6523.41 MK= 5175.90 3664.79 MinPt-O-5F 6971.45 6897.59 6861.1 5428.95 3674.21 MinPt-0-SF 8402.01 8313.99 8270.4 mum 6189.63 3674.32 MinPt-O-SF 9106.17 9011.53 8964.7.MIK 6543.35 3685.81 MinPt-O-SF 14907.02 14760.42 14687.611 9199.61 3832.04 MinPt-O-SF 16107.84 15939.51 15855.:'=CH 10200.69 3842.10 MinPt-O-SF 16605.09 16428.06 16340.04 94.32 10614.06 3869.49 TD OP17-02(P8)(Def Plan) Pass 95.99 94.77 92.66 N/A 000 0.00 Surface 95.99 93.36 92.66 67.36 249.00 249.00 MinPt-CtCt 96.1 11 58.33 299.00 299.00 MinPts 126.79 118.85 115.481 737.27 737.02 MinPt-0-SF 8305.33 8271.89 8255.••=SZIE 2587.91 2401.45 MinPt-O-SF 9150.14 9113.03 9094.9 111==. 2712.28 2483.13 MinP1-0-SF 10161.43 10119.29 10098.71=MEE 2942.77 2632.37 MinPt-O-SF 11088.62 11041.74 11018.7.1 3138.04 2758.82 MinPt-O-SF 11370.25 11322.07 11298.4 Mr= 3200.32 2799.15 MinP1-0SF 6975.01 6905.91 6871.; MIZEZ 5176.41 3664.81 MinPt-0-6F 7811.24 7736.72 7699.•'MICE 6186.96 3674.32 MinP1-0SF 8252.77 8173.39 8134.1 1 6706.26 3692.06 MinP1-0-SF • 8711.58 8625.42 8582.1'1. 1 7242.90 3726.64 MinP1-0SF 9021.42 8930.48 8885. .MIDSE 7601.01 3756.03 MinPt-0SF 10348.82 10231.37 10173.1 .MI129197.44 3832.08 MinPt-O-SF 10951.83 10824.63 10761.5 1MM 9740.96 3836.32 MinPt-0-SF 11586.65 11451.53 11384.47 im••'i. 10120.41 3840.20 MinPt-O-SF 14297.27 14138.44 14059.52.1.•. 11256.45 3890.78 MinPt-0-SF 14665.94 14503.50 14422.77 90.83 11408.55 3893.50 TO 0114-08(P2)(Def Plan) Pass 71.97 70.75 68.64 N/A 0.00 000 Surface I 71.97 69.14 68.34 43.99 275.00 275.00 MinPt-CtCt 72.09 69.01 68.09 38.18 320.00 320.00 MinPt-0-EOU 72.15 89.03 68.07 37.24 330.00 330.00 MinPt-0-ADP 134.38 121.73 116.02 11.66 833.71 832.90 MinPt-O-SF 11145.96 11093.74 11068.12 217.50 4156.10 3389.86 MinPt-0-SF 5784.88 5720.25 5688.43 90.88 5196.22 3665.85 MinPt-0-SF 6051.86 5984.31 5951.03- 90.91 5432.29 3674.21 MinPt-0-SF 7288.91 7207.99 7168.021 91.17 6187.41 3674.32 MinPt-O-5F 8183.17 8092.47 8047.611 91.20 6702.13 3691.91 MinPt-0-SF 1' 9055.89 8954.59 890444_ 90.27 7219.34 3724.98 MinPt-0-SF 9607.67 9499.42 9445.78 89.56 7551.85 3751.61 MinPt-0-SF 10589.33 10471.21 10412.65 90.40 8111.40 3828.02 MinPl-0-SF 14972.72 14826.75 14754.27 103.27 10666.28 3873.14 MInP1-0SF 15140.39 14992.86 14919.58 103.31 10758.83 3878.20 TD 11044.26 11011.26 10995.2344 9 2536.10 2365.64 MinPt-0-SF ' 10867.571 10834.761 10818.8 341.4 2536.87 2366.18 MinPts OP12.01(Del Survey) Pass 11 38.19 mum 9162 127.62 127.62 MinPts 40.081 36.75 45.19 197.61 197.61 MinPt-0-EOU 41.44 38.22 111.0310 20.21 327.51 327.51 MinPt-O-ADP 44.16 39.51®1 12.52 467.31 467.31 MinPt-0-ADP 162.59 136.87 124.621 1097.57 1092.09 MinP1-0-SF 2899.67 2831.42 2797.79' '•' 5119.60 3661.84 MinP1-0-SF 4416.64 4327.70 4283.7 1 6700.03 3691.82 MinPt-0-SF 4613.18 4520.86 4475.2.=gm 6943.62 3706.73 MInPI-0-SF 4851.40 4754.28 4706.2.1• ''' 7219.59 3725.00 MinPt-0-SF 4928.12 4829.98 4781.401 7302.46 3731.40 MinPt-0-SF 5157.78 5055.03 5004,151.1M 7548.86 3751.37 MinPt-0-SF 5669.54 5560.20 5506.02,1 8030.87 3818.95 MinPt-0SF 6170.40 6050.85 65 5991.561 8544.04 3844.81 MinPt-0-SF • • 24.87 6398.86 6336.051 8863.32 384524 MinPt-0-SF 6806.40 8674.78 6609.46 9117.87 3834.46 MinPt-0-SF Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0107-04\0107-04\0107-04(P4) 9/17/2010 1:21 PM Page 4 of 7 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-0t(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 740080 7257.21 7186.01 51.96 9742.12 3836.33 MinP1-0-SF 7692.94 7542.03 7467.07 51.31 10122.31 3840.22 MinPt-O-SF 7752.45 7600.39 7524.86 51.31 10198.00 3842.00 MinPI-O-SF 8220.80 8057.44 7976.25 50.62 10769.36 3878.59 MinPt-O-SF OP16-03(P3)(Det Plan) Peas 88.00 86.78 84.68 N/A 0.00 0.00 Surface u 84.19 82.89 33.51 400.00 400.00 MinPl-CICt 88.0 11111113210 8276 32.05 420.00 420.00 MinPt-O-EOU 88.10 84.11 MEE 31.44 430.00 430.00 MinPI-0-ADP 150.50 141.63 13781 MEM 850.31 849.36 MinPt-0SF 7309.61 7240.31 7206.15=1:31. 5198.49 3665.97 MinPt-0-SF 7642.15 7569.62 7533.8 106.8., 5429.62 3674.21 MinPt-O-SF 8500.83 8420.47 8380.78n107 09 5872.81 3674.28 MinPI-O-SF 15353.43 15247.67 15195.28 146.53 8415.57 3842.71 TD 9254.98 9222.67 9207.n004 295.37 2250.04 2147.93 MinPt-0-SF I 10898.051 10836.441 10806.13 179.7 4645.17 3582.79 MinPts OP05-06PB2(Non-Def Survey) Pass 23.76 21.90 20.43 35.63 148.94 148.94 MinPts 23.8 21.83 20.47 30.33 168.94 168.94 MinPt-0-EOU 44.42 38.57 36.2 mills 65920 659.14 MinPt-0-SF 55.32 48.34 45.. ®1 749.00 748.71 MinPt-0-SF 169,64 146.68 135.81 MIME 1193.55 1184.72 MinPt-O-SF 4217.57 4162.51 4135.4 4955.20 3647.14 MinPt-O-0F �i r.,)MEIKKE 4129.56. 79.09 5066.23 3658.55 MinPts 4210.9.illimaI 412806 77.15 5200.24 3666.06 MinPts 4210.91 4155/2 4127.86 111111111:05285.52 3670.52 MinPt-0-SF scgazwingm1MBEES 76.96 5295.27 3671.00 MinPts 4207.25 4150.24 4122.2 5785.78 3674.26 MinPt-O-SF MEW 4144.07 4115.50 73.53 6116.75 3674.31 MinPl-CtCt 2 4144 p21 4115.38 73.38 6136.73 3674.31 MinPt-0-EOU 4202.2 ®� 73.30 6146.73 3674.32 MinPt-O-ADP 420311 4144 53 4115 7, n 6197.49 3674.34 MPI.O-SF 4217.8 J e J 1 1 6754.81 3694.37 MinPts ))))jj) 4154.91 4124.03 68.28 6839 79 3699.85 MinPl-CtCI 3951.85 3862.84 3818.8311 , 9197.15 3832.08 MinP1-0SF 3904.81 3802.38 3751.66.1.111. 10198.18 3842.00 MinPt-0-SF 3900. 3795.98 3744.43 37.82 1045920 3858.67 MinPt-CtCt 3900.2 3795 71 3743.91 37.64 10489.19 3860.76 MinPt-0-EOU 3900.67 3795.766 3743.81 37.52 10509.17 3862.16 MinPt-0-ADP 1 3901.79 3787.34 3730.61 34.38 11065.84 3886.12 MinPt-CtCI 1 3902.1 3786.98 3729.91 34.18 11115.81 3887,37 MinPt-O-EOU ' 3903.26 3787.20 3729,6 33.91 11175.78 3888.86 MinP1-0-ADP I 3925.17] 3793.361 3727. 29.991 12053.25 3890.19 MinPts i 0P06-06PB1(Non-Def Survey) Pees 23,76 21.90 20.43 35.63 148.94 148.94 MinPts 23.80 21.83 2047 30.33 168.94 168.94 MinPt-O-EOU 44.42 38.57 36. nmE 859.20 659.14 MinPI.O-SF 55.32 48.34 45. •MOM 749.00 748.71 MinPt-O-SF 169.64 146.68 135.8111111M2 1193.55 1184.72 MinPt-O-SF 4068.29 4015.65 3989.82 78.73 4513.42 3541.39 TD OP05.06(Non-Del Survey) Pass 23.76 21.90 20.43 35.63 148.94 148.94 MinPts 23.80 21.83 20.47 30.33 168.94 168.94 MinPt-O-EOU 44.42 3857 36.2 illiiim. 659.20 659.14 MinPt-O-SF 55.32 48.34 45.46 LIKE 749.00 748.71 MinPl-OSF 169.64 146.68 135.81® 1193.55 1184.72 MinPt-O-SF 4217.57 4162.51 4135.48 II 4955.20 3647.14 MinPt-O-SF 79.10 5066.23 3658.55 MinPts 4210.'.1.31M'MEMO77,16 5200.24 366606 MinPts 4210.91 4155.22 4127.87 M', 5285.52 3670.52 MinPIASF =En mum=EEO 76.97 5295.27 3671.00 MinPts 4207.25 4150.25 4122.2,, 5785.78 3674.26 MInP1-0-SF IMEEREE 4144.07 4115.51 73.53 6116.75 3674.31 MInPt-CICt 4202.2'®' 4115.38 73.38 6136.73 3674.31 MinPt-0-EOU 4202.32 4144.. MGM 73 31 6146.73 3674.32 MinPt-0-ADP 4203.11 4144.54 4115.75® 6197.49 3674.34 MinPt-0-SF • 4217.:>MOM1�•'• . 6754.81 3694.37 MinPts =m194 4154.91 4124.04 68.28 683979 3699.85 MinPt-CtCt 3951.85 3862.83 3818.8.' 9197.15 3832.08 MinPt-0-SF 3904.81 3802.37 3751,•'MOE 10198.18 3842.00 MinPl-0-SF te...'1y 3795.97 3744.41 37.81 10459.20 3858.67 MinPl-CtCt 3900.2,MEM 3743.89 37.64 10489.19 3860.76 MinPI-0-EOU 3900.67 3795.7 =ME 37.52 10509.17 3862.16 MinPl-0-ADP MEM.', 3787.33 3730.59 34.38 11065.84 3886.12 MInPl-CtCI 3902.1. 3729.89 34.18 11115.81 3887.37 MinPt-0-EOU 3902.78 3787.11 MiMri 3402 1115579 3888.36 MinPI-0-ADP MEM 3765.72 3702.36 30.72 11863.78 3896.65 MinP1-ClCt 3895.331' 3760.9._1111a'.n 12231.88 3884.10 MinPts 0118-07(P3)(Def Plan) Pees 10400 102.77 100.67 N/A 0.00 0.00 Surface 104.00 101.36 100.65 72.76 250.00 250.00 MinPl-CtCt 104.04 101.29 100.52 67.28 270.00 270.00 MinPt-0-EOU 104.09 10129 100.50 65.25 280.00 280.00 MinPl-0-ADP 163.01 154.10 150.25 21.04 734.23 734.00 MinPI.0-SF 407.70 391.86 384.55_ 27.81 1132.32 1125.74 MinPt-0-SF 12041.26 11974.51 11941.63 183.08 5175.68 3664.78 MinPt-0-SF 12344.74 12276.89 1224346 184.62 5428.64 367421 MinPt-0-SF 13485.74 13412.21 13375.93 185.88 6187.62 3674.32 MinPt-0-SF 14210.90 14132.39 14093.63 183.29 6661.03 3690.33 TD Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)J EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 9787.55 9753 49 9736 96 295 93 1935.92 1875.93 MinPt-O-SF 1 7400.14 7370 264 7355.86 256 9 2173.26 2084.30 MinPts Oliktok Point I-1(Def Survey) Pass 56.54 54.63 5322 N/A 0.00 0.00 Surface 56.54 5463 53.22 153399.19 40.10 40.10 MinPts 56.67 54.52 53.34 238.04 89.20 89.20 MinP1-0-EOU 216.45 196.40 187.33 I=BM 1206.84 1197.46 MinPt-O-SF 4841.18 4781.85 4752.9.min 5203.71 3666.24 MinPt-O-SF 4867.35 4807.74 4778.73',_- :] 5275.21 3669.99 MinPt-O-SF 4910.16 4850.10 4820.88MM. 5389.40 3673.90 MinPt-O-SF 4976.97 4915.20 4885.12mm 5735.81 3674.25 MinPt-O-SF 4992.9 MIKEZERINIZMI'MMEG 5847.38 3674.27 MinPts Oliktok Point I-1A-106(P5)(Def Plan) Pass 56.54 54.63 5322 N/A 0.00 0.00 Surface 56.54 54.63 53.22 153399.19 40.10 40.10 MinPts 56.67 54.52 53.34 238.04 8920 89.20 MinPt-O-EOU 216.45 196.40 187.33 11.83 1206.84 1197.46 MinPt-OSF 5239.95 5179.59 5149.90' 88.23 5325.76 3672.28 MinPt-O-SF 5190.97 5009.64 4919.47 78 11858.85 3896.82 MinPt-O-SF 1 5189 034 5000.301 490643 27 63 12231.88 3884.10 MinPts OP23-W W02(Del Survey) Pass ®'' 148.51=MK 126.34 267.98 267.98 MinPts IMEM 148.22 147.47 99.81 329.00 329.00 MinPt-CtCt 5"'. 147.84 146.87 77.49 414.54 414.54 M1nPt-CtCt 151..,MI= 146.79 74.50 429.00 429.00 MinPI-O-EOU MIME 147.35 146.13 61.31 508.69 508.69 MinPt-CtCt 151.12 11111= 145.97 57.37 537.68 537.68 MinPt-0{OU 151.19 147.30 MOM 56.08 547.35 547.35 MinPt-O-ADP 241.23 229.08 223.62 MEM 1203.01 1193.79 MinPt-O-SF 673.52 650.13 638.9; EaLE. 2584.88 2385.67 MinPt-O-SF 906.65 877.75 863.;'MEM. 3281.67 2851.83 MinPt-O-SF 996.45 964.79 949.5. 3552.16 3026.98 MinP1-0-SF 1088.63 1054.03 1037. ;MEE. 3836.63 3210.05 MinPt-O-SF 1322.35 1275.82 1253.0 ®" 5146.08 3663.23 MinPt-O-SF 2557.88 2514.51 2493.3.E 7591.08 3755.07 MinPt-0-SF 5768.03 5724.25 5702.85 134.74 8829.38 3846.44 TO 0113-03(P2)(Del Plan) Pass 63.98 62.75 60.65 N/A 0.00 0.00 Surface 61.34 60.63 44.41 250.00 250.00 MinPI-CtCt 64.2 Min 59.79 29.23 369.98 369.98 MinPt-O-EOU 64.40 60.8,MEM 27.61 38996 38996 MinPI-O-ADP 64.76 111111110 59.52 23.74 419.89 419.89 MinPt-0-EOU 65.10 60.92 MErn 21.59 439.82 439.82 MinP1-0-ADP 11225 98.40 92..• 777.40 776.97 MinPt-OSF 136.84 119.87 111.••MEMO 851.60 850.63 MinP4-0SF 169.86 148.93 139.0 zlim 933.38 931.44 MInPt-OSF 217.26 190.77 178.1 :Em 1030.48 1026.74 MinPt-O-SF 246.16 216.30 201.9;=LE 1081.95 1076.91 MinPt-0-SF 266.58 234.32 218.81 1115.64 1109.60 MinPt-0-SF 298.84 262.81 245.40 imam 1165.17 115744 MinP9-O-SF 4097.72 4014.09 3972.7 mow 5429.57 3674.21 MinPt-0-SF 6294.31 6178.97 6121.8.IMMEIC 7548.94 3751.38 MinPt-O-SF 7867.20 7722.06 76499;MIER 9119.41 3834.40 MinPt-0-SF 8550.63 8392.91 8314.5 mzi22, 9738.31 3836.30 MinPt-0-SF 8675.37 8515.68 8436.3 54.66 9842.14 3837.36 MinPt-O-SF 12679.86 12492.69 12399.60 68.10 12231.88 3884.10 TD OP28-DSPO2(Def Survey) Pees I365.68 363.71 362.361 N/A 0.00 0.00 MinPts 341.40 332.40 328.86 47.96 908.72 907.13 MinPt-CtCt 341.54 332.23 328.53 45.90 934.42 932.47 MinPt-O-EOU 341.69 332.27 328.52 45.30 942.99 940.91 MinPt-O-ADP 389.60 372.06 364.25 24.82 1356.25 1339.10 MinPt-O-SF 451.55 431.91 423.05. 25.37 162323 1587.75 MinPt-0SF 545.07 521.79 511.11 25.42 1906.11 1848.66 MinPt-O-SF 1951.06 1897.32 187125 37.39 5177.39 3664.87 MinPt-O-SF 3654.38 3602.43 3577.2 6676.77 3690.93 MinPt-O-SF Kigun 1(Def Survey) Pass 17140.94 17138.22 17108.13 21455.17 162.14 162.14 MinPts 17141.09 17138.11 17108.28 16094.78 197.17 197.17 MinPt-O-EOU 17145.21 17138.85 17112.401 3857.39 671.83 671.75 MinPts 17145.2 17138.82 17112.43 3807.34 682.23 682.13 MinPt-0-EOU 17152.90 17145.05 17120.09 2890.03 811.62 810.98 MinPt-O-SF • Kigun 1 PB1(Def Survey) Pass 17140.94 17138.22 17108.13 21455.17 162.14 162.14 MinPts 17141.09 17138.11 17108.28 16094.78 197.17 197.17 MinPt-O-EOU 1 17145.21 17138.85 17112.401 3857.39 671.83 671.75 MinPts 17145.24 17138.82 17112.43 3807.34 682.23 682.13 MinPI-O-EOU 17152.90 17145.05 17120.09 2890.03 811.62 810.98 MinPt-O-SF Tavoog ST 1(Def Survey) Pass 17140.94 17138.22 17108.13 21455.18 162.14 162.14 MinPts 17141.09 17138.11 17108.28 16094.78 197.17 197.17 MinPt-O-EOU I 17145.21 17138.85 17112.401 3857.39 671.83 671.75 MinPts • 171452 17138.82 17112.43 3807.34 682.23 682.13 MinPt-O-EOU 17152.90 17145.05 17120.09 Ell= 811.62 810.98 MinPt-0SF Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0107-04\0107-04\0107-04(P4) 9/17/2010 1:21 PM Page 6 of 7 Offset Trajectory Se aration Allow Sep. ReferenceTrajectorySeparation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major Nikaitchuq 3(Del Survey) Paas 18470.13 18468.16/I 18437.32 378963.79 5100 51.00 MinPts 18470.93 18467.1 18438.12 10124.89 250.80 250.80 MinPt-O-EOU I 18472.96 18466.5 18440.151 4152.93 562.19 562.18 MinPts 18472.97 18466.59 18440.16 4139.32 565.16 565.15 MinPt-O-EOU 18478.12 18471.37 18445.31 MEM 622.74 622.72 MinPt-O-SF Nikaitchuq 3PB1(Def Survey) Peas 18470.13 18468.16 18437.32 378963.79 51.00 51.00 MinPts 18470.9 18467.19 18438 12 10124.89 250.80 250.80 MinPt-O-EOU I 18472.96 18466.59 18440.14 4152.93 562.19 562.18 MinPts 18472.97 18466.59 18440.16 4139.32 565.16 565.15 MinPt-O-EOU 18478.12 18471.37 18445.31 MEM 622.74 622.72 MinPt-O-SF Nikaitchuq 3P82(Def Survey) Pass ®' 18468.16 II= 378963.79 51.00 51.00 MinPts 18470.9 .t. 18438.12 10124.89 250.80 250.80 MinPt-O-EOU 18472.96 4152.93 562.19 562.18 MinPts 18472.97 18466.59 18440.16 4139.32 565.16 565.15 MinPt-O-EOU 18478.12 18471.37 18445.31 IMIZEM 622.74 622.72 MinPt-O-SF Nikaitchuq 3P83(Def Survey) Pass 18468.16 378963.79 51.00 51.00 MinPts 16470.9 18467.19', 18438.12 10124.89 250.80 250.80 MinPt-0-EOU EIMET 18466.5'! 84401 4152.93 562.19 562.18 MinPts 18472.97 18466.59 18440.16 4139.32 565.16 565.15 MinPt-O-EOU 18478.12 18471.37 18445.31=ME 622.74 622.72 MinPt-O-SF Nikaitchuq 4(Def Survey) Pass 18509.56 18507.59 18476.75 380390.21 51.00 51.00 MinPts 18510.14 18507.2 18477.33 18847.85 170.92 170.92 MinPt-O-EOU I 18513.29 18506.9 18480.481 4222.16 564.43 564.43 MinPts 18513.32 18506.95 18480.51 4155.87 573.24 573.24 MinP1-O-EOU 18517,51 18510.77 18484.70 `®" 621.91 621.89 MinPt-O-SF Nikaitchuq 4PB1(Def Survey) Pees 18509.56 18507.59 MEM 380390.21 51.00 51.00 MinPts 18510.1'Immo. 18477.33 18847.87 170.92 170.92 MinPt-O-EOU MUM Mc.)jjjjMO 4222.16 564.43 564,43 MinPts 18513.32 18506.95 18480.51 4155.87 573.24 573.24 MinPt-O-EOU 18517.51 18510.77 18484.70 MIME 621.91 621.89 MinPt-OSF Nikaitchuq 1(Del Survey) Paas 19535.49 18530.14 16502.68 5402.00 452.51 452.51 MinPts 18535.53 18530.081 18502.73 5232.74 466.19 466.19 MInP1-0-EOU I 18535.56 18529.69 18502.74 4694.54 512.91 512.91 MinPts 18535.57 18529.69 18502.76 4681.59 514.00 514.00 MinPt-O-EOU 18550.39 1854365 18517.59 MEM 622.80 622.78 MinPt-O-SF Nikeitchuq 2(Def Survey) Pass 19036.80 19031.91 19003.99 6388.85 432.25 432.25 MinPts 19036..c 19031.4 190040 5397.55 506.97 506.97 MinPts 19036.87 19031.41 19004.06 5372.09 509.48 509.48 MinPt-O-EOU 19045.22 1903907 19012.41=am 612.21 612.19 MinPt-O-SF Schlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: 0107-04(P4)Surface Hole '/ Oriented EOU Dimension Field: Nikaitchuq ' .N NoGo Region Anti-Collision rule used: Structure: Oliktok Point di * Minor Risk-Separation Factor A 4 Date: August 31,2010 1-11t, iflo'v North 350 0 10 340 ��ppD� r/��,\=`i\'1. 20 330 �'• 9F.19:� �M��i'1 ►� •` ,-07P e � I I wb Br"320 1p;\ ''AllirZ j ,,� `�iii 1 . \ 40 310 Ni calf �'_—r 11' �v' � '. 4* 1,11 ��F,meg,/ -i. 'j:;•4 4 �.�,-50 OP10-.- (P �. �= !j:11l\��\v�w°. 4t s .,, 03-P05PB2 300 :° 4 ��r' ,� �i4*�,��/.•�/, 1 :._. 60 410' /�� �� �1. �.,ill I 1&`• It�. .�itt'' /liktok Point 1-1A-106(P5) 290Alt �� �► ,1� ���:`i70 ,lb.Nik,,N....44" ___,--401,'altly ilp dlikVA 0 illik. dam`: . 280 tglillib:3:7411.4, .W.44e fire 47 r .ed,. . .._. ii, gfri•zia. ..:1 Imp_4"44-',I, tets il, ,-?4%-.„.. A'hW 270 ,� rile,— ��..._. ;��=�1Ltit4 ��i1...� .-.. .���. �\ so lillik-v-ir Irl'al --,gr...„t•-....- . 4 WI i ii it it..... III 260 i `k.:e,i.:�,0�-r'iA . INtia ,4111‘r 41k . `��:� 100 oPos-osP62 250 s/ 110 o / ` I 240 111 o°j 120 230 130 220 / 140 210 illrall‘ 50 200 0 106-05(P5) 190 180 170 Well Ticks Type: MD on 0107-04(P4) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=20.00 ft i S Schlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOUbased on. Well: 0107-04(P4)Surface Hole , 's Oriented EOU Dimension Field: Nikaitchuq 3\I Structure: Oliktok Point NoGo Region Anti-Collision rule used: TW Minor Risk-Se.aration Factor A At Date: August 31,2010 4111......_ North 0 350 10 340 -...,,,fir, 4 07411itk 20 33°11194PAk40:q1144 30 40 -40,r4 '-'i i --41$1.14/4 320 4,.,... , ,,,,,,,..., ,7,,,,.,,.., ,/xtu,-114 10..„,,,,...v41 ,,,..........„....0.116,,,;,,..44, Ali..ollmow• 310 dria.V;r41111/A „„A IV , 0 ear 4 50 l°7101/:' 14/N11101ritilik. 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VP'-'414!*:r ap Aillirsis al *1101# 4.: 4,.01111B,vs, 110 . ,4 \ '41(tip.),d tillilg, rA04,71 2. 240 ,;,:4 I 41111111111bito ,t 414,0p -06P132 .. 2301411111' lje'130 05 220 41iiiiiiiii1111 I I I I ittolk41040 -.° 16tW 50 210 1 20Aram,,,t);CD5(P5) 190 180 170 Well Ticks Type: MD on 0107-04(P4) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Jnterval: 10.0 deg Scale: 1 IN=%50.00 ft Schlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: 0107-04(P4)Intermediate Hole Oriented EOU Dimension Field: Nikaitchuq N NoGo Region Anti-Collision rule used: Structure: Oliktok Point / Minor Risk-Separation Factor A = Date: August 31,2010 .4, North 350 0 10 340 _300 20 330 ' 280 30 'Wigan 260 `320 � 240 '` 40 .�',�I220 3140* 10 0 !Ss 50 Ij �� a, �� -I, ♦♦Tilligarr4300 ♦ ggramb ♦ S60 290 Nr ♦ •Oil�TIW ♦•♦ , 70 280 likarbit♦ Avip, & ♦ 80 �/� 270 1111111111iL.141 � � 190 1111111511rITIO"S �... ■■11�r260 �/ � ,�i�►, ,�•1••� . . . 03-P05P62 Willstags r� 4 250 '.® AMA , 110 ♦Wal ♦ • ? 120 230 411111111101 130 41/111111110. 220 � ,I 140 2,0`*� 0160 150 _r 190 180 170 Well Ticks Type: MD on 0107-04(P4) 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: 0107-04(P4)Production Hole Oriented EOU Dimension Field: Nikaitchuq NoGo Region Anti-Collision rule used: Structure: Oliktok Point Minor Risk-Separation Factor A '. Date: August 31,2010 ir r North 350 0 10 340 300 20 330 280 Air 30 260 ., 0 320 / 240 %40 220 ft*. 310 4Il $1111114ftilitt 50 300 guirga„„-.._ oliiii.47 4$ 70 Alliiii, 290 • 01111111141.1111 • 280Ste 11.�•,Alli ,,•♦ '' 80 litirb Al i r/ 4F111111111 MIN NalistivAehtsitaissill1111111 270 - 90 260 •1111:M14tP3*7i,,ii,►a4St•i••. 100 ♦ ty ♦ ■ I 250 0 ♦ 110 ly*ar III 10 240 4 A) O� 0 .. 4 o gw120 ♦ii=i �230 Alt -- , 130 220 ��-1 01140 2210141210141a1111r• 200 01110k50 60 190 180 170 Well Ticks Type: MD on 0107-04(P4) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=100.00 ft Drilling Hazards Summary 16" 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 8-1/2" Open Hole / 5-1/2 Liner Interval Hazard Risk Level Miti ation 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 ED gi 1 : 9) D _ . O z a 77 w w m (0 < D '< w 3 c7 °- Oz a, CL F CD D \:1 W 1� N -1.' 0 CD < CDCD CD CO 7 < 1 - to 0. CD < rn rn rn rn g Cn CD = _ T' y Cn � � , , O O O O CCD A, O A, SBD U r -� c--- C) OCD CD CD — u5 3o 3n O • .. ,5 IKK X14,"" , C cy 7 4C C C7 W � A, -p - . O C O O -" ��. 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' | Ja6JagwnlgoS to veW 'papa;w aq of lou s!sJaylo Jo Je6j9gwnlgos;o slualed;o luawa6uu;w way;wopaaid •seowas asagl woped 01 pagnbai AIawwgin ieualew pue'luawdinba'awg uodn 6uwpuadap tien Aew sa6Jego lenloy'anssi;o amp agl wog;s(ep og sol pooh ale pue Apo salewgsa ale paionb saoud •Al6u!pJ000e seam w Ilam 8141;o SJ8UMO Jo Jeumo eql Algou o1 A4!I!glsuodsai sdoleiadO eql s!1!waiag pasodwd luawleail agl Aq pepaje aq lg6iw spam Jo gam 6uuogg6iau e AgeJagm suog!puoo lue;o aieme s!JoleiadO 8141ll'waw 6ugoaJe suompuoo pue Nag 8141'J!onlasaJ 8111'Ilam 8141 to a6palmoum iouadns seq JoleJadO 8111 6ugoalas w ls1Sse ueo ia6Jagwnwos goigm sainpaowd pue sisal uiejeo;o asn agl g6nwg1 panoidwi aq Aew'sllnsai aouag pue`elep lndui;o Alpenb atm.'saw alniosge uegl Jeglel sasodind uosuedwoo Jo;pasn aq pinogs pue panaigoe aq Aew legl sllnsai lenloe 814410 alewgsa 'sag sua6Jagwngios s!paluasaid uogewio;w agl'elep lndw Lions pue suogdwnsse eq1'iapow 8141 uegl aleinooe avow ou aq ueo pue elep umou)lun 01 se salewgsa uo pue JoleJad0 eq1 Aq pap!AoJd elep lndw uo puadap sqnsai aql'luawleail pue Jioniasaj`gam agl uo suogdwnsse snouen 6wpnpu iapow Jaindwoo a Aq paonpaid suogelnojeo uo paseq salewgsa ale uani6 sjnsai aql'aomwas Jo lonpoid (ue;o asn 8141 wal pawelgo aq of sgnsai 6wwaouoo spew suwlepuawwooai Jo aoinpe Jo;/gipgeg ou sawnsse Ja6Jagwnwos pue Aq uani6 Si llue.uem ou lnq `gl1el pooh u! paluasaid si uogewlolu sigl :aogoN Jawiepsia C31494.�� ,4O woo'gls@ 6uo1r : ssaJppy I1eW-3 £600-£ZZ(L06) : Ilao 9LL 6-£LZ(L06) : auo4d 6uoi gar : Aq paJedaJd 9£5Z-659(L06) '0N XVd 17£pZ-659(L06) : auogd ssauisne 0LOZ-60-06 paJedaJd oleo m{sely 'i(e8 904PnJd : luiod ao!MJaS Vn l}8JG : .ON Iesodojd eNsely- edols lJON : uol;eoo1 mum" uoser•Jyj : Jo;paJedaJd m{sely : aleiS bn43llevN : Plaid vsfl : AJluno3 VO-L010 II°M wneloJled Iu3 : Jo;eJadO 6uise3 aoeJlnS «g/E c Joj uoRepuawwooaa 6uljuawao 3 ado w oO �l do egwnigas Client Eni Petroleum Well : 0107-04 Schlumberger String : 13.375 District : Prudhoe Bay Alaska Country USA Loadcase : Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Total MD : 2300.0 ft BHST : 50 degF Bit Size : 16 in ft (x 1000) psi 0 1 1 .0 1 .5 � 1- Frac — Pore G _ O— o — ' Permafrost o- Lr,– — Ugnu Top (UG4) . . . . . . Csg pt. r – Well Lithology Formation Press. Page 2 opO107-04 10-1-10.cfw;10-04-2010; LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : 0107-04 Sdinkrier String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 160.0 20 169.0 18.376 Landing Collar MD : 2200.0 ft Casing/liner Shoe MD : 2280.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2280.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 233.0 %(275%to the base of Permafrost, 35%to TD) Mean OH Equivalent Diameter: 20.832 in Total OH Volume : 902.2 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 1909.0 16.000 275.0 21.634 2280.0 16.000 35.0 16.822 2300.0 16.000 0.0 16.000 Page 3 op0107-04 10-1-10.cfw;10-04-2010; LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : 0107-04 Salimrger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Max. Deviation Angle : 37 deg Max. DLS : 3.539 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 34.0 0.000 100.0 100.0 0.0 34.0 0.000 200.0 200.0 0.0 34.0 0.000 300.0 300.0 0.0 34.0 0.000 400.0 400.0 0.0 34.0 0.000 500.0 500.0 0.0 34.0 0.000 600.0 600.0 1.5 34.0 1.500 700.0 699.9 4.0 34.0 2.500 800.0 799.4 6.5 34.0 2.500 900.0 898.5 9.0 34.0 2.500 1000.0 996.9 11.5 34.0 2.500 1100.0 1094.4 14.0 34.0 2.500 1200.0 1190.9 16.5 34.0 2.500 1300.0 1286.1 19.0 34.0 2.500 1370.0 1352.0 20.8 34.0 2.571 1400.0 1380.0 20.9 34.0 0.333 1500.0 1473.3 21.4 34.0 0.500 1600.0 1566.2 21.9 34.0 0.500 1700.0 1658.8 22.4 34.0 0.500 1800.0 1751.1 22.9 34.0 0.500 1900.0 1843.1 23.4 34.0 0.500 1910.0 1852.2 23.5 34.0 1.000 2000.0 1933.8 26.6 34.0 3.444 2100.0 2021.8 30.1 34.0 3.500 2200.0 2106.7 33.6 33.0 3.539 2280.0 2172.2 36.4 33.0 3.500 2300.0 2188.2 37.1 33.0 3.500 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 1909.0 12.00 8.43 Permafrost Siltstone 2124.0 13.00 9.20 Ugnu Top(UG4) Sandstone 2280.0 13.00 9.20 Csg pt. Sandstone 2300.0 13.00 9.20 TD Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1909.0 1851.3 32 0.6 2300.0 2188.2 51 1.4 Page 4 opO107-04 10-1-10.cfw;10-04-2010; LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : 0107-04 5iiger String : 13.375 District : Prudhoe Bay Alaska �fj Country : USA Loadcase : Surface Casing ft degF deg • o_ 0 R1l 60 90 0 U 20 30 40 -—Geoth.ProfileI --- Deviation —Tubular Fluids —Annulus o– u� o– 0 u,- 0 N – Temp. Profile At 190 min Deviation Section 2: fluid sequence Job Objectives: Cement to Surface in Permafrost,shoe integrity sufficient to drill ahead. Original fluid Mud 9.30 lb/gal k:2.06E-3 Ibf.s^n/ft2 n :0.812 Ty: 8.74 lbf/100ft2 Displacement Volume 329.4 bbl Total Volume 994.9 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbjj (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 479.7 1780.0 0.0 10.70 k:1.73E-1 Ibf.s^n/ft2 n:0.220 Ty:10.85 lbf/100ft2 DeepCRETE(12.5) 85.7 500.0 1780.0 12.50 k:2.74E-3 lbf.s^n/ft2 n:0.995 Ty:32.35 lbf/100ft2 Mud 329.4 0.0 9.30 k:2.06E-3lbf.s^n/ft2 n:0.812 Ty:8.74 lbf/100ft2 Page 5 opO107-04 10-1-10.cfw;10-04-2010; LoadCase Surface Casing;Version wcs-cen1461_08 Client : Eni Petroleum Well : 0107-04 gchlmkrger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Static Security Checks : Frac 11 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2009 psi at 2200.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 50 ton Section 3: pumping schedule Start Job: Circulate Two Hole Volumes, Safety Meeting, Test Surface Equipment Pumping Schedule Name Flow Volume Stage Time Cum.Vol Inj.Temp. Comments Rate (bbl) (min) (bbl). (degF) (bbl/min) MUDPUSH II 5.0 100.0 20.0 100.0 80 Spacer Ahead Pause 0 0 5.0 0 80 Drop Bottom Plug Lead Slurry 5.0 328.4 65.7 328.4 80 Mix&Pump Lead Slurry Lead Slurry 5.0 1.0 0.2 329.4 80 Mix&Pump Lead Slurry Lead Slurry 5.0 150.3 30.1 479.7 80 Bottom Plug at Float Collar DeepCRETE(12.5) 4.0 85.7 21.4 85.7 80 Mix&Pump Tail Slurry Pause 0 0 3.0 0 80 Drop Top Plug Pause 0 0 2.0 0 80 Line-up Rig Pumps Mud 8.5 309.0 36.4 309.0 80 Displace Mud 3.5 20.4 5.8 329.4 80 Slow Rate Shut-In 0 0 0 0 80 Bump Plug Total 03:09 hr:mn 994.9 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 6 psi at 160.0 ft Pore 7 psi at 160.0 ft Collapse 2009 psi at 2200.0 ft Burst 4775 psi at 0.0 ft Temperature Results BHCT 65 degF Simulated Max HCT 72 degF Simulated BHCT 72 degF Max HCT Depth 2280.0 ft CT at TOC 59 degF Max HCT Time 03:09:33 hr:mn:sc Static temperatures : At Time 1 (hr:mn) 00:00 hr:mn Geo.Temp. Top of Cement (degF) 59 degF 20 degF Bottom Hole (degF) 72 degF 50 degF Page 6 opO107-04 10-1.10.cfw;10-04-2010; LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : 0107-04 String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing ft lb/gal 8 9 10 11 12 13 14 o - Hydrostatic - Mn.Hydrostatic - Max.Dynamic - Mn.Dynamic ------ Frac p - R re O— U) O O O O U)— 1111 O O u7 N— Fluid Sequence Dynamic Well Security ■MUDPUSH II 100.0 bbl 10.10 lb/gal Herschel:k=2.54E-2 Ibf.s^n/ft2 n=0.420 Ty=13.04 Ibf/100ft2 3 Lead Slurry 479.7 bbl 10.70 lb/gal Herschel:k=1.73E-1 Ibf.s^n/ft2 n=0.220 Ty=10.85 Ibf/100ft2 DeepCRETE(12.5) 85.7 bbl 12.50 lb/gal Herschel:k=2.74E-3 Ibf.s^n/ft2 n=0.995 Ty=32.35 Ibf/100ft2 ■Mud 329.4 bbl 9.30 lb/gal Herschel:k=2.06E-3 Ibf.s^n/ft2 n=0.812 Ty=8.74 Ibf/100ft2 Total Depth = 2300.0 ft Top of Cement= 0.0 ft Page 7 opO107-04 10-1-10.cfw;10-04.2010; LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : 0107-04 Si" String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Calculated Pressure: Calc.Pump Press. Calc.VVHP 8-� 0 0 20 40 60 80 100 120 140 160 180 200 Time (min) Calculated Return Rate: m Fluids at 2280 ft Q out n In oo r`_ - - N— 0 20 40 60 80 100 120 140 160 180 200 Time (min) Page 8 op0107-04 10-1.10.cfw;10-04-2010; LoadCase Surface Casing;Version wcs-cem461_08 • Client : Eni Petroleum Well : 0107-04 Sc 1/1011 String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing SlurryTemperature Profile: o First Sa Depth First Sa• Tenp. _ Last Sac fl • R IQ -d i \ co g ak v? cci i ai0 -N — -- N O 20 40 60 80 100 120 140 160 180 200 Time(min) Frac Profile at the 13 3/8"shoe: N _ _ _ __ Depth= 2280 ft _ ri I o 1 V- I N -Frac -Fibre -Hydrostatic o -Dynamic G.N- .16 4 Ln 1 of d d- in 0 of -- — 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 9 opO107-04 10-1-10.cfw;10-04.2010; LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : 0107-04 Schlumberger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 4: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2260.0 ft Casing Shoe :2280.0 ft NB of Cent. Used :33 NB of Floating Cent. :33 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 1920.0 24 1/2 NW-TR-13 3/8-8-TR 3 W304 16.7 660.0 2280.0 9 1/1 NW-TR-13 3/8-8-TR 3 W304 16.2 1920.0 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 (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications ft i 10 20 30 40 50 60 70 80 90 100 o < 1 > • Between Cent. + +At Cent. O - + O-I + + 1-1- -H- -H- -H- -H- -H- -ft 1- ++++++++1+ 7+ + g_ + t+ O N Well Pipe Standoff Page 10 opO107-04 10-1-10.cfw;10-04-2010; LoadCase Surface Casing 1 Version wcs-cem461_08 Client : Eni Petroleum Well : 0107-04 SWIM" String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 5: WELLCLEAN II Simulator ft 0 20 40 60 80 100 0 20 40 60 80 100 0 - — I— I __Std Betw.Cent. —Mud Contamination .. —Cement Coverage — Uncontaminated Slurry Ic------ ----"----------- --- 8 -a.....,----- a 1 s7 I r1 L 1 I _ Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall z° z° 3 0-P ' 0 0 _ _ 0 200- 200 200 200 400- 400 400 400 600- 600 600 600 800- 800 800 800 Z. 1000- 1000 Z 1000 --- -- 1000 i a 1200-_ i 1200 fn LS. 1200 _._ 1200 0 c 1400- A 1400 o c 1400 1400 Al 1600- 1600 1500 1600 1800 1800 1800 -- 1800 2000 2000 2000 -. 2000 2200 2200 2200 2200 z° = Mud - High 111. Low ® DeepCRETE(12.5) ED Medium =I None Lead Slurry MUDPUSH II Page 11 opOl07-04 10-1-10.cfw;10-04-2010; LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : 0107-04 Sek urger String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Section 6: fluid description Mud DESIGN Fluid No: 1 Density :9.30 lb/gal Rheo. Model : HERSCHEL_B. k :2.06E-3 Ibf.s^n/ft2 At temp. : 80 degF n :0.812 Ty :8.741bf/100ft2 Gel Strength : 38.42 lbf/100ft2 MUD Mud Type :WBM Job volume : 329.4 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 Ibf.s^n/ft2 At temp. : 65 degF n :0.420 Ty : 13.04Ibf/100ft2 Gel Strength :(Ibf/100ft2) Job volume : 100.0 bbl Lead Slurry DESIGN Fluid No: 3 Density : 10.70 lb/gal Rheo. Model : HERSCHEL_B. k : 1.73E-1 Ibf.s^n/ft2 At temp. : 72 degF n :0.220 Ty : 10.85 lbf/100ft2 Gel Strength : 14.94 I bf/100ft2 DESIGN BLEND SLURRY Name : B809(1001b) Mix Fluid :9.666 gal/sk Job volume :479.7 bbl Dry Density : 103.96 lb/ft3 Yield :2.25 ft3/sk Quantity : 1194.92 sk Sack Weight : 100 lb Solid Fraction :42.7% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 9.666 gal/sk Page 12 op0107-04 10-1-10.cfw;10-04-2010; LoadCase Surface Casing;Version wcscem461_08 Client : Eni Petroleum Well : 0107-04 SchIolerier 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 :2.74E-3 Ibf.s^n/ft2 At temp. : 72 degF n :0.995 Ty : 32.35lbf/100ft2 Gel Strength :63.19 Ibf/100ft2 DESIGN BLEND SLURRY Name : 12.5(0.76) Mix Fluid :5.174 gal/sk Job volume :85.7 bbl Dry Density : 119.32 lb/ft3 Yield : 1.54 ft3/sk Quantity :313.04 sk Sack Weight : 100 lb Solid Fraction : 55.0 BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid :5.174 gal/sk Additives Code Conc. Function D046 0.129%BWOB Antifoam D065 0.250%BWOB Dispersant D167 0.250%BWOB Fluid loss D153 0.100%BWOB Antisettling Page 13 opO107-04 10-1-10.cfw;10-04-2010; LoadCase Surface Casing;Version wcscem461_08 Client : Eni Petroleum Well : 0107-04 SchImatrier String : 13.375 District : Prudhoe Bay Alaska Country : USA Loadcase : Surface Casing Running Force Calculations: Travelling Block Weight :33 ton Friction Factor Centralizer/Formation :0 Total Drag Force :8 ton Hook load Down Stroke :88 ton Hook load Up Stroke :105 ton ft ton 0 10 20 30 40 50 60 70 80 90 100 110 O- —f — I • - Hookload Up - Fiookload Down - Weight - Drag Force O O- 11) O O O O Ln— O O N O O U, — Running Forces Page 14 opO107-04 10-1-10.cfw;10-04-2010; LoadCase Surface Casing;Version wcscem461_08 $cblumberger Ce m CAD E well cementing recommendation for 9 5/8" Intermediate Casing Operator : Eni Petroleum Well : 0107-04 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr. Jason Brink Location : North Slope-Alaska Proposal No. : Draft v1 Service Point : Prudhoe Bay Alaska Date Prepared : 10-04-2010 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 C7 C fay OL '9‘VATE Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment.The results depend on input data provided by the Operator and on estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger Client : Eni Petroleum Well : 0107-04 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 Intermediate Casing(a) Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Total MD : 5300.0 ft BHST : 86 degF Bit Size : 12 1/4 in ft (x 1000) psi t _ 0 2.5 —Frac — Pore Permafrost , Coal UG-2 :.••.'.' L U gnu •o N Top (A) Shale OA Top ,--4 Shale TD (D- Well Lithology Formation Press. Page 2 opoi07-04 10-4-10.cfw;10-05-2010; LoadCase 9 5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : 0107-04 SchIokrger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 Intermediate Casing(a) Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 2280.0 13 3/8 68.0 12.415 Landing Collar MD : 5180.0 ft Casing/liner Shoe MD : 5260.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 5260.0 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: 13.356 in Total OH Volume : 523.4 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 5260.0 12.250 50.0 13.371 5300.0 12.250 0.0 12.250 Page 3 opoi07-04 10-4-10.cfw;10-05-2010; LoadCase 9 5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : 0107-04 SCRIMP'S' String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 Intermediate Casing(a) Max. Deviation Angle : 87 deg Max. DLS : 3.554 deg/1O0ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 34.0 0.000 100.0 100.0 0.0 34.0 0.000 200.0 200.0 0.0 34.0 0.000 300.0 300.0 0.0 34.0 0.000 400.0 400.0 0.0 34.0 0.000 500.0 500.0 0.0 34.0 0.000 600.0 600.0 1.5 34.0 1.500 700.0 699.9 4.0 34.0 2.500 800.0 799.4 6.5 34.0 2.500 900.0 898.5 9.0 34.0 2.500 1000.0 996.9 11.5 34.0 2.500 1100.0 1094.4 14.0 34.0 2.500 1200.0 1190.9 16.5 34.0 2.500 1300.0 1286.1 19.0 34.0 2.500 1370.3 1352.2 20.8 34.0 2.505 1400.0 1380.0 20.9 34.0 0.471 1500.0 1473.3 21.4 34.0 0.500 1600.0 1566.2 21.9 34.0 0.500 1700.0 1658.8 22.4 34.0 0.500 1800.0 1751.1 22.9 34.0 0.500 1900.0 1843.1 23.4 34.0 0.500 1910.0 1852.2 23.5 34.0 0.502 2000.0 1933.8 26.6 33.8 3.500 2100.0 2021.8 30.1 33.6 3.501 2200.0 2106.7 33.6 33.5 3.501 2280.0 2172.2 36.4 33.4 3.501 2300.0 2188.3 37.1 33.3 3.499 2400.0 2266.1 40.6 33.2 3.501 2500.0 2340.0 44.1 33.2 3.501 2600.0 2409.7 47.6 33.1 3.500 2658.4 2448.3 49.6 33.0 3.495 2700.0 2475.2 49.6 33.0 0.000 2800.0 2540.0 49.6 33.0 0.000 2900.0 2604.7 49.6 33.0 0.000 3000.0 2669.5 49.6 33.0 0.000 3100.0 2734.2 49.6 33.0 0.000 3200.0 2799.0 49.6 33.0 0.000 3300.0 2863.8 49.6 33.0 0.000 3400.0 2928.5 49.6 33.0 0.000 3500.0 2993.3 49.6 33.0 0.000 3600.0 3058.0 49.6 33.0 0.000 3700.0 3122.8 49.6 33.0 0.000 3753.2 3157.3 49.6 33.0 0.000 3800.0 3187.2 50.8 31.5 3.512 3900.0 3248.7 53.3 28.4 3.498 4000.0 3306.7 55.8 25.4 3.499 4100.0 3361.0 58.5 22.7 3.500 4200.0 3411.3 61.1 20.1 3.503 4300.0 3457.5 63.9 17.6 3.500 4400.0 3499.4 66.6 15.3 3.496 4500.0 3536.8 69.4 13.0 3.505 4600.0 3569.6 72.3 10.8 3.500 4700.0 3597.6 75.1 8.7 3.496 Page 4 opoi07-04 10-4-10.cfw;10-05-2010; LoadCase 9 5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : 0107-04 Schlemkrger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 Intermediate Casing(a) Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 4800.0 3620.9 78.0 6.7 3.503 4900.0 3639.2 80.9 4.6 3.501 5000.0 3652.5 83.8 2.7 3.501 5100.0 3660.8 86.7 0.7 3.491 5110.5 3661.4 87.0 0.5 3.554 5200.0 3666.1 87.0 0.5 0.000 5210.5 3666.6 87.0 0.5 0.000 5260.5 3669.2 87.0 0.5 0.000 5280.5 3670.3 87.0 0.5 0.000 5300.0 3671.2 87.4 0.5 2.014 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 1909.0 12.00 8.43 Permafrost Siltstone 2124.0 13.00 9.20 Ugnu Top(UG4) Sandstone 2280.0 13.00 9.20 13 5/8 Csg pt. Sandstone 2790.0 13.00 9.20 UG-2 Coal 3758.0 13.00 9.20 L Ugnu Sandstone 4349.0 12.83 9.20 N Top(A) Sandstone 4986.0 12.83 9.20 OA Top Shale 5300.0 12.83 9.20 TD Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1909.0 1851.3 32 0.6 2300.0 2188.3 50 1.4 5300.0 3671.2 86 1.8 Page 5 opoi07-04 10-4-10.cfw;10-05-2010; LoadCase 9 5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : 0107-04 li String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 Intermediate Casing(a) ft degF deg o_ 0 nn 60 90 0 I 60 90 _— Geath.Profile I —Deviation Tubular Fluids —Annulus 11\.\\11(\\ ry 0 — v cn Temp. Profile At 113 min Deviation Section 2: fluid sequence Job Objectives: Cement coverage verifiable to 1000'above the top of the N-Sand Original fluid Mud 9.30 lb/gal k:8.82E-3 lbf.sAn/ft2 n :0.572 Tv:9.46 Ibf/100ft2 Displacement Volume 379.2 bbl Total Volume 625.0 bbl TOC 3349.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 80.0 956.1 2392.9 10.50 k:5.23E-2 lbf.sAn/ft2 n:0.324 Ty:12.92 lbf/100ft2 DeepCRETE(12.5) 165.8 1911.0 3349.0 12.50 k:3.44E-3 lbf.sAn/ft2 n:0.997 Ty:37.44 Ibf/100ft2 Mud 379.2 0.0 9.30 k:8.82E-3 lbf.sAn/ft2 n:0.572 Ty:9.46 lbf/100ft2 Static Security Checks: Frac 418 psi at 2280.0 ft Pore 11 psi at 2280.0 ft Collapse 4419 psi at 5180.0 ft Burst 6870 psi at 0.0 ft Csg.Pump out 68 ton Page 6 opoi07-04 10-4-10.cfw;10-05-2010; LoadCase 9 5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : 0107-04 Schlifilkerger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 Intermediate Casing(a) 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 lnj.Temp. Comments (bbl/min) (bbl) (min) (bbl). (degF) MUDPUSH II 5.0 80.0 16.0 80.0 80 Spacer Ahead Pause 0.0 0.0 5.0 0.0 80 Drop Bottom Plug DeepCRETE(12.5) 4.0 165.8 41.4 165.8 80 Mix&Pump Cement Slurry Pause 0.0 0.0 3.0 0.0 80 Drop Top Plug Pause 0.0 0.0 2.0 0.0 80 Line-up Rig Pumps Mud 8.5 370.0 43.5 370.0 80 Displace Mud 4.0 9.2 2.3 379.2 80 Slow rate Shut-In 0.0 0.0 0.0 0.0 80 Bump Plug Total 01:53 hr:mn 625.0 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 285 psi at 5260.0 ft Pore 11 psi at 2500.0 ft Collapse 4394 psi at 424.6 ft Burst 6447 psi at 0.0 ft Temperature Results BHCT 83 degF Simulated Max HCT 86 degF Simulated BHCT 65 degF Max HCT Depth 5260.0 ft CT at TOC 66 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures : At Time 00:00 hr:mn 00:00 hr:mn Geo.Temp. Top of Cement 66 degF 66 degF 67 degF Bottom Hole 65 degF 65 degF 86 degF Page 7 opoi07-04 10-4-10.cfw;10-05-2010; LoadCase 9 5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : 0107-04 Saki ler String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 Intermediate Casing(a) ft lb/gal 9 10 11 12 13 14 o7 < � - Hydrostatic -Mn.Hydrostatic - Max.Dynamic - Mn.Dynamic -_ Frac - Fore 0- N is O I I - I O O O co— Fluid Sequence Dynamic Well Security ■MUDPUSH II 80.0 bbl 10.50 lb/gal Herschel:k=5.23E-2 Ibf.s^n/ft2 n=0.324 Ty=12.92 Ibf/100ft2 DeepCRETE(12.5) 165.8 bbl 12.50 lb/gal Herschel:k=3.44E-3 Ibf.s^n/ft2 n=0.997 Ty=37.44 Ibf/100ft2 ■Mud 379.2 bbl 9.30 lb/gal Herschel:k=8.82E-3 Ibf.s^n/ft2 n=0.572 Ty=9.46 Ibf/100ft2 Total Depth = 5300.0 ft Top of Cement= 3349.0 ft Page 8 opoi07-04 10-4-10.cfw;10-05-2010; LoadCase 9 5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : 0107-04 Sii be rpi String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 Intermediate Casing(a) ECD Profile at the shoe: Depth= 5260 ft M Frac I Pore Hydrostatic N_ Dynarric i I � I I j N I ; i O_ i O d- in I 1 0 20 40 60 80 100 120 Time(min) ECD Profile at the previous shoe: • Depth= 2280 ft Fluids at 5260 ft Loel 0 1 I r � N Frac Fore I Hydrostatic Dynamic N- 11 to a • � N if O I I i I d- O Lo u i di- I I oal _ 0 20 40 60 80 100 120 Time (min) Page 9 opoi07-04 10-4-10.cfw;10-05-2010; LoadCase 9 5/8 Intermediate Casing(a);Version wcscem461_08 Eni 0107-04 Client : 9 Petroleum Wellt : Prudhoe 9 5/8 District Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 Intermediate Casing(a) Calculated Surface Pressure: Calc.Pump Ress. Calc.VVHP //•g Q N 8-� 0 20 40 60 80 100 120 Time (min) Qin vs.Qout rate of returns: Fluids at 5260 ft Q Out Oh G r co- - I O — — — T 0 20 40 60 80 100 120 Time(min) Page 10 opoi07-04 10-4-10.cfw;10-05-2010; LoadCase 9 5/8 Intermediate Casing(a);Version wcs-cem461_08 Client Eni Petroleum Well : 0107-04 Schlumberger String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 Intermediate Casing(a) Section 4: centralizer placement Top of centralization :3349.0 ft Bottom Cent. MD :5240.0 ft Casing Shoe :5260.0 ft NB of Cent. Used :47 NB of Floating Cent. :47 Centralizer Placement Bottom MD Nbr. Cent.I Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 5260.0 47 1/1 NW-TR-9 5/8-6-TR 3A W090 52.5 3400.0 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 (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications ok ft 0 20 40 60 80 100 o < Betw een Cent. + +At Cent. O O O— Tt o . 0 0 co-- Well Pipe Standoff Page 11 opoi07-04 10-4-10.cfw;10-05-2010; LoadCase 9 5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : 0107-04 STEM IR String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 Intermediate Casing(a) Running Force Calculations: Travelling Block Weight :33 ton Friction Factor Centralizer/Formation :0 Total Drag Force :17 ton Hook load Down Stroke :90 ton Hook load Up Stroke :124 ton ft ton 0 20 40 60 80 100 120 140 o- --� - Hookload Up l-bokload Dow n Weight - Drag Force O O— N 8 O- O O O et- co- Running Forces Page 12 opoi07-04 10.4-10.ctw;10-05-2010; LoadCase 9 5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : 0107-04 hillinkiller String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 Intermediate Casing(a) Section 5: WELLCLEAN II Simulator ft 0 20 40 60 80 100 0 20 40 60 80 100 o - I 1 I I I I -Std Betw.Cent. -Mud Contamination -Cement Coverage -Uncontarrinated Slurry 1 l 1 Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall 3400 - 3400 3400 5400 3800 3600 3600 3600 3600 " 3800 3600 3800 4000 4000 4000 4000 42004200 �- 4200 4200 T .G L a 4400 4400 o n 4400 4400 n 4800 4600 4600 4600 4800 4800 4800 4000 5000 5000 5000 5000 5200 4 5200 5200 5200 0 0 z z IMud l I High Low DeepCRETE(12.5) I 1 Medium = None MUDPUSH II Page 13 opoi07-04 10-4-10.cfw;10-05-2010; LoadCase 9 5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : 0107-04 String : 9 5/8 District : Prudhoe Bay Alaska Country : USA Loadcase : 9 5/8 Intermediate Casing(a) Section 6: fluid description Mud DESIGN Fluid No: 1 Density :9.30 lb/gal Rheo. Model : HERSCHEL_B. k : 8.82E-3 lbf.sAn/ft2 At temp. :80 degF n :0.572 Ty :9.461bf/100ft2 Gel Strength :21.35 Ibf/100ft2 MUD Mud Type :WBM Job volume : 379.2 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil :2.0% Water :94.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.50 lb/gal Rheo. Model : HERSCHEL_B. k : 5.23E-2 lbf.s^n/ft2 At temp. :65 degF n :0.324 Ty : 12.92 lbf/100ft2 Gel Strength :(lbf/100ft2) Job volume :80.0 bbl DeepCRETE(12.5)DESIGN Fluid No:4 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 3.44E-3 Ibf.s^n/ft2 At temp. :63 degF n :0.997 Ty :37.44 lbf/100ft2 w Gel Strength :67.24 Ibf/100ft2 U DESIGN BLEND SLURRY Name : 12.5(0.76) Mix Fluid : 5.176 gal/sk Job volume : 165.8 bbl Dry Density : 119.32 lb/ft3 Yield : 1.54 ft3/sk Quantity :604.93 sk Sack Weight : 100 lb Solid Fraction : 55.0 BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid :5.166 gal/sk Additives Code Conc. Function D046 0.177%BWOB Antifoam D065 0.250%BWOB Dispersant D167 0.250%BWOB Fluid loss D153 0.100%BWOB Antisettling D177 0.010 gal/sk blend Retarder Page 14 opoi07-04 10-4-10.cfw;10-05-2010; LoadCase 9 5/8 Intermediate Casing(a);Version wcscem461_08 SPEO IDENTIFICATION CODE PAG 206 OF 338 ENI S.p.A. Ertl 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 ND where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight (kg/I). SPEO IDENTIFICATION CODE PAG 207 OF 338 ENI S.p.A. Eni E&P Division REVISION STAP-P-1-M-6140 0 1 I 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 I/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. If* SPEO IDENTIFICATION CODE PAG 208 OF 338 ENI S.p.A. En! 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. • S P E O IDENTIFICATION CODE PAG 209 OF 338 ENI S.p.A. Eni E&P Division REVISION STAP-P-1-M-6140 0 1 LEAK-OFF TEST REPORT Report N' Date: WELL NAME: WELL CODE CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m): 825 Mud Type: FWGELS Rigt}pe: J.UPs Hole Dameter(in): 121/4 Weight(KgA): 1.3 R.K.B.ele\eton(rn): 26 Last Cog.Shoe(m). 797 Marsh'Ascosity(sec/Ot): 44 Water Depth(m). 24 diameter(in) 13"35 P.V.(cps): 19 Pumps: 12.P.160 Grade: J55 Y.P.(1b/100 ttO): 5 Liners(in): 6.5" Weight Obit): 61 GelsQb/100 t': 2/8 Flow Rate(bpi): 0.25 Max.Burst pres(psi): 3103 W.L(oc/30 min). 10.5 Litholog y Shale Expected EMW 1.68 Kg/cm2/10 m Time Volume Pressure Time Volume Pressure Time Vdume Pressure (min) (bd) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 400 16 2 435 2 050 100 95 2 480 3 0.75 200 10 2 470 4 100 300 105 2 463 5 125 400 11 2 465 6 150 5013 11.5 2 460 7 1.75 570 12 2 446 8 200 600 13 2 440 8 200 550 14 2 437 8.5 2 D 0 505 15 2 435 Nd e: Pumped with a constant tow rate of(bbl). Wlume pumped(bbl): \blume returned(bbl): (pSi) 1000 900 — B00 , stop pump 700 r e 600 shut in curve S 500 / U 400 r 6 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(bbO 41 1, Time mins RESULTS (Press.R„e+Prete tn.)x10,Depth=[(1.3 x 797 110)+(430 x0.07)]x10 1797=1.68(Kgicm2/10 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 12/18/08 MRT AJR Add New Well Conductors 4-24 2 12/23/08 JFC JMS Add New Well Conductor OP26 Oliktok OLIKTOK 5 el Point 0 INTAKE DOCK OPP 'N THIS I MODULE it t. /5 SURVEYS' _O TANK N •V•>Qr�°� *� DS-3R Eiii DEW LINE 9 SI E STP I / , TANK Nuc STA STAGING AREA, MODULES 1 I DS-3Q ' T13N, R9E '‘'\) / i' l!----'1-'7 iC) C '.. 15 SCALE: 1" = 150' I DS-30 19 \ 21) `A22 STP PAD VICINITY MAP 0-0 SCALE: 1" = 1 Mile 0,0°00 °�O\a \ o 00,0-0 �° 000'0 x 0 (57 \, 7709 09 0 0 '\ 004-0 oCeK, 0 0°-05‘\\\:\ �.0 -0 OI Oq v' 0 O �O7--- 090'3 O0 � 1 \ -----. .? -o N..,-,1) CJS \ /' 1 c \ Z OLIKTOK 0 POINT PAD \ ,,,, \ 0• O \. � ON \ 0 \ n'0 \ T / \ \, SEE SHEET 3 FOR NOTES / \ \ / LOUNSBURY Existing Conductor /---' ..,; & ASSOCIATES, INC. • Conductor Asbuilt this survey / SURVEYORS ENGINEERS PLANNERS 44) / �p'� AREA: MODULE: UNIT: EraEno Petiroll�tui� OLIKTOK CONDUCTOR ASBUINT LTASBUILT LOCATIONS I CADD FILE NO. I DRAWING NO: NSK G.BO-d1 PART: 1 OF 3 I REV: 2 LK680D1 10/9/08 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 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 4414 AREA: MODULE: UNIT: Call Petirdetillrla OLIKTWELL CONDUCTOR POINT D C�III ASBUILT LOCATIONS CAD FILE NO.LK680D1 10/9108 DRAWING NO: NSK 6.80-d1 PART: REV: 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. /��� _ cF. /.� .L SURVEYORS CERTIFICATE : h �� .♦♦ I HEREBY CERTIFY THAT I AM PROPERLY / REGISTERED AND LICENSED TO PRACTICE I , LAND SURVEYING IN THE STATE OF / 73 . r 0 '• gr. ROOKUS %frf)ifit ALASKA AND THAT THIS PLAT REPRESENTS ♦ J' LS-803 A SURVEY DONE BY ME OR UNDER MY ♦♦ TFC•.,. 5• i DIRECT SUPERVISION AND THAT ALL 1♦OTHER DETAILS ARE 1Fp..•114,0 Pao.' DIMENSIONSRECTASA OF DECEMBER 23, 2008. ',,1\"`lvi,rEssi NO-��• 0 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: fiza - �=��11 'r eZ�rOIIe��M OLIKTOK POINT WELL CONDUCTOR PAD C�tii ASBUILT LOCATIONS _ CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80-d1 3 OF 3 2 •*As Schlumberger mil "'EL` 0107-04 1/4 Mile Plot F'ELD Nikaitchuq —TDREOliktok Point Mapnatc Parameten Surface Laaaon 92027 Alaska SUN Pane.200e 00,US Foot Mixalar-orrs Mod, 6GGM2910 DID. W.F. Date November 11.2010 Lal'. N 70 30 39 799 North, 6036554.426U5 Grn1 Com.'.012691230• Slot OPO] ND Ref'. Rotary Taba(5223 above MSL) Mag Dec. 21 384' FS 57641 5nT Lon: W 1495t 47.710 Eaang: 51671103615 Scale Fact'.099990032 Plan 0107-04(P4) Srvr Date segembe,17,2010 -1500 0 1500 3000 4500 N A., 0PO4-07 0106-05(P6) 10500 — 193 — — — 10500 ' TV''., p — 3930 TVD 0107-04 vs 0PO4-07 3953 0107-04 P4) 3938 TW° Within 1/4 mile from -5000'md to TD 3884 TVD V 3937 TVD 0 0PO4-07PB1 1 OP03-P05 3899 TVD 0 3923 TVD 9000 r__.__.___.__.. .. a 1•,. 9000 OP09-S03 (P2)3R5 s 7867 TV k • 3929 ND 3866 TV' • 0107-04 vs OP03-P05 397tj1 • Within 1/4 mile from • -5000'md to TD ct° 3ffri A ti Z 7500 -i .. , 5 a • _ '_.. 7500 3880TVD OP03-P 5PB2 OP23-' 02 3880 TVD o OP08-04 o • 3832 TVD 0 3835 TVD I , TVD r— 4' ! 3840 TVD •v 4,•.0.• iI.4' 3848 TVD 0 3836 TVD .y a ,_..._.. _)c56TVD e— 6000 _....._ — 6000 Ii OP08 04PB1 "''',•\` D! I :88:10Z N 0107-04 vs OP23-WW2 TO• • D I I D ii 3'1``1S500T r I 3851 TVD 3861'1 o Within 1/4 mile from t,,o• -5000'md to--5300'md '3j49`"D• D j1f14 RB U) 11 }g57 TVD ✓ 0107-04 vs OP08-04 59'• 1D D . 3859 TVD ✓ Within 1/4 mile from -- - 4500 -5000'md to-6000'md 1 5499 1Ii, • OP26-DS'02 ,: 2999 OP10-09 (P2) ° '$� • 3371-'DT•' • N 4499D _ 3709 TVD ! i OP12-01� ' a .3]j•I - 3713TVD • OP03-P05PB1-I 3000 OI 1yyy TVD • 1`• 3776 TVD is 0113-03 (P2) -c'O 3�1,, ';•. b . tI 2 • ' •t,4>T I 3S00T1D• 9➢3,�• Oliktok Point I-1 Oliktok Point 1- o • `3;9TVD . 3S%T` r. 1 �. l:299.1' ivo — . — 1500 2. TVD • TiO '9T • • PO 0114-08 (P2) q • I ) ,•,.,F,°g -150, 1500 3000 4500 ( 0114-08 P2 /<< ill''‘ •..Ie 1(in):1500( >>> Oliktok Point I-1 Oliktok Point 1-2 OP12-01 0107-04 (P4 0106-05 (P6) 0113-03 (P2) OP09-S03 (P2)( ) OP03-P05 0111-01 0PO4-07 0P03-P05PB2 OP10-09 (P2) OPO4-07PB1 0P08-04 OP03-P05PB1 ltdWiener 0107-04(P4)Anti-Collision Report Analysis Method: 3D Least Distance Distance Unit: ft Depth Interval: Every 50.00(X)Measured Depth Azimuth Unit: deg Step-down Trajectory: Reference Trajectory TC Azimuth Reference: North Analysis Date-24hr Time: October 01,2010-09:27 North Reference: True Analysis Machine: DELAPP-M4400 Client ENI Database 1 Project: localhost\drilling-projl Version I Patch: 2009 1.745C NOTE.Measured Depth is referenced to individual borehole elevation. TVD,NS.EW are referenced to the reference trajectory's wellhead location and borehole elevation. A minimum of 0.300 m is always included for borehole diameters All local minima indicated. Results filtered:Depth 5000.00 X<=MD<=12232.00 X,Ct-Ct separation<=1320.00 X Anti•Collislon Rules Used Rule Set Name DAM AntiCollison Standard Exemption Risk Level: Minor Rule Name Risk Level Rule Tvoe Rule Label NOGo Rule SLB Alert Zone Threshold OSF=5.0 v4.0 Alert Ratio OSF=5.00 SLB Minor Risk Threshold OSF=1.5 v4.0 Minor Ratio OSF=1.50 X SLB Major Risk Threshold OSF=1.0 v4.0 Major Ratio OSF=1.00 SLB Template Surface Hole 80%ADP v4.0 Major Fixed MAS=32.81(ft) SLB Single Well Surface Hole 10m v4.0 Major Fixed MAS=32.81(9) nnnn<7A0 n Ln L..a..1.....\nI1La..L o...,.enrm nnrnin,nx\nin=nn inns In/I ronin n.00 nna o.,,...I ,.a.c Reference Trajectory Summary Field: Nikeflchuq Well: 0107-04 Structure: 0111dok Point Borehole: 0107-04 Slot: OP07 Trajectory: 0107-04(P4) Client: ENI Type: Da/Plan Structure MAS: 4.159(ft) Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12891234° God Scale Factor: 0.99990032 Magnetic Declination: 21.384' Magnetic Declination Date: November 11,2010 Magnetic Model: BGGM 2010 Reference Point: Northing Easting Elevation Structure Unc.(1ed) Slot Unc.(1sd) 6038554.420(ftUS) 516711,030(fIUS) 52.200(11)MSL 0.000(fl) 0.000(%) Trajectory Error Model:ISCWSAO 3-D95.000%Confidence 2.7955 sigma Surveying Proa: MD From IN MD To(ft) EOU Freu Iftl Survey Tool Time (tole Diameter tin) Borehole I Sumac 0.000 40.000 1/100.000 SLB_GYRO-MWD-Depth Only-No Global 16000 0107-04/0107.04(P4) 40.000 1200.000 1/100.000 SLB_GYRO-MWD-No Global 16.000 0107-04/0107-04(P4) 1200.000 2279.988 1/100.000 SLB_MWD+GMAG-No Global 18.000 0107-04/0107-04(P4) 5260.526 1/100.000 SLB_MWD+GMAG^^2-No Global 12.250 0107-04/0107-04(P4) 5280.528 12231.877 1/100.000 SLS_MWD+GMAG^^3-No Global 8.500 0107-04/0107-04(P4) • • IY Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0107-04\0107-04\0107-04(P4) 10/1/2010 9:33 AM Page 2 of 16 Offset Trajectory Summary Offset Selection Criteria: Wellhead distance scan:Restricted within 40000 ft Offset Selection Criteria: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 Selection Summary Wells Selected 4 Boreholes Selected:8 Definitive Surveys Selected:8 Non-Del Surveys Selected:0 Definitive Plans Selected:0 Non-Del Plans Selected•0 Total Trajectories:8 Tra ect Borehole Well Type OPO8-04 OP08-04 OP08.04 Def Survey OP08-04PB1 OP08-04P51 OP08-04 Def Survey OP03-P05PB1 OP03-P05PB1 OP03-P05 Def Survey OP03-P05 OP03-P05 OP03-P05 Def Survey OP03-P05PB2 OP03-P05PB2 OP03-P05 Def Survey OPO4.07 OPO4-07 OPO4.07 Def Survey OPO4-07P81 OPO4-07PB1 OPO4-07 Def Survey OP23-W W02 OP23-W W02 OP23-W W 02 Def Survey • Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0107-04\0107-04\0107-04(P4) 10/1/2010 9:33 AM Page 3 of 16 Field: Nlkeifchuq Well: OP08-04 Structure: Olikfok Point Borehole: OP08-04 Slot: OP08 Trajectory: OP08-04 Client: ENI Type: Def Survey Structure MAS: 4.159(OJ Coordinate System: NAD27 Alaska State Plane,Zone 04.US Feet North Reference: True Grid Convergence Angle: 0.12885757° Grid Scale Factor: 0 99990032 Magnetic Declination: 21.564° Magnetic Declination Date: July 08,2010 Magnetic Model: BGGM 2010 Reference Point: Northing Elevation Structure Una(1 sd( Slot Una(tsd( 6036550 670((US) 518703.940(SUS) 53.300(ft)MSL 0000(ft) 0000(0) Trajectory Error Model:ISCWSAO 3-D95.000%Confidence 2.7955 sigma Surveying Prop: MD From(61 MDT OU Fre Survey Tool Tyne pole Diameter lin) j3orehole I Survey 0.000 41.100 Act-Stns SLB_GYRO-MWD-Depth Only-No Global 18.000 OP08-04PB1/OP08-04PB1(Projected-Up) 41.100 41.100 Act-Stns SLB_GYRO-MWD-Depth Only-No Global 18.000 OP08-04PB1/OP08-04PB1 • 41.100 834.520 Act-Stns SLB GYRO-MWD-No Global 16.000 OP08-04P81/OP08-04PB1 834.520 2281.410 Act-Stns SLB MWD0GMAG-No Global 16.000 OP08-04PB1/OP08-04PB1 • 2261.410 4954.890 Act-Stns SLB_MWD.GMAG-No Global 12.250 OP08-04PB1/OP08-04P91 4954.890 8059.610 Act-Stns SLB MWDoGMAG-No Global 8.500 OP08-04PB1/0P08.04PB1 8059.610 11240.000 Act-Stns SLB MWD+GMAG-No Global 8.500 OP08-04/OP08-04 • Reference Cylinder North MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) All local minima indicated. • Results filtered:Depth 5000.00 ft<=MD<=12232.00 ft Results filtered:Ct-Ct separation<=1320.00 ft Results highlighted:Ct-Ct separation<a 1320.00 ft 505000 365727 2479.92 1199.01 4675.18 3800.32 2467.85 -117.43 27307 1317.74 5100.00 3660.79 2529.78 1200.05 4736.10 3608.45 2528.01 -118.09 272.93 1319.19 5150.00 3663.43 2579.71 1200.51 482428 3615.83 2615.87 -117.48 272.62 1310.33 5200.00 3666.05 2829.84 1200.94 4893.44 3620.05 2684.86 -114.96 272.60 1317.87 5250.00 3688.67 2879.57 1201.38 4942.35 3623.29 2733.63 -113.05 272.57 1316.32 5280.53 3670.26 2710.05 1201.64 4968.29 3825.19 2759.48 -112.08 272.55 1315.42 530000 3671.22 2729.50 1201.81 4983.03 3826.38 2774.16 -111.59 272.48 1314.92 5350.00 3673.06 2779.47 1202.17 5029.45 3630.40 2820.38 -110.27 27228 1313.77 5400.00 3674.04 2829.46 1202.44 5079.99 3634.45 2870.74 -108.82 272.00 1312.50 5450.00 367421 2879.46 1202.82 5142.49 3838.99 2933.04 -106.74 271.74 1310.94 5500.00 3674.22 2929.46 1202.80 5196.88 3642.60 298726 -104.39 271.58 1308.84 5550.00 367423 2978.46 1202.97 522953 3644.22 3019.85 -103.20 271.51 1307.14 5600.00 3674.23 3029.48 1203.14 526225 3645.24 305254 -102.43 271.47 1306.09 5850.00 3674.24 3079.46 1203.31 5294.05 3845.66 3084.34 -102.09 271.45 1305.72 5700.00 3674.25 3129.46 1203.48 5324.31 3645.58 3114.60 -102.20 27145 130608 575000 3674.26 3179.45 1203.85 535454 3645.04 3144.82 -102.76 271.48 130720 5800.00 3674.26 3229.45 1203.83 5388.57 3643.93 3178.81 -103.90 27153 1309.06 5850.00 3674.27 3279.45 1204.00 5436.52 3642.25 3226.69 -105.75 271.60 1311.20 5900.00 3674.28 332945 1204.17 5483.05 3840.72 3273.16 -107.63 271.68 1313.43 595000 3674.29 3379.45 1204.34 5524.51 3839.54 3314.56 -109.51 271.71 1315.91 6000.00 367429 3429.45 1204.51 5565.95 3638.57 3355.93 -11186 27175 1318.71 End of results Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0107-04\0107-04\0107-04(P4) 10/1/2010 9:33 AM Page 4 of 16 Field: Nikeilchug Well: OP06.04 Structure: 056106 Point Borehole: OP08-04P81 Slot: OP08 Trajectory: OP08.04PB7 Client: ENI Type: Del Survey Structure MAS: 4.150(8) Coordinate System: NAD27 Alaska State Plane.Zone 04,US Feet North Reference. True Grid Convergence Angle: 0.12885757° Grid Scale Factor: 0.99980032 Magnetic Declination. 21.581° Magnetic Declination Date: June26,2010 Magnetic Model: BGGM 2010 Reference Point: Northing E449ng Elevation Structure Unc.11sd( Slot Unc.11edl 6036550 670(flUS) 510703 940(BUS) 53.300(6)MSL 0000(6) 0000(8) Trajectory Error Model:ISCWSAO 3-D95.000%Confidence 2.7955 sigma Surveying Prog: MD From IBI MD To(ftl EOU Frea Survey Tool Type Hole Diameter lin( Borehole I Survey 0.000 41.100 Act-Stns SLB_GYRO-MWD-Depth Only-No Global 16.000 OP08-04P8110P08-04PB1 41.100 834.520 Act-Stns SLB GYRO-MWD-No Global 16.000 OP08-04PB1/OP08-04PB1 834.520 2261.410 Act-Stns SLB__MWD+GMAG-No Global 16.000 OP08-04PB1 I OP08-04P61 2261.410 4954.890 Act-Stns SLB_MWD+GMAG-No Global 12.250 OP08-04PB1/OP08-04PB1 4954.890 8840.000 Act-Stns SLB_MWD+GMAG-No Global 8.500 OP08-04PB1/OP08-04PB1 Reference Cylinder North MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance (8) (ft) (B) (8) (B) (B) (0) (ft) (°) (B) All local minima indicated. Results filtered:Depth 5000.00 B<=MD 0=12232.00 ft Results filtered:Ct-Ct separation<=1320.00 B Results highlighted:Ct•Ct separation<=1320.00 B 5050.00 3657.27 2470.92 1199.01 467518 3600.32 2467.65 -117.43 273.87 1317.74 5100.00 3660.79 2529.78 1200.05 4736.10 3608.45 2528.01 -118.09 272.93 131910 5150.00 3663.43 2579.71 1200.51 482428 3615.83 2615 87 -117 46 272.62 1310.33 5200.00 3666.05 2620.64 1200.94 489344 3620.05 2684.86 -114.96 272.60 1317.87 5250.00 3668.67 2678.57 1201.38 4942 35 3623.29 2733.63 -113.05 272.57 1316.32 5280.53 3670.26 2710.05 1201.64 4968.29 3625.19 2759.48 -112 08 272.55 1315.42 5300.00 3671.22 272950 1201.81 4983 03 3626.38 2774.16 -111.59 27248 1314.02 5350.00 3673.06 2779.47 1202.17 5025.45 363040 2820.38 -110.27 27226 1313.77 5400.00 3674.04 2829.46 120244 5079.99 3634 45 2870.74 -108.82 272.00 1312.50 5450.00 3674 21 2879.46 1202.62 5142.49 3638 99 2933 04 -106.74 271.74 1310.94 5500.00 3674 22 2929 46 1202.80 5196 88 3642.60 2987.26 -104 39 271.58 1308.84 5550 00 3674.23 2975 46 1202.87 5229.53 3644.22 3019.85 -103.20 271.51 1307.14 5600.00 3674 23 3029 46 1203.14 526225 3645.24 3052.54 -102.43 271 47 1306.09 5650.00 3674 24 3079.46 1203.31 5294.05 3645.66 3084.34 -102.09 271 45 1305.72 5700.00 3674.25 3129.46 1203.48 5324.31 3645.58 3114 60 -102.20 271 45 1306.08 5750.00 3674.26 3178.45 1203.65 5354.54 3645.04 3144.82 -102 76 27148 1307.20 5800.00 3674 26 3229.45 1203.83 5388.57 3643 93 3178.81 -103 90 271 53 1309.06 5850.00 3674.27 3278.45 1204.00 543652 3842.25 3226.68 -105 75 271.600 1311.20 5900.00 3674.28 3329.45 120417 5483.05 3640.72 3273.16 -107.63 271.66 1313.43 5950.00 3674.28 3379.45 1204.34 5524.51 3639.54 3314.56 -109.51 271.71 1315.01 6000 00 3674 29 3429.45 1204 51 5565.95 3638 57 3355 93 -111 66 271 75 1318.71 End of results • • • Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0107-04\0107-04\0107-04(P4) 10/1/2010 9:33 AM Page 5 of 16 Field: Nikeitchuq Well: OP03-PO5 Structure: Oliktok Point Borehole: OP03-PO5PB1 Slot: OP03 Trajectory: OPO3-PO5PB1 Client: ENI Type: Det Survey Structure MAS: 4.159(5) Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12918509° Grid Scale Factor: 0.99990032 Magnetic Declination: 22.488° Magnetic Declination Date: November 15,2008 Magnetic Model: BGGM 2008 Reference Point: Northing Easting b ion Structure Unc.ltsd) Slot Unc.lt sd) 6036573.110(OUS) 516746.340(8US) 53.200(11)MSL 0.000(8) 0.000(8) Tralectory Error Model:ISCWSAO 3-D95.000%Confidence 2.7955 sigma Surveying Prop: MD From IR) MD To Ott EOU Freq Survey Tool Digo Hole Diameter lin) Borehole I Survey 0.000 41.000 Act-Stns SLB_NSG+SSHOT-Depth Only-No Global 16000 OP03-P05PB1/OP03-P05PB1 41.000 643.000 Act-Stns SLB_NSG+SSHOT-No Global 16.000 OP03-P05PB1/OP03-P05PB1 643.000 2289.220 Act-Stns SLB_MWD+GMAG-No Global 16000 OP03-P05PB1/OP03-PO5PBI 2289.220 6045.000 Act-Stns SLB MWD+GMAG""2-No Global 12.250 OP03-P05P81/OP03-P05PB1 Reference Cylinder North MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance (8) (ft) (0) (ft) (if) (ft) (6) (ft) (°) (ft) All local minima indicated. Results filtered Depth 5000.00 8<=MD<=12232.00 8 Results 6Oered Ct-Ct separation<_1320.00 0 Results highlighted.Ct-Ct separation<=1320.00 O 5050 00 3657 27 2479.92 1199.01 5595.66 3598 38 2291 39 2488.96 89.64 1304.98 5100 00 3660 79 2529.78 1200.05 5658.35 3621 74 2348.84 2498.05 89A1 1311.13 5150 00 3663 43 2579 71 1200 51 5730 98 3649 39 2415 34 2507 47 90 24 1317 33 End of results Field: Nikailchuq Well: OP03-P05 Structure: Oliktok Point Borehole: OP03-P05 Slot: OP03 Trajectory: OP03-P05 Client: ENI Type: De!Survey Structure MAS: 4.159(N) Coordinate System: NAD27 Alaska Stale Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12918509° Grid Scale Factor: 0.99990032 Magnetic Declination: 22.447° Magnetic Declination Date: December 15,2008 Magnetic Model: BGGM 2008 Reference Point: Pilornsj kiLe.tingley ion Structure Unc.11sdt Slot Unc.(1sd) 6036573.110(WS) 516746.340(WS) 53.200(8)MSL 0.000(0) 0.000(8) Trajectory Error Model:ISCWSAO 3-D95.600%Confidence 2.7955 sigma Surveying Prom MD From fft l MD Tc_4(111 OU Fre Survey Tool Type Hole Diameter lin) Borehole 1 Survey 0.000 41.000 Act-Stns SLB_NSG+SSHOT-Depth Only-No Global 16.000 OP03-P05PB1/OP03-P05PB1 41.000 643.000 Act-Stns SLB_NSG+SSHOT-No Global 16000 OP03-PO5PB1/OP03-P05PB1 643.000 2280.220 Act-Stns SLB MWD+GMAG-No Global 16.000 OP03-P05PB1/OP03-P05PB1 2289.220 5195.770 Act-Stns SLB_MWD+GMAG^^2-No Global 12.250 OP03-P05PB1/OP03-P05PB1 5195.770 5935 300 Act-Stns SLB_MWD+GMAG^^2-No Global 12.250 OP03-P05PB2/OP03-P05PB2 5935.300 9594.120 Act-Stns SLB_MWD+GMAG^^3-No Global 8.500 OP03-P05PB2/OP03-P05P82 9594.120 12384.000 Ad-Stns SLB_MWD+GMAG^^3-No Global 8.500 OP03-P05/OP03-P05 Reference Cylinder North MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance (6) (ft) (rt) (p) (6) (8) (8) (0) (°) (6) All local minima indicated. Results filtered:Depth 5000.00 8<=MD<=12232.00 fl Results filtered:Ct-Ct separation<=1320.00 8 Results highlighted.Ct-Cl separation<=1320.00 8 5050.00 3657.27 2479.92 1199.01 5817.93 3659.06 2505.87 2478.40 01.52 1279.65 510000 3660.79 2529.78 1200.05 5869.69 3670.05 2556.44 2477 40 91.01 1277.66 5150.00 3663.43 2579.71 120051 5930.52 3680.56 2616.33 2475.61 91.16 1275.94 5200.00 3668.05 2629.84 1200.94 5968.80 3686.02 2654.20 2474 79 91.31 1274.24 • 5250.00 3888.67 2679.57 1201.38 600524 3690.72 2690.33 2474.21 91.44 1273.07 530050 3871.22 2729.50 1201.81 6041.76 3694.96 2726.61 247402 91.51 1272.44 5350.00 3873.06 2779.47 1202.17 6087.73 3699.52 2772.35 2474.18 91.55 1272.31 5400.00 3674.04 2829.46 120244 6139.64 3703.31 2824.11 2474.35 9158 1272.27 5450.00 3674.21 287946 1202.62 6194.71 3706.30 2879.11 2474.42 91.84 1272.20 5500.00 367422 292946 1202.80 6250.33 3709.44 293463 2474.22 91.78 1271.03 5550.00 367423 2979.46 1202.97 6298.29 3711.34 2982.55 2474.01 91.87 1271,50 5600.00 367423 3029.46 1203.14 6346.61 3711.62 3030.87 2473.93 01.88 1271.34 5850.00 3674.24 3079.46 1203.31 6399.92 3710.85 3084.18 2473.82 91.85 1271,04 5700.00 3674.25 312946 120348 6462.50 3709.46 3148.74 2473.45 91.78 1270.57 5750.00 3874.26 3179.45 1203.85 6548.09 3709.30 3232.29 2471.05 91.78 1268.98 5800.00 3674.26 322945 1203.83 8622.18 3711.11 3308.25 246720 91.87 1266.25 5850.00 3674.27 3279.45 1204 00 6691.81 3713.96 3375.66 2462.35 92.00 1262.85 5900.00 367428 3329.45 120417 675056 3716.66 3434.14 2457.49 92.13 1258.40 5950.00 3674.29 337945 1204.34 6800.54 3718.88 3483.89 245325 92.24 1254.06 8000.00 3674.29 3420.45 1204.51 6845.83 3720.88 3528.98 2449.46 92.33 1249.78 6050.00 3674.30 3479.45 1204.68 6888.23 3721.83 3571.24 2448.17 92.39 1245.78 6100.00 3874.31 3529.45 1204.85 6936.22 3722.54 3619.10 2442.71 92.43 1242.03 8150.00 3674.32 357945 1205.03 6993.51 3723.64 3676.21 2438.36 92.49 1238.10 6200.00 3674.34 3629.45 120520 7051.30 3725.11 3733.79 2433.80 92.55 1233.87 6250.00 3674.98 3679.45 1205.38 7108.78 372646 3791.03 2428.49 92.52 1229.26 6300.00 3876.48 372942 1205.59 7148.45 3727.65 3830.52 2425.00 92.48 1224.66 6350.00 3678.40 3779.39 1205.80 7188.17 3729.43 3870.07 2421.81 92.47 1220.45 6400.00 3880.32 3829.35 1206.01 7221.27 3731.32 3903.03 2419.45 92.51 1216.74 6450.00 3682.23 3879.31 1206.23 725020 3733.06 3931.87 2417.87 92.54 1213.85 6500.00 3684.15 3929.27 1206.44 7279.18 3734.86 3980.78 2416.79 92.58 1211.82 6550.00 3686.07 3979.24 1206.66 7314.24 3737.16 3995.75 2416.09 92.62 1210.63 6600.00 3687.99 4029.20 1206.87 7362.64 3741.41 4043.96 241528 92.74 1200.88 6650.00 3689.91 4079.16 1207.08 7409.21 3748.76 4090.21 2414.52 92.91 1208.83 6700.00 3691.82 4129.13 1207.30 7452.45 3752.00 4133.13 2414.00 93.08 1208.21 6750.00 3694.11 4179.07 1207.51 7493.74 3757.01 4174.11 2413.72 93.22 1207.86 6784.04 3896.16 4213.05 1207.65 7511.11 3759.02 4191.38 2413.81 93.27 1207.90 680000 3897.22 4228.97 1207.72 7519.25 3759.90 4199.46 241393 93.29 1208.20 68.50.00 370053 4278.86 1207.93 7544.79 3762.47 4224.86 2414.88 93.33 1209.54 6900.00 3703.84 4328.75 1208.15 7570.31 3764.69 4250.24 2415.96 93.35 1211.89 6950.00 3707.15 4378.84 1208.36 7508.07 3766.74 4277.88 2417.94 93.36 1215.23 7000.00 3710.46 4428.53 1208.57 7629.40 3788.83 4309.01 2420.68 93.34 1219.37 7050.00 3713.77 4478.42 1208.78 7660.63 3770.10 4340.04 2423.90 93.31 122427 7100.00 3717.08 4528.31 1209.00 7701.97 3771.80 4381.06 2428.79 93.24 1220.86 7150.00 3720.39 4578.20 1209.21 7764.65 3775.35 444323 2435.79 9320 1235.21 7200.00 3723.70 4828.09 1209.42 7856.40 3785.41 453405 2443.90 93.37 1239.59 7219.18 372497 4847.23 120950 7887.70 3790.23 4564.91 2445.82 93.49 1240.78 7250.00 3727.18 4077.07 1209.63 792729 3796.78 460390 2447.93 93.68 1242.47 7300.00 373121 4727.81 1209.83 7986.19 3807.18 4661.81 245052 93.95 1244.77 7350.00 3735.26 4777.64 1210.02 8033.07 3815.38 4707.93• 2452.53 94.14 1247.03 • 740000 3739.31 482748 121022 8077.89 3822.82 475208 245458 04.31 124944 7450.00 3743.36 4877.31 1210.42 8117.30 382847 4791.02 2456.73 94.42 1252.19 7500.00 3747.41 4927.15 1210.61 8156.77 3833.04 4830.14 2459.29 0448 1255.38 • 7550.00 3751.46 4976.98 1210.81 819623 3836.53 4869.33 2482.26 94.48 1258.95 7800.00 3755.93 5026.78 1211.02 8235.60 3839.00 4908.48 2465.62 94.52 1262.90 7650.00 3761.27 5076.50 1211.24 827758 3840.54 4950.24 2469.62 94.48 1267.17 7700.00 3767.47 5126.11 1211.49 8322.86 3841.07 4995.28 2474.18 94.35 1271.58 7750.00 3774.54 5175.61 1211.76 8377.86 3840.44 5049.99 2479.89 94.06 1276.04 7800.00 3782.46 5224.07 121206 8458.02 3841.14 5129.83 2486.82 93.62 1279.65 785000 379095 527425 1212.39 8554.64 3844.85 5226.22 2492.07 93.06 1281.72 7900.00 3799.44 532352 1212.72 8645.71 3848 67 5317 19 2493.68 92.53 1281 92 • Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0107-04\0107-04\0107-04(P4) 10/1/2010 9:33 AM Page 7 of 16 Trajectory'0107-04(P4)Vs.OP03-P05 Reference Cylinder North MD Reference TVD Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW Nim Ct-Ct Distance (8) (n) (ff) (ft) (ft) (8) (ft) (ft) (°) (n) 7950.00 3807.59 5372.65 1213.04 8685.77 3849.87 5357.24 2493.98 92.29 1281.73 8000.00 3814 88 5422.31 1213.36 8725.82 3850.67 5397 28 2494.59 92.05 1281.97 805000 3821.31 5471.89 1213 68 8770.26 3851 18 5441 71 2495 55 91.80 1282.58 8100.00 3826.87 5521.58 1213.99 8815.93 3851.45 5487.35 2496 69 91 56 1283 40 8150.00 3831.57 5571 36 1214.29 8869.91 3851.40 5541.32 2498.09 91.31 1284 31 8200.00 3835.39 5621 21 1214.58 8927.74 3850 75 5599.14 2499.28 91 06 1284.08 8250.00 3838.34 5671 12 1214.87 9008.00 3850.10 5879.39 2499 72 90.81 1284.93 8300 00 3840.42 5721.08 1215 14 9063.57 3850.32 5734.96 2499 16 90.69 1284 13 8350 00 3841.64 5771 06 1215.36 9114.12 3850.71 5785.50 2498.60 90.62 1283.35 8400 00 3842 45 5821 06 1215.56 9161 14 3850.82 5832.52 2498.12 90.59 1282.63 8450.00 3843.27 5871 05 1215.77 9207.89 3850.17 5879.25 2497 76 90.53 1282.04 8500 00 3844 09 5921.04 1215.97 9271.03 3847.95 5942.35 2497 09 90.39 1281.30 8550.00 3844.90 597104 121617 9354.74 384313 6025.89 2494.81 9011 1279.81 8600.00 3845 72 6021.03 1216.38 942645 3839.98 609742 2490.79 89.91 1276.72 8650 00 3846.54 6071.02 1216.58 9466.69 3838.33 6137.56 2488.53 89.81 1273.72 8700.00 3847.35 6121.01 1216.78 9514.08 3836.39 6184.85 248620 89.69 127107 8750.00 3847.69 6171 01 1216.99 959226 3838.27 6262 87 248141 89.73 1267.80 880000 3847 16 6221 01 1217.20 9649.76 3838.44 6320.17 2477.08 89.94 1263.81 8850.00 3845 76 6270.99 1217.41 970221 3841.25 6372.37 2472.87 90.22 1259.55 8900.00 3843 68 6320 94 1217.63 9743.68 3843 74 6413 64 246968 90 44 1255.48 8950.00 3841.57 6370.90 1217.84 9785 16 3846.34 6454.94 2466.76 90.64 1251.75 9000 00 383945 6420.85 1218 05 9815 99 3848.11 6485.66 2464.91 90 78 1248.57 9050.00 3837.34 8470.81 1218.26 9846 53 3849 41 6516 15 2463.55 90.90 1246.17 9100 00 3835.22 6520 76 1218.48 0877.19 3850.27 6546 78 246266 91.00 1244.55 9150.00 3833.24 6570 72 1218.69 9916.86 3851 08 6586.43 246202 91 10 1243 56 9200 00 3832.04 6620.71 121B 90 9958.53 3852 16 6628.09 2461.62 91 18 1242.90 9243.83 383170 6664.53 1219.09 10002.40 3853.64 6671.94 246140 91.26 1242.53 9250.00 383171 6670.70 121912 10009.78 3853.96 6679.31 2461.35 91.27 1242.46 9300.00 3832.11 6720.70 1219.33 10069.48 3857 33 6738.91 2460.64 91 40 1241.70 9350.00 3832.58 6770.70 1219.54 10115.36 3860.68 6784.65 2459.95 91.53 1240.81 9400.00 3833.06 8820.70 1219.75 10159.95 3864.23 682910 2459.47 91.68 1240.13 9450.00 3833.54 6870.68 1219.97 10218.55 3869 07 6887.50 2458.81 91 88 1239.47 9500.00 3834.02 6920.69 1220.18 10277.60 3873 65 6946.36 245760 92 06 1238.32 955000 3834.50 6970.89 1220.39 10325.01 3876.62 6993 66 2456.57 92.18 1237.11 960000 3834.97 7020.60 1220.60 10371 78 3878.70 7040.38 2455.68 92.26 1236.01 9650.00 3835.45 7070.68 122082 10415.94 3879.78 7084.52 2455.05 92.29 123510 9700.00 3835.93 7120.68 1221.03 10460.35 3879.96 7128.92 245465 92.28 1234 43 9743 90 3836.35 7164.58 1221.22 10501.20 3879.78 7169.77 2454.43 92.26 1233.99 9750.00 3836.41 7170.68 122124 10506.87 3879 76 7175.45 2454.41 92.25 1233.94 9800.00 3836 92 7220.87 1221.45 10553.40 3879.54 7221.98 2454.30 9222 1233.58 9850.00 3837 44 7270.67 1221.67 10643.76 3880.69 7312.30 2452.69 92.23 1232.49 9900.00 3837.95 7320.67 1221.88 10701.13 3882.80 7369.59 245048 92.31 1230.40 9950.00 3838.46 7370.67 1222.09 10755.73 3885.43 7424.08 2448.00 92.41 1228.06 10000.00 3838.97 7420.86 1222.31 1080543 3887.88 7473.67 2445.84 92.51 122566 10050.00 3839.48 7470.66 1222.52 10853.77 3890.12 7521.90 2443.67 92.59 122328 10100.00 3840 00 7520.66 1222.73 10899.46 3802.03 7587.51 2441 76 92.66 1221.04 1015000 3840.64 7570.65 1222.05 10945.85 3893.73 7613.84 2439.98 92 70 1218.96 10200.00 3842 07 7620.83 1223 16 10994.80 3895.61 7662.72 2438.10 92 68 1218.94 10250.00 3844.37 7670.58 1223.37 11041.62 3897.60 7709.47 2436.51 92.64 1214.93 1030000 3847.54 772047 1223.58 11082.52 3899 13 775032 243529 92.56 1213.17 10350.00 3851.03 7770.35 1223.78 1112340 3900.30 7791.17 2434.38 92.48 1211.78 10400.00 3854.53 7820.23 1223.99 11163.25 3901.29 7831.01 2433.82 92.39 1210.78 10450.00 3858.02 7870.11 1224.20 1120307 3902 35 7870.81 2433.59 92.31 1210.20 10500.00 3861.52 7919.98 1224.41 11240.73 390335 790846 2433.71 92.24 1210.08 10550.00 3865.01 7969.86 1224.62 1127666 3903.98 7944 37 243423 92.15 1210.51 10600.00 3868.51 8019.74 1224.82 11312.53 3904 27 7980.23 2435.19 92.04 1211.54 10650.00 3872.00 8069.62 1225.03 11363.69 3904 77 8031.37 2436.86 91.89 1212.88 10700 00 3875.33 8119.50 1225.25 11417.43 3906 37 8085.05 2438.43 91.81 1214 07 10750.00 3877.85 8169.44 1225.49 1147044 3908.46 8138.01 2439.81 91.80 1215.11 10800.00 3879.49 8219.41 1225 79 11524.09 3910.66 8191.60 2441.07 91.85 1218.00 10850.00 3880.74 8269.39 1226.10 11570.34 391313 8246.78 2442.15 91.90 1218.89 10900.00 3881.99 8319.38 1226.42 11628.05 3915 33 8295.43 2442.96 61.95 1217.24 10950 00 3883.23 8369.36 1226.73 11671.44 3916.48 8338.80 2443.90 91.95 1218.01 11000.00 3884.48 8419.34 1227.05 11716.14 3916.78 8383.47 2445.13 91.91 1219.04 • 11050.00 3885.73 8469.33 1227.37 11763.09 3916.94 8430.40 2446.57 91.86 1220.22 11100.00 3886.97 8519.31 1227.68 11811.68 391712 8478.97 2448.16 91.81 1221.52 11150 00 3888.22 8569.29 1228.00 11863.82 3917.44 8531.08 2449.83 91 77 1222.78 11200.00 3889.47 8619.28 1228.31 11852.41 3918.99 8619.84 2451.53 91.73 1223.57 11250.00 3890 66 8669.26 1228.62 12022.88 3922 10 869002 2450.53 91.72 1222.49 11300.00 3891.56 8719.25 1228.83 12071.47 3924.39 8738.55 2449.67 91.76 1221.44 11350.00 3882.45 8769.25 1229.04 1212323 3926.90 8790.24 2448.77 91.84 122039 11400.00 3893.35 8819.24 1229.25 12176.12 3929.81 8843 04 2447.71 91.93 1219.24 11450 00 3894.24 8869.23 1229.46 12215.55 3931 85 8882.42 2447.03 92.00 1218.22 • 11500 00 3895.13 8919.22 1229.68 1225404 3933 16 8920 88 2446.76 92.03 1217.67 11550 00 3896.03 8969.21 1229.89 12293.70 3933.83 8960.53 2446.86 92.02 1217 59 11600 00 3896.92 9019.20 1235.10 12337.17 3933 90 9004.00 2447.32 91.99 1217 88 11650.00 3897 82 9069.20 123031 12384 00 3933 79 8050.83 2447.91 91 95 121827 11693.35 3898.59 9112.53 1230.50 12384.00 3933.79 9050.83 2447.91 9195 1219.49 11700.00 3898.70 9119.19 1230.52 12384.00 3833 79 9050.83 2447.91 91.94 1219.81 11750.00 3899.04 9169 18 1230.74 12384 00 3833.79 9050.83 2447.91 91.87 1223.41 11800.00 3898.51 9218.18 1230.95 12384 00 3933 79 9050 83 2447.91 91.76 1229.06 • 11850.00 3897.12 926816 123117 12384.00 3933.79 9050.83 2447.91 91.63 1236.72 11900.00 3895.42 9319 13 1231.38 12384 00 3933.79 9050.83 2447.91 91.63 1246.36 11950.00 3893.71 9369 10 1231 60 12384 00 3933.79 9050.83 2447.91 91.63 1257.90 12000 00 3892.01 9419 07 1231 81 12384 00 3933 70 9050 83 244701 91 63 1271 32 Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0107-04\0107-04\0107-04(P4) 10/1/2010 9:33 AM Page 8 of 16 Trajectory.0107-04(P4)Vs.OP03-P05 Reference Cylinder North MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance (0) (0) (6) (ft) (6) (6) (ft) (0) (°) (8) 1205000 3890.30 9469.04 1232.03 12384.00 3933.79 9050.83 2447.91 91.63 1286.53 1210000 388860 951901 123224 12384.DO 393379 905083 244791 9163 130349 End of results Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0107-04\0107-04\0107-04(P4) 10/1/2010 9:33 AM Paae 9 of 16 Field: Nikaltchuq Well: OP03-P05 Structure: Oliktok Point Borehole: OP03-P05PB2 Slot: OP03 Trajectory: OP03-P05P82 Client: ENI Type: Del Survey Structure MAS: 4.159(1l) Coordinate System: NAD27 Alaska Stale Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12918509° Grid Scale Factor: 0.99990032 Magnetic Declination: 22.442° Magnetic Declination Date: December 19,2008 Magnetic Model: BGGM 2008 Reference Point: Northin anti Elev ion Structure Unc,11sdt Slot Lino-lied) 6036573.110(WS) 516746.340(ftUS) 53.200(ft)MSL 0.000(ft) 0.000(ft) Trajectory Error Model:ISCWSAO 3.1)95.000%Confidence 2.7955 sigma Survevinti Prop: MD From Mt MD To 1R1 gOU Free Survey Tool Type Hole Diameter NO 13orehole I Survey 0.000 41000 Act-Stns SLB_NSG+SSHOT-Depth Only-No Global 16.000 OP03-P05PB1/OP03-P05PB1 41.000 643.000 Act-Stns SLB_NSG+SSHOT-No Global 16 000 OP03-P05PB1/OP03-P05PB1 643.000 2289.220 Act-Stns SLB_MWD+GMAG-No Global 16.000 OP03-P05PB1/OP03-P05PB1 2289.220 5195.770 Act-Stns SLB_MWD+GMAG^^2•No Global 12.250 OP03-P05PB1/OP03-P05PB1 5195.770 5935.300 Act-Stns SLB_MWD+GMAG""2-No Global 12.250 OP03-P05P82/OP03-P05PB2 5935.300 10040.000 Act-Stns SLB_MWD+GMAG""3-No Global 8.500 OP03-P05PB2/OP03-P05P82 • Reference Cylinder North MD Reference ND Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW Azim Ct-Ct Distance (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) All local minima indicated. Results filtered:Depth 5000.00 ft<=MD<-12232.00 ft Resets filtered:Ct-Ct separation<=1320.00 ft Results highlighted:Ct-Ct separation<-1320.00 ft 5050.00 3657.27 2479.82 1199.01 5817.93 3659.06 2505.87 2478.40 91.52 1279.65 5100.00 3680.79 2529 78 '1200.05 5869.69 3670.05 2556.44 2477.40 91.01 1277.88 5150.00 3683.43 2579.71 1200.51 5930.52 3680.56 2618.33 2475.81 91.16 1275.94 5200.00 3666.05 2629.64 120094 5968.80 3686.02 2854.20 2474.79 91.31 1274.24 525000 3688.67 2679.57 1201.38 8005.24 3690.72 2690.33 2474.21 91.44 127307 5300,00 3871.22 2729.50 1201.81 604176 369496 2726.61 2474.02 91.51 1272.44 5350.00 3673.06 2779.47 1202.17 6087.73 3698.52 2772.35 2474.18 91.55 1272.31 5400.00 3674.04 2829.46 1202.44 8139.64 370331 2824.11 2474.35 91.58 1272.27 5450.00 367421 287946 1202.82 6194.71 3706.30 2879.11 247442 91.64 1272.20 5500.00 367422 2929.46 1202.80 6250.33 3709.44 2934.63 2474.22 91.78 1271.93 5550.00 3674.23 2979.46 1202.97 6298.29 3711.34 2982.55 247401 91.87 1271.59 5800.00 3874.23 3029.46 1203.14 6348.81 3711.62 3030.87 2473.93 91.88 1271.34 9650.00 3874.24 307946 1203.31 6399.92 3710.85 3084.18 2473.82 91.85 1271.04 5700.00 3874.25 3129.46 120348 8462.50 3709.46 3146.74 247345 91.78 1270.57 5750.00 3674.26 317945 1203.65 6548.09 3709.30 323229 2471.05 91.78 1268.98 5800.00 3674.26 3229.45 1203.83 6822.18 3711.11 3306.25 2467.20 91.87 1266.25 5850.00 3674.27 3279,45 1204.00 6691.81 3713.96 3375.68 2462.35 92.00 1262.65 5900.00 3674.28 3329.45 1204.17 6750.56 3716.66 3434.14 2457.49 92.13 1258.40 5950.00 3674.29 3379.45 1204.34 6800.54 3718.88 3483.88 2453.25 92.24 1254.06 6000.00 3674.29 342945 1204.51 6845.83 3720.88 3528.98 2449.46 92.33 1249.78 6050.00 3674.30 3479.45 1204.68 688823 3721.83 3571.24 2446.17 92.39 1245.78 6100.00 3674.31 352945 1204.85 693622 3722.54 3819.10 2442.71 92.43 1242.03 615000 3674.32 357945 1205.03 6993.51 3723.64 3676.21 2438,36 92.49 1238.10 620000 3674.34 362945 1205.20 7051.30 3725.11 3733.79 2433.80 92.55 1233.87 6250.00 3674.98 3679.45 1205.38 7108.78 3726.46 3791.03 242849 92,52 122926 6300.00 3676.48 3729.42 1205.59 7148.45 3727.65 3830.52 2425.00 92.48 1224.86 6350.00 367840 3779.39 1205.80 7188.17 3729.43 3870.07 2421.81 92.47 1220.45 6400.00 3880.32 3829.35 1206.01 7221.27 373132 390303 241945 92.51 1218.74 6450.00 3882.23 3879.31 1206.23 725020 3733.06 3931,87 2417.87 92.54 1213.85 6500.00 3684.15 392927 1206.44 7279.18 3734.86 3960.78 2416.79 92.58 1211.82 6550.00 3686.07 3979.24 1206.66 7314.24 3737.16 3995.75 2416.09 92.62 1210.63 6600.00 3687.99 4029.20 1206.87 7362.64 3741.41 4043.96 2415.28 92.74 1209.88 665000 3689.91 4079.16 1207.08 7409.21 3746.76 4090.21 2414.52 92.91 1208.83 6700.00 3691.82 4129.13 1207.30 7452.45 3752.00 4133.13 2414.00 93.08 1208.21 6750.00 3694.11 4179.07 1207.51 7493.74 3757.01 4174.11 2413.72 9322 1207.86 6784.04 3696.16 4213.05 1207,65 7511.11 3759.02 4191.36 2413.81 83.27 1207.99 6800.00 3697.22 4228.97 1207.72 7519.25 3759.90 419946 241393 93.29 1208.20 6850.00 3700.53 4278.86 1207.93 7544.79 3762.47 4224.86 2414.68 93.33 1209.54 6900.00 3703.84 4328.75 1208.15 7570.31 3784.69 4250.24 2415.96 93.35 1211.89 6950.00 3707.15 4378.64 1208.36 7598.07 3766.74 4277.86 2417.94 93.36 1215.23 7000.00 3710.46 4428.53 1208.57 7629.40 3768.63 4309.01 2420.68 93.34 1219.37 7050.00 3713.77 4478.42 1208.78 7680.63 3770.10 434004 2423.90 93.31 1224.27 7100.00 3717.08 4528.31 1209.00 7701.97 3771.60 4381.06 2428.79 93.24 1229.88 7150.00 3720.39 4578.20 1209.21 7764.65 3775.35 4443.23 2435.79 93.20 123521 7200.00 3723.70 4828.09 1209.42 7856.40 3785.41 4534.05 2443.90 93.37 1239.59 7218.18 3724.97 4647.23 1209.50 7887.70 3790.23 4564.91 2445.82 93.48 1240.78 7250.00 3727.18 4677.07 1209.83 792729 3798.78 4803.90 2447.93 93,68 124247 730000 3731.21 4727.81 1209.83 7986.19 3807.18 4681.81 2450.52 93.95 1244.77 7350.00 3735.26 4777.64 1210.02 8033.07 3815.36 4707.93 2452.53 94.14 1247.03 7400.00 3739.31 4827,48 1210.22 8077.89 3822.82 4752.08 2454.58 94.31 1248.44 7450.00 3743.36 4877.31 1210.42 8117.30 3828.47 4791.02 2456.73 94.42 1252.19 7500.00 3747.41 4927.15 1210.61 8156,77 3833.09 4830.14 2459.29 94.48 1255.36 7550.00 3751.46 4978.98 1210.81 8196.23 3836.53 4889.33 2482.26 9448 1256.95 7800.00 3755.93 5026.78 121102 8235.60 3839.00 4908.48 2465.82 94.52 1262.90 7650.00 376127 5076.50 1211.24 8277.58 3840.54 495024 2489.62 94.48 126717 7700.00 3767.47 5126.11 1211.49 8322.86 3841.07 4985.28 2474.18 94.35 1271.58 7750.00 3774.54 5175.61 1211.76 8377.86 3840.44 5049.99 2479.89 94.06 1276.04 7800.00 3782.46 5224.97 1212.06 845802 3841.14 512983 2486.82 93.82 1279.65 7850.00 3790.95 5274.25 121239 8554.64 3844.85 522622 2492.07 93.06 128172 7900.00 3799.44 5323.52 1212.72 8645.71 3848.67 5317.19 2493.68 92.53 1281.92 7950.00 3807.59 5372.85 1213.04 8685 77 3849 87 5357.24 2493.98 92.29 1281 73 Drilling Office,,2009.1.745.0 Nikaitchuq\Oliktok Point\0107-04\0107-04\0107-04(P4) 10/1/2010 9:33 AM Page 10 of 16 Trajectory:0107-04(P4)Vs.OP03-P05P62 Reference Cylinder North MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) 8000.00 3814.88 5422.31 1213.38 8725.82 3850.67 5397.28 2494.59 92.05 128197 8050.00 3821.31 5471 89 1213.68 877026 3851 18 5441.71 2485.55 91 80 1282 58 8100.00 3826.87 5521.58 1213.99 8815.93 3851.45 5487.35 2496.69 91.56 1283 40 815000 3831.57 5571.36 1214.29 8869.91 3851.40 5541.32 2498.09 91 31 1284 31 8200 00 3835.39 5621.21 1214.58 8927.74 3850.75 5599 14 2499.28 91 06 1284 98 8250.00 3838.34 5671 12 1214.87 9008.00 3850.10 5679.39 2499.72 80.81 1284 93 8300 00 3840.42 5721 08 1215 14 9063.57 3850.32 5734.96 2499 16 90.69 1284 13 8350.00 3841.64 5771 06 1215.36 9114 12 3850.71 5785.50 2498.60 BO 62 1283.35 8400.00 3842.45 582106 1215.56 9161.14 3850.82 5832.52 249812 90.59 1282.63 8450.00 3843.27 5871 05 1215.77 9207 89 3850.17 5879.25 2497 76 90.53 1282 04 8500 00 3844 09 5921 04 1215.97 9271.03 3847.95 5942.35 2497.09 90.39 1281.30 8550.00 3844.90 597104 1216.17 9354.74 3843.13 6025.89 2494.81 80i1 1279.81 8600.00 3845.72 6021.03 1216.38 9426.45 3830 98 6097.42 2490.79 89.91 1276.72 865000 3846.54 6071.02 1216 58 9466.69 3838.33 6137.56 2488.53 89 81 1273.72 8700.00 3847.35 8121.01 1216.78 9514.08 3836.39 6184.85 248620 80 69 1271.07 8750.00 3847 69 6171.01 1216 99 9592 26 3836.27 6262.87 2481.41 80 73 1267.80 8800 00 3847 16 6221 01 1217.20 9648.28 3837.86 6318.71 247722 89 91 1263.83 8850 00 3845.76 6270.99 121741 9704.80 3839.25 6375.04 2472.73 90 13 1259.63 8900.00 3843.68 6320.94 1217.63 9764 91 3840.10 6434.91 2467.52 90 31 1255 08 8950.00 3841 57 6370 90 1217.84 9805.94 384024 6475 78 2463.81 90.40 1250 38 9000.00 3839.45 6420.85 1218.05 9837.30 384021 6507.04 2461.41 90.46 1246.34 9050.00 3837 34 6470 81 1218.26 8868 74 3840.07 6538.42 245047 90.51 1243.04 9100.00 3835.22 6520 76 1218.48 9903 35 3839.73 6572.99 2457.82 90.57 1240.45 9150.00 3833.24 8570 72 1218.68 0940.08 3838.89 8609 68 2456 47 90.57 1238.41 9200.00 3832.04 6620 71 1218.90 9976.83 3837 52 6646.40 2455 52 90 52 1236 90 9250.00 3831 71 6870.70 1219.12 10025.51 3835.31 6695.02 2454.57 BO 41 1235 70 9300.00 3832 11 6720 70 1219.33 10040.00 3834.65 6709.49 2454.29 90 36 1235 01 8350.00 3832.58 6770.70 1219.54 10040.00 3834.65 6709.49 2454.29 90 36 1238.26 9400 00 3833.06 6820.70 1219.75 10040.00 3834.65 6700 49 2454.29 90.36 1239.53 9450.00 3833.54 6870.69 1219.87 10040.00 3834 65 6700 49 2454.29 90.36 1244 80 9500.00 3834 02 6920 69 1220 18 10040.00 3834.65 6709.49 2454.29 90.36 1252 05 9550.00 3834.50 6970 69 1220.39 10040.00 3834.65 6709.49 2454.29 90.36 1261.24 9600 00 3834 97 7020.89 1220.60 10040.00 3834.65 6709.49 2454.29 90.36 1272.33 9650.00 3835 45 7070.68 1220.82 10040.00 3834 65 6709.49 2454.29 90.36 1285.27 9700.00 3835.93 7120.68 1221.03 1004000 3834.65 6709.49 2454.29 90.36 1300.00 9750 00 3836.41 7170.68 1221 24 10040.00 3834 85 6709.49 2454.29 90 38 1316 47 End of results Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0107-04\0107-04\0107-04(P4) 10/1/2010 9:33 AM Page 11 of 16 Field: Nikeilchuq Well: OPO4-07 Structure: Oliktob Point Borehole: OPO4-07 Slot: OPO4 Trajectory: OPO4-07 Client: ENI Type: Del Survey Structure MAS: 4.159(4) Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12913048° Grid Scale Factor: 0.99990032 Magnetic Declination: 21.610° Magnetic Declination Date: June 06,2010 Magnetic Model: BGGM 2010 Reference Point: Northing astin Elevation Structure UncJlsd) Slot Unc.11 di) 6036569.440(SUS) 516739.270(SUS) 53.360(ft)MSL 0.000(0) 0.000(ft) Trajectory Error Model:ISCWSAO 3-D95.000%Confidence 2.7955 sigma Surveying Pros: MD From lft1 M To k FOU Free Survey Tool Ty Hos Diameter(in) J;<orehole I Survey 0.000 41.160 Act-Stns SLB_NSG+SSHOT-Depth Only-No Global 76.000 OPO4-07P81/OPO4-07PB1 41.160 566.000 Act-Stns SLB_NSG+SSHOT-No Global 16.000 OPO4-07PB1/OPO4-07PB1 586.000 2382.520 Act-Stns SLB_MWD+GMAG-No Global 16.000 OPO4-07PB1/OPO4-07PB1 2382.520 8750.000 Act-Stns SLB_MWD+GMAG-No Global 12250 OPO4-07PB1/OPO4-07PB1 8750.000 9880 180 Act-Stns SLB_MWD+GMAG-No Global 8.500 OPO4-07PB1/OPO4-07PB1 9880 190 12144.000 Act-Stns SLB MWD+GMAG-No Global 8 500 OPO4-07/OPO4-07 Reference Cylinder North MD Reference TVD Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW Azim Ct-Ct Distance (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) All local minima indicated. Results filtered.Depth 5000.00 ft<=MD<=12232.00 ft Results filtered.Ct-Ct separation<=1320.00 ft Results highlighted:Cl-Ct separation<=1320.00 ft 6150.00 3674 32 3579.45 1205.03 5415.29 2982.40 3837.93 11441 302.57 1317.20 6200.00 3674 34 3629.45 1205.20 5463.11 2996 16 3883.67 116.51 302.14 1307.58 6250.00 3674.98 3679.45 1205.38 5510.28 3009 74 3928.81 118.59 301.87 1298 40 6300.00 3676.48 3729.42 1205.59 5556.36 3022.90 3972.92 120.61 301.82 1289.82 6350.00 3678.40 3779.39 1205.80 5604.08 3036.40 4018.64 122.70 30121 128161 6400.00 3680.32 3829.35 1208.01 5656.24 3051.28 4068.58 125.00 300.75 1273 39 6450.00 368223 3879.31 1206.23 570720 3066 00 4117 31 127.30 300.29 1265 10 6500.00 3684.15 3929.27 1206.44 5756.65 308018 4164.63 129.66 299.85 1256.84 • 6550.00 3686.07 3979.24 1206.66 5807.36 3094 57 4213 19 13224 299 40 1248.59 6600.00 3687.99 4029.20 1206.87 5859.36 3109 35 4262.96 135.03 298.93 1240.28 6650.00 3689.91 4079.18 1207.08 5908.77 3123 44 4310.24 137.78 298.48 1231 95 6700.00 369182 4129.13 1207.30 5956.74 3137.10 4356.15 140.45 298.04 1223.69 6750.00 3694.11 4178.07 1207.51 6005.02 3150.83 4402 35 143 14 297 74 1215 68 6800.00 369722 4228.97 1207.72 8053.59 3164.66 4448.84 145.83 297 42 1208 13 6850.00 3700.53 4278.86 1207.93 6106.82 3179.87 4499.87 148.85 296 98 1200.86 6900.00 3703.84 4328.75 1208.15 6162.53 3195.86 4553.02 15227 296.50 1192.99 6950.00 3707.15 4378.64 1208.36 6212 11 3210 15 4600.38 155.48 296.08 1185.21 7000.00 371046 4428.53 1208.57 6261 16 3224.22 4647.25 158 72 295 66 1177.48 705000 3713.77 4478.42 1208.78 6302.98 3236 15 4687.25 161.39 295 30 1169.94 7100.00 3717.08 4528.31 1209.00 6344.88 3247 99 4727 37 163.86 294.94 1162 75 7150.00 372039 4578.20 1209.21 6458.28 3281.82 4835.24 172 38 293.88 1154.74 7200.00 3723.70 4628.08 1209.42 6534 52 3307.28 4906.66 180.37 293.07 1144.53 7250.00 3727.18 4677.97 1209.63 6575.14 3321 37 4944.48 184 90 292 73 1133.92 7300.00 373121 4727.81 1209.83 6608 98 3332.53 4976.23 188 50 292.43 1124.17 7350.00 3735.26 4777.64 1210.02 864318 3343.19 5008.55 191.96 29210 111512 7400.00 3739.31 4827.48 1210.22 6686 56 3355 97 5049 77 19626 291.73 1106.56 7450.00 3743.36 4877.31 1210.42 6730.90 3368 32 5092.11 200.78 291 37 1098.25 7500.00 3747.41 4927 15 1210.61 677744 3380 79 5136.70 205.57 291.03 1090 15 7550.00 375146 4976.98 1210.81 6824.55 3393.49 5181.82 210.30 290.66 108218 7600.00 3755.93 5026.78 1211.02 6866.76 3405.00 522223 214.35 290.50 1074.57 7650.00 3761.27 5078.50 1211.24 8907.50 3416.34 5261.20 217.83 290.35 1067.69 7700.00 3767.47 5126.11 1211.49 6949.34 3428.21 5301.20 220.97 290 IS 1061.55 7750.00 3774.54 5175.81 1211.76 6992 76 3440.54 5342.72 223.96 290.05 1056.05 780000 3782.46 5224.97 1212.06 7034.64 3452 41 5382.80 226.59 289.95 1051 19 7850.00 3790.95 527425 1212.39 7071.87 3462 94 5418.46 228.54 289 77 1047.06 7900.00 379944 5323.52 1212.72 7109.15 3473.47 5454.18 230.03 289.57 1043.55 7950 00 3807.59 5372.85 121304 7162.60 3488.62 5505.41 231 78 289 19 1040.27 8000.00 3814.88 5422.31 1213.36 7222.70 3505.89 5562.92 234 30 288.69 1036.25 8050.00 382131 5471.89 1213.68 7272.81 352013 5610.90 236.71 288.21 1031.74 8100.00 3826.87 5521.58 1213.99 7319.97 3533.13 565618 239.16 287.73 1026.98 8150.00 3831.57 5571.36 1214.29 7354.90 3542.63 5689 75 240.68 287.32 1022.46 8200.00 3835.39 5621 21 1214.58 7389.75 3552 08 5723.28 241.69 286.88 1018.43 8250.00 3838.34 567112 1214.87 7426.09 356191 5758.26 242.25 286.39 1014.90 8300.00 3840.42 5721 08 1215.14 748412 357219 5794.88 242.40 285.81 1011 74 8350.00 3841 64 5771 06 1215.36 7501.99 3582 43 5831 34 242 13 285 19 1008 95 8400.00 3842.45 5821.06 1215.56 7543.59 3593.66 5871.38 241.47 284 60 1006 62 8450.00 3843.27 5871 05 1215.77 7585.47 3604 93 5911.71 240.54 284.00 1004.75 8500.00 3844.09 5921 04 1215.97 7624.67 3615.46 5949.45 239 38 283 43 1003.40 8550 00 3844 90 5971 04 1216.17 7662.32 3625.55 5985.69 237 86 282.88 1002.71 8600.00 3845 72 6021.03 1216.38 7700.50 3635 77 6022.42 235.91 282.32 1002.69 8650.00 3846.54 6071.02 1216.58 7743.36 364717 6163.66 233.41 281.68 1003.21 8697.66 3847 32 6118.67 1216.77 7784.23 3657 94 6103 01 230.82 281 09 1004.09 8700.00 3847.35 6121 01 1216.78 778624 3658 47 6104.94 230.69 281 06 1004 15 8750.00 3847 69 6171 01 1216.99 7833.55 3670 77 6150.52 227.56 280.38 1005 34 8800.00 3847 16 6221 01 121720 7881 52 3682 96 6196.80 224.41 279.66 1006.57 8850 00 3845 76 6270.99 1217.41 7934.45 3696.45 6247.87 221.06 278.82 1007.75 • 8900 00 3843 68 6320 94 1217 63 7986.20 371020 6297.67 217 98 277.91 1008.78 8950 00 3841.57 637090 1217.84 8025.69 3720 47 6335 72 215.56 277.22 1010.18 9000.00 3839.45 6420.85 1218 05 8065.59 3730 13 6374.34 212.88 276.57 1012 17 9050.00 3837.34 6470 81 1218.26 8117.15 3741 67 6424 46 209.30 275.78 1014.55 9100 00 3835.22 6520 76 1218 48 8175 17 3753 67 6481 13 205 84 274 55 1016 69 Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0107-04\0107-04\0107-04(P4) 10/1/2010 9:33 AM Page 12 of 16 Trajectory:0107-04(P4)Vs.OPO4-07 Reference Cylinder North MD Reference TVD Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW Azim C1-Ct Distancel I (8) (ft) (9) (6) (f) (It) (9) (9) (1 (It) 9122.57 3834.27 6543.31 1218.57 8204.81 3759.28 6509.98 204.38 274.58 1017.52 9150.00 3833.24 6570.72 1218.69 8240.75 3765.59 6545.54 202.89 274.11 1018.36 9200.00 3832.04 662071 1218.90 8294.72 3773.91 8588.84 20128 273.54 1019.52 9250.00 383171 6670.70 1219.12 8338.68 3780.11 6642.34 199.87 273.14 1020.94 930000 3832.11 8720.70 1219.33 8385.63 378632 8888.84 198.16 27279 1022.69 9350.00 3832.58 6770.70 1219.54 8437.42 3793.27 8740.13 198.31 272.43 1024.45 9400.00 383306 8820.70 1219.75 8487.74 3800.27 678993 19459 272.08 1028.15 9450.00 3833.54 8870.89 1219.97 8536.87 3807.32 6838.32 192.89 271.89 1027.92 950000 383402 8920.89 1220.18 858400 3814.34 6885.10 191.21 271.32 1029.77 9550.00 3834.50 6970.89 1220.39 8630.14 3821.11 6930.70 189.43 270.98 1031.83 960000 3834.97 7020.69 1220.80 8687.95 3829.13 6987.91 187.18 270.55 1033.98 9650.00 3835.45 7070.88 122082 875624 3837.21 7055.70 185.77 270.14 1035.15 9700.00 3835.93 7120.68 1221.03 8806.07 3842.85 7105.21 185.07 289.85 1036.10 9742.79 3836.34 7163.47 1221.21 8852.41 3847.95 7151.26 184.48 289.59 1038.89 9743.90 3836.35 716458 1221.22 8853.72 3848.09 7152.57 184.45 26959 1038.90 975000 3836.41 7170.68 1221.24 8860.93 3848.86 7150.73 184.38 26955 1037.00 9800.00 383692 7220.67 1221.45 8920.05 3854.86 7218.54 184.09 26925 1037.52 9850.00 3837.44 727067 1221.67 8966.43 3858.74 7284.77 184.00 269.08 1037.90 9900.00 3837.95 7320.67 1221.88 9012.15 3861.16 7310.42 183.70 288.96 1038.49 9950.00 3838.46 7370.67 1222.09 9060.61 3862.40 7358.86 183.20 268.01 1039.23 10000.00 3838.97 7420.86 1222.31 910958 3882.65 7407.82 182.83 258.93 1040.03 1005000 383948 7470.66 122252 9147.11 3862.49 7445.34 181.98 268.96 1041.13 1010000 3840.00 752088 1222.73 9183.82 3882.55 7482.03 180.83 268 98 1042.86 1015000 3840.84 7570.65 1222.95 9225.64 3862.85 7523.82 179.03 268.97 1045.20 10200.00 3842.07 7820.83 1223.18 9281.94 3863.44 758007 176.89 288.98 1047.47 10250.00 3844.37 7670.58 1223.37 933792 3864.11 7636.01 174.71 269.05 1049.42 10300.00 384754 7720.47 1223.58 9393.59 3864.45 7691.65 173.03 269.19 1051.08 10350.00 385103 7770.35 1223.78 9439.50 3884.51 7737.54 171.72 289.38 1052.613 10400.00 3854.53 7820.23 1223.99 948353 3864.50 7781.55 17023 26953 1054.52 1045000 385802 7870.11 1224.20 952875 3864.47 7826.73 168.46 269.71 1056.65 10500.00 3861.52 791998 122441 9574.59 3864.67 7872.53 166.49 269.87 1058.96 10550.00 386501 7989.86 1224.62 9826.19 3865.18 7924.07 164.17 270.04 1081.44 1060000 3868.51 8019.74 1224.82 968222 3866.06 7980.05 161.91 270.20 1063.95 1065000 3872.00 8089.82 1225.03 9724.60 38666.93 8022.39 160.22 270.32 1085.87 1070000 3875.33 8119.50 122525 9765.05 3867.90 8062.78 158.25 27047 1068.53 1075000 3877.85 8189.44 1225.49 9804.36 3868.96 8102.00 155.97 270.82 1071.88 10800.00 3879.49 821941 1225.79 9842.47 3870.03 8140.01 153.36 270.75 107541 10850.00 3880.74 8269.39 1228.10 9880.57 3871.12 8177.98 150.33 270.74 1079.70 10900.00 3881.99 8319.38 1226.42 9926.33 3872.42 8223.54 146.36 270.73 1084.35 10950.00 3883.23 8369.36 1228.73 997205 3873.64 8289.06 142.22 270.73 1089.18 11000.00 3884.48 8419.34 1227.05 10013.21 3874.87 8310.01 138.27 270.72 1094.29 11050.00 3885.73 8489.33 1227.37 10053.74 3876.46 8350.29 13405 270.88 1099.82 11100.00 3886.97 8519.31 1227.68 10099.88 3878.87 8398.09 128.91 270.63 1105.70 11150.00 388822 8569.29 1228.00 10150.99 3881.25 8446.82 123.23 270.56 1111.58 11200.00 3889.47 8619.28 1228.31 10221.23 3884.85 851659 115.99 270.46 1117.07 11250.00 3890.66 8669.26 122862 10287.57 3888.10 8582.83 110.52 270.31 1121.48 11300.00 3891.56 8719.25 122883 10341.32 3890.51 8838.17 106.46 270.22 1125.45 11350.00 3892.45 8769.25 1229.04 1039165 3892.60 8886.31 102.78 270.16 1129.31 11400.00 3893.35 8819.24 1229 25 1044027 3894.56 8734.77 99.18 270.10 1133.22 11450.00 3894.24 8869.23 1229.46 10483.50 3896.21 8777.84 95.87 270.06 1137.27 • 11500.00 3895.13 8919.22 1229.68 1052450 3897.54 8818.67 9243 270.03 1141.69 11550.00 3896.03 8969.21 1229.89 10573.22 3898.78 8867.18 88.01 270.01 1146.43 11800.00 3896.92 9019.20 1230.10 1063551 389944 892923 82.81 27003 1150.82 11650.00 3897.82 9069.20 1230.31 10707.91 3900.14 9001.46 77.82 270.06 1154.49 11700.00 3898.70 9119.19 1230.52 10789.17 390225 9062.60 74.68 270.02 1157.25 11750.00 3899.04 9169.18 1230.74 10818.82 3904.45 9112.15 72.24 289.98 1159.91 11800.00 3898.51 9219.18 1230.95 10886.58 3907.95 917975 89.30 269.82 1162.36 11850.00 3897.12 9269.16 1231.17 10968.95 3912.80 9261.96 67.68 269.50 1163.83 • 1190000 389542 9319.13 1231.38 11068.02 3919.15 9360.80 69.05 269.02 1163.32 1195000 3893.71 9369.10 1231.80 11169.09 3923.92 9461.56 75.25 268.60 1160.43 12000.00 3892.01 9419.07 1231.81 11241.32 3826.69 9533.43 81.87 268.34 1156.13 1205000 3890.30 9469.04 123203 11300.32 3929.25 9592.06 88.02 268.10 1151.26 12100.00 3888.60 9519.01 123224 11341.72 3931.43 9833.15 92.47 267.91 1146.28 12150.00 3886.89 9568.98 1232.46 11376.59 3933.86 9867.78 95.80 267.72 1141.91 12200.00 3885.19 9618.95 1232.67 11411.40 3936.86 9702.34 98.71 267.51 1138.20 12231.88 3884 10 9650 81 1232 81 11435.03 3939.09 9725.80 10045 287.35 1138.17 End of results • Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0107-04\0107-04\0107-04(P4) 10/1/2010 9:33 AM Page 13 of 16 Field: Nikeilchuq Well: OPO4-07 Structure: Okklok Point Borehole: OPO4-07PB I Slot: OPO4 Trajectory: OPO4-07PB7 Client: ENI Type: Del Survey Structure MAS: 4.159 Off Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet North Reference: True Grld Convergence Angle: 0.12913048° Grid Scale Factor: 099990032 Magnetic Declination: 21.706° Magnetic Declination Date: May 18,2010 Magnetic Model: BGGM 2009 Reference Point: Northingamain Qylidigg Structure Unc.tled( Slot Unc.tlsd( 6036569.440(BUS) 516739.270(ftUS) 53.360(ft)MSL 0.000(B) 0.000(ft) Trajectory Error Model:ISCWSAO 3-D95.000%Confidence 27955 sigma Surveying Prop: MD From(R( MD To(RI 01, ,leg Survey Tool Type Hole Diameter lint Borehole I Surve1( 0.000 41.160 Act-Stns SLB_NSG•SSHOT-Depth Only-No Global 16.000 0PO4-07PB1/OPO4-07PB1 41.160 566.000 Act-Stns SLB_NSG•SSHOT-No Global 16.000 OPO4-07PB1/OPO4-07PB1 568.000 2382.520 Ad-Stns SLB MWD+GMAG-No Global 16000 OPO4-07PB1/OPO4-07PB1 2382.520 8750.000 Act-Stns SLB_MWDuGMAG-No Global 12.250 OPO4-07PB1 I OPO4-07PB1 8750.000 10540.000 Act-Stns SLB_MWD♦GMAG-No Global 8.500 OPO4-07PB1/OPO4-07PB1 Reference Cylinder North MD Reference TVD Reference NS Reference EW Offset MD Offset TVD Offset NS Offset EW Azim Ct-Ct Distance (ft) (B) (fl) (B) lit) (ft) (ft) (ft) (°) (ft) All local minima indicated. Results filtered,Depth 5000.00 fl<=MD<=12232.00 fl Results filtered:Ct-Ct separation<=1320.00 fl Results highlighted:Cl-Ct separation<=1320.00 ft 6150.00 3674.32 3579.45 120503 5415.29 2982.40 3837.93 114.41 302.57 1317.20 6200.00 3674.34 3629.45 120520 5463.11 2996.16 3883.67 116.51 302.14 1307.59 6250.00 3674.98 367945 1205.38 5510.28 3009.74 3528.81 118.55 301.87 1298.40 6300.00 3678.48 3729.42 120559 5556.36 3022.90 3972.92 120.61 301.62 1289.82 6350.00 3678.40 3779.39 1205.80 5604.08 303640 401864 12270 301.21 1281.81 6400.00 3680.32 3829.35 1206.01 565624 3051.28 4068.58 125.00 300.75 1273.39 6450.00 3882.23 3879.31 1206.23 570720 3066.00 4117.31 127.30 30029 1265.10 6500.00 3684.15 3929.27 120644 5756.85 3080.18 416483 125.66 299.85 1256.84 6550.00 3888.07 397924 1208.66 5807.36 3094.57 4213.19 13224 299.40 1248.59 6600.00 3687.99 402920 1206.87 5859.36 3109.35 4262.98 13503 298.93 1240.28 6650.00 3689.91 4079.16 1207.08 5808.77 3123.44 431024 13778 298.48 1231.95 6700.00 3691.82 4129.13 1207.30 595674 3137.10 4356.15 140.45 298.04 1223.69 6750.00 3694.11 4179.07 1207.51 6005.02 3150.83 4402.35 143.14 297.74 1215.88 6800.00 3697.22 422897 1207.72 6053.55 3184.66 4448.84 145.83 297.42 1208.13 6850.00 3700.53 4278.86 1207.93 6106.92 3179.87 4409.87 148.85 296.58 1200.86 6900.00 3703.84 432875 1208.15 8182.53 3195.86 4553.02 15227 29650 1192.59 695000 3707.15 4378.84 1208.36 6212.11 3210.15 4800.38 155.48 296.08 118521 700000 3710.46 4428.53 1208.57 8261.16 3224.22 4847.25 15872 295.86 1177.48 7050.00 3713.77 4478.42 1208.78 6302.98 3236.15 4887.25 181.39 295.30 1169.94 7100.00 3717.08 4528.31 1209.00 6344.88 3247.99 4727.37 163.88 294.94 1162.75 7150.00 3720.39 4578.20 1209.21 645828 3281.82 483524 172.38 253.88 1154 74 7200.00 3723.70 4628.09 1209.42 6534.52 3307.28 4908.88 180.37 293 07 1144.53 7250.00 3727.18 4677.97 1209.63 657514 3321.37 4944.48 184.90 292.73 1133.92 7300.00 3731.21 4727.81 1209.83 660898 3332.53 4976.23 188.50 292 43 1124 17 7350.00 3735.26 4777.64 1210.02 6843.18 3343.19 5008.55 191.96 29210 1115.12 7400.00 3739.31 482748 1210.22 8686.56 3355.97 5049.77 196.26 291.73 1108.56 7450.00 3743.38 4877.31 1210.42 8730.90 3368.32 5092.11 200.78 291.37 1098.25 7500.00 3747.41 4927.15 1210.61 6777.44 3380.79 5138.70 205.57 291.03 1090.15 7550.00 3751.46 4576.98 1210.81 682455 339349 5181.82 210.30 290.66 1082.18 7600.00 375593 5026.78 1211.02 6886.76 3405.00 5222.23 214.35 290.50 1074.57 7850.00 3781.27 5076.50 1211.24 8907.50 3416.34 528120 217.83 290.35 1067.69 770000 378747 5126.11 1211.49 8949.34 3428.21 5301.20 220.97 290.19 1061.55 775000 377454 5175.81 1211.76 6992.76 3440.54 5342.72 223.96 290.05 1056.05 780000 378246 522497 1212.06 7034.64 3452.41 5382.80 226.59 289.95 1051.19 785000 379095 527425 1212.39 7071.87 346294 5418.48 228.54 289.77 1047.06 790000 3709.44 5323.52 1212.72 7109.15 3473.47 5454.18 230.03 289.57 1043.55 7950.00 3807.59 5372.85 1213.04 7162.60 348882 5505.41 231.79 28919 1040.27 8000.00 3814.88 5422.31 1213.36 7222.70 350589 5582.92 234.30 288.85 1036.25 8050.00 3821.31 5471.89 1213.68 7272.81 3520.13 5610.90 236.71 288.21 1031.74 8100.00 3826.87 5521.58 1213.99 7319.97 3533.13 5856.18 239.16 287.73 1026.98 8150.00 3831.57 5571.36 1214.29 7354.90 3542.83 5880.75 240.88 287.32 1022.46 8200.00 3835.39 5621.21 1214.58 7389.75 3552.08 5723.28 241.89 28888 101843 825000 3838.34 5671.12 1214.87 7426.09 3561.91 5758.26 24225 288.35 1014.90 8300.00 384042 5721.08 1215.14 7464.12 3572.19 5794.88 242.40 28581 1011.74 8350.00 3841.64 5771.06 1215.38 7501.99 3582.43 5831.34 242.13 285.19 1008.95 8400.00 3842.45 5821.06 1215.56 7543.59 3593.66 5871.38 241.47 284.80 1006.62 8450.00 3843.27 5871.05 1215.77 7585.47 360493 5911.71 240.54 284.00 1004.75 8500.170 384409 5921.04 1215.07 7624.67 3615.46 5949.45 23938 283.43 1003.40 8550.00 384490 5971.04 1218.17 7662.32 3825.55 5985.89 237.86 282.88 1002.71 8600.00 3845.72 6021.03 1216.38 7700.50 3635.77 6022.42 235.91 282.32 1002.89 8650.00 384854 6071.02 1216.58 774336 3647.17 6083.66 233.41 281.68 100321 8697.66 3847.32 6118.67 1218.77 7784.23 3657.94 6103.01 230.82 281.09 1004.09 8700.00 3847.35 6121.01 1216.78 7786.24 3658.47 6104.94 230.69 281.08 1004.15 875000 3847.69 6171.01 1216.99 7833.55 367077 615052 227.56 28038 1005.34 8800.00 3847.16 8221.01 1217.20 7881.52 3682.96 6198.80 224.41 279.66 1006.57 8850.00 3845.76 8270.09 1217.41 7934.45 3696.45 8247.87 221.06 278.82 1007.75 8900.00 3843.68 6320.94 1217.63 7988.20 3710.20 8297.67 217.98 277.91 1008.78 8950.00 3841.57 6370.90 1217.84 8025.89 372047 6335.72 215.56 277.22 1010.18 9000.00 3839.45 8420.85 1218.05 8065.59 373013 8374.34 212.88 278.57 1012.17 9050.00 3837.34 847081 121826 8117.15 3741.87 8424.46 209.30 275.78 1014.55 9100.00 3835.22 6520.76 121848 8175.17 3753.67 8481.13 205.84 27495 1016.69 9122 57 3834 27 6543.31 1218.57 8204.61 3759.28 8509.98 204 36 27458 1017.52 • n-.n.-...rsc....nnnn 4 Inc A Miknit,=h tn\Clliletnle pninl\(lln7_nAknin7_ndV11n7_nd 1P41 1n/1/9f11f1 Q•°19 AM Pana 1d of 1R Trajectory:0107-04(P4)Vs.OP0407PB1 Reference Cylinder North MD Reference TVD Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW Azim Ct-Ct Distance (8) (8) (e) (8) (6) (8) (6) (8) (°) (e) 9150.00 3833.24 8570.72 1218.89 824075 376559 654554 202 89 274.11 101836 9200.00 3832.04 6620.71 1218.90 8294 72 3773 91 6598.84 201 28 273.54 1019 52 925000 383171 667070 121912 8338.68 378011 6642.34 19987 27314 102004 930000 383211 672070 121933 8385.63 378632 6688.84 19816 27279 1022 69 9350.00 383258 6770.70 121954 843742 379327 674013 19631 27243 1024 45 9400.00 3833.06 6820.70 1219.75 8487 74 3800 27 678993 194 59 272.06 102615 945000 3833.54 6870.69 121997 8536.67 3807 32 6838.32 192.89 27169 1027.92 9500.00 3834.02 6920.69 1220.18 8584.00 3814 34 8885.10 191.21 271.32 1029.77 9550.00 3834.50 6970.69 1220.36 863014 382111 6930.70 189.43 270.96 103183 9600.00 3834.97 7020.69 1220.60 868795 382913 6987.91 18718 270.55 1033.96 965000 383545 7070.88 1220.82 8756.24 3837.21 7055.70 185.77 270.14 1035 15 970000 3835.93 7120.68 1221.03 880607 3842 85 7105.21 185.07 269.85 1036.10 9742 79 3836.34 7163.47 1221.21 8852.41 3847.95 7151.26 18446 268.59 1036.89 9743.90 383635 7164.58 122122 885372 384809 7152.57 18445 269.59 1036.90 9750.00 3836.41 7170.68 1221.24 886093 384886 7159.73 18438 269.55 103700 980000 3836.92 722067 122145 892005 3854 86 7218.54 184.09 269.25 1037.52 985000 383744 7270.67 122167 896643 385874 726477 184.00 26906 1037.00 990000 383795 7320.87 122188 901215 3861 16 731042 18370 26866 1038.49 9950.00 383846 737067 1222.08 906061 386240 7358.86 18320 26801 103923 1000000 383897 7420.66 1222.31 9109.58 3862 65 7407.82 18263 28803 1040.03 1005000 383948 747066 122252 914711 386249 7445.34 18196 26896 1041.13 1010000 3840.00 752066 1222.73 918382 3862 55 7482.03 180.83 26888 1042.86 1015000 3840.64 7570.65 122295 922564 386285 7523.82 17903 26897 104520 1020000 3842.07 7620.83 122316 928194 386344 7580.07 176.69 26888 1047.47 1025000 384437 7870.58 122337 933792 3864 11 7638.01 174.71 26905 1049.42 1030000 3847.54 7720.47 1223.58 939359 3818145 7691.65 173.03 26919 1051.08 1035000 3851.03 7770.35 122378 9439.50 3864 51 7737.54 171.72 26936 1052.66 10400.00 3854.53 7820.23 122399 948353 3864.50 7781.55 170.23 26953 105452 10450.00 3858.02 7870.11 122420 952875 386447 7826.73 168.46 26971 1056.65 10500.00 3861.52 7919.98 122441 957459 3864 67 787253 166.49 26987 105888 1055000 3865.01 7969.86 122462 962619 386518 7924.07 16417 270.04 106144 1060000 3868.51 801974 1224.82 968222 386606 798005 161.91 270.20 1063.85 1065000 387200 806962 1225.03 972460 3866.93 8022.39 160.22 27032 1065.87 10700.00 3875.33 8119.50 1225.25 9765.05 3867.90 8062.78 158.25 270.47 106853 1075000 387785 8169.44 1225.49 980436 386896 8102.00 155.97 270.62 107168 10800.00 387949 821941 122579 984247 3870.03 8140.01 15336 270.75 1075.41 1085000 388074 826939 122610 988067 3871 13 8178.08 15032 270.74 1078.70 10900.00 3881.99 8319.38 122642 093784 3872.06 8235.15 145.66 270.77 108408 1095000 3883.23 8369.36 1226.73 9991.70 3871.67 8288.75 14164 270.86 1088.14 1100000 3884.48 8419.34 122705 10037.83 3870.71 8334.75 138.16 270.97 1082.26 11050.00 3885.73 8469.33 1227.37 10092.03 3889.09 8388.76 133.96 27112 109650 11100.00 3886.97 851931 1227.68 10168.32 3866.60 8464.86 129.32 271.35 1099.90 1115000 3888.22 8569.28 1228.00 10224.35 3865 71 8520.82 12672 271.46 1102.58 1120000 3889.47 861928 1228.31 10280.79 386654 8577.20 12438 271.48 110497 1125000 3890.66 8669.26 1228.62 1033793 386709 8634.31 122.38 271.45 1107.04 1130000 3891.56 8718.25 1228.83 10394.24 3866 79 8690.59 12078 271.49 1108.70 11350.00 3892.45 876925 1229.04 10450.04 386626 8746.37 118.48 271.57 1110.09 1140000 3893.35 8819.24 1229.25 1050717 386545 8803.49 118.80 27186 1111.12 1145000 389424 886923 1229.46 10540.00 386494 8836.31 11815 271.72 1112.19 11500.00 380513 8919.22 1229.68 10540.00 3864 94 8836.31 11815 271.72 111503 1155000 3896.03 8069.21 1229.89 1054000 386494 883631 118.15 271.72 1120.00 11600.00 3896.92 9010.20 123010 10540.00 3864 94 8836.31 11815 27172 112735 1165000 389782 906920 1230.31 10540.00 386494 883631 118.15 27172 1136.76 11700.00 389870 011819 123052 10540.00 386494 8836.31 118.15 271.75 1148.28 11750.00 389904 916818 123074 10540.00 386494 883631 11815 272.04 1161.82 11800.00 3898.51 921818 1230.95 10540.00 386494 883631 11815 272.38 1177.31 11850.00 3897.12 8268.16 1231 17 10540.00 3864 94 883631 118.15 272.67 1194.66 1190000 389542 031913 1231.38 10540.00 3864 94 883631 11815 27267 1213.81 11950.00 389371 936910 123180 10540.00 386494 8836.31 11815 27267 1234.69 12000.00 389201 0419.07 1231.81 1054000 386494 8836.31 11815 272.67 125722 12050.00 3890.30 9469.04 1232.03 10540.00 386494 883631 118.15 272.67 1281.30 12100.00 388860 9519.01 1232.24 10540.00 3864 84 8836.31 11815 272.87 130685 End of results r_.ii.__..cr-nnnn 4 ,.c n r,i..,.,..r,..-knru,.,o,,....nim/1.4111,7 nnrnim nn ionN 4414 ion.n nn,nen o..,.,,a.4.a • Field: Nikaitchuq Well: OP23-WW02 Structure: Oliklok Point Borehole: OP23-W W02 Slot: OP23 Trajectory: OP23-WW02 Client: ENI Type: Del Survey Structure MAS: 4.150(0) Coordinate System: NAD27 Alaska State Plane.Zone 04,US Feet North Reference: True Grid Convergence Angle: 0.12787579° Grid Scale Factor: 0.99990031 Magnetic Declination: 21.741° Magnetic Declination Date: April 20,2010 Magnetic Model: BGGM 2009 Reference Point: Northing asC le bn Structure Unc.11sd) Slot Unc.ltsd) 6036483.060(WS) 516576.840(ftUS) 53.200(ft)MSL 0.000(9) 0.000(t) Trajectory Error Model:ISCWSAO 3-D95.000%Confidence 2.7955 sigma Surveying Prog: 7AD From lftt MD To ilkOU!Jig Survey Tool Tyne Hole Diameter fin) Borehole I Survey 0.000 41.000 Act-Stns SLB_MWD*GMAG-Depth Only-No Global 16.000 OP23-WW02/OP23-WW02 41.000 4607.000 Act-Stns SLB_MWD*GMAG-No Global 16000 OP23-WW02/OP23-WW02 4607.000 9120.000 Act-Stns SLB_MWD*GMAG-No Global 12.250 OP23-WW02/OP23-WW02 9120.000 12323.000 Act-Stns SLB MWD*GMAG-No Global 8.500 OP23-WW02/OP23-WW02 Reference Cylinder North MD Reference ND Reference NS Reference EW Offset MD Offset ND Offset NS Offset EW Azim Cl-Ct Distance (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) All local minima indicated. Results filtered.Depth 5000.00 ft<=MD<=12232.00 ft Results filtered:Cl-Ct separation<=1320.00 ft Results highlighted:Ct-Ct separation<=1320.00 ft 5050.00 3657.27 2479.92 1199.01 5052.97 4045 50 2282.88 -12 88 253.06 1287.73 5100.00 3660 79 2529.78 1200.05 5104.00 4076.48 2323.27 -9.33 251.19 1295.39 5150.00 3663.43 2579.71 1200.51 5163.08 4112.56 2369.81 -4.47 249.57 1302.98 5200.00 3666.05 2629.64 1200.94 5218.81 4146.83 2413 38 1.14 248.17 1310.51 5250.00 3668.67 2679 57 1201 38 5256 36 4169 98 2442 70 5.09 247.23 1318.54 End of results • Drilling Office 2009.1.745.0 Nikaitchuq\Oliktok Point\0107-04\0107-04\0107-04(P4) 10/1/2010 9:33 AM Page 16 of 16 0 0 O O O co M �.. O . O N • I o . O ti qt r � Ce IL ° V Q O s 0 "Cr 1 3 o r� o T co O N O .4170 Q V Q. U E o X o O c O w N. o LC DC)CD L Co 411 CrQ Q O a o W O o O O O O o O O O O o O 0 C:) 0 0 O 0 0 00 OVERSIZED DOCUMENT INSERT This filecontains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST A7 T WELL NAME / �' / / L/ kI�l `-'7' 0 / PTD# 7)---/0 / Development Service Exploratory Stratigraphic Test P P Non-C nventional Well FIELD:/ / / � r' POOL: / I / l r7 (lit, Z/ ,//C Circle Appropriate Letter I 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 . /0_75/.-/0/ SPACING The permit is approved subject to full compl'-- • ' 20 AAC 04..irt-<-4-z"^- EXCEPTION 25.055. Approval to perforate and produce /inject is yontingent h,c0_, __ /v/0"[ L2E� /� ,/ upon issuance of a conservation order L _ 1 spacing — it)_ /�,,i / ,.,C,/ exception. assumes the y ;/ liability of any protest to the spacing exception that may occur. r'-144't- )' /—s -' -ibPR � Y 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 l �/ / program. /-Ec%/ Ir ip ` ,e / /e)il e')- t- ` l�w,A,( 7� e r �/ ce �� }//,-/e K fa 7 _ Ko Com' Rev: 1/11/2008 �> /i t <t_ [ E��/1 741/ca._ � �C/`61 F�l•1---, )}'l&,Y 10 a t 1-2 e C' -l��L._._, C Y'-7-(_ 1-76-')- . / �,1� i (/) D cD O D 7 CO D a TI 0 0 r V co T •0 0 to co C) 0 0 Cn a 5 013 -• 4k o co.O 0 0 0 coO 0) O 3 ' .s OA y C71 y A 0) 7 C7 • 7 C) N a IJ rp. 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N co 7' O N co.CD C 3 N A X 7OD A CD 7 w ° 13 °A0 CO CO if) m N 3 °o0 O CO CO n N (O �1 O N 7 0 -° N 7 n O N CO °n O 33 (O •0 N co CD c 7 N w co a cn 0 O O a 3 - o v < CI) Q c P. N CD 'ao A 'm1 n n 0 0 3 I O SA -00) O- •0 o p. CD co N O CA C - o rn E 0 o co c N 0 A o CD N Cn O N 0 CD 7 N O N O. 0 Well History File P EN ' 1X Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. conn C�n�i� Ptir©IIim FINAL WELL REPORT MUDLOGGING DATA NIKAITCHUQ 0107-04 OLIKTOK POINT, ALASKA I #0000., a --"' CANRIG Approved by: Andrew Buchanan Compiled by: John Lundy Tollef Winslow Emil Opitz Distribution: February 3, 2011 Date: January 13, 2011 /tS DIdN V J Z CIO elea lewd (ani pue aw) 601 soiweuAa 6u1IIua ,006/„Z (ant pue an) 601 ogwo0 awn ,006/„Z (ani pue an) 601 oge�l sap ,006/„Z (ant pue an) 601 uollewa0d ,006/„Z saJnsolou3 tit spodeld 6ulwon Aga 6'9 tti SThOd2 l A1IVa 9 Et aloH uollonpad :pJooa2j pnW 9'9 Z17 aloes alelpewJelul pue aoe}.ins VS 6b pJ00a1l18 £*9 L£ elea Aeiung Z'S Z£ iewwng A11n113V AIlea 6'9 Z£ Viva ONI111 1a 9 6E spoinen andlellluen0 Z'P 6£ uogenlen3 lue!peJ0 9J11ssaJd 9J0d Vt 6£ Vida H1JN3b1S NOIiV i JOd aNV 3 If1SS32id b 0£ yoledsia eldweS pue weJ6wd 6ulldweS 9'£ 6Z tiewwnS ses Jed1M/dul S'£ 6Z i(.iewwns se0 uo1loauuo0 b'£ 06 AydeJ6geJls/suogduosea ol601041!1 E'£ 6 PO-L0-10 uogoaS leaale1/u0gonpaid Z'Z'E g uolloaS elelpew.ielul pue eoeJns 6'Z'E g sdo1 uollewJOd Z'£ L sled IIaM les;40 pue le6Jel 6'£ L VIVA 1V01001030 g slsdouAS 118M £'Z S sled 810H Z'Z g tiewwnS IIaM 6'Z S S1IV130 113M Z 1, M9JO Z'6 £ IcJewwnS luawdlnb3 6' £ M32J0 PUB 1N3Wd1f103 ONIOOO1afL 6 S1N31NOO AO 318)11 P0-L010 Vit eni Eni Petroleum 0107-04 1 MUDLOGGING EQUIPMENT and CREW 1.1 Equipment Summary Parameter Equipment Type/Position Downtime (hours) Comments Casing Pressure Cable to 1502 transducer for BOP 0 tests only. Computer—Drill Floor Monitor Azonics 0 Computer—Pit Monitor Azonics 0 Computer for Company Man, RigWatch Remote(HP Compaq) 0 camp Computer for Company Man/ RigWatch Remote(HP Compaq) 0 ToolPusher, office (wireless) Computer for Mud Engineer RigWatch Remote(HP Compaq) 0 Computer for ToolPusher RigWatch Remote(HP Compaq) 0 Computers for Mudloggers (3) Data editing, RigWatch Master, and 0 RigWatch Remote(all HP Compaq) QGM Agitator g (Mounted in possum belly) Clean and service Ditch as Flame Ionization Detector(FID) 2 trap Total Gas and Chromatography. Hook Load/Weight on bit Drilling Line Sensor on Rig Floor 0 Mud Flow In Derived from Strokes/Minute and 0 Pump Output Mud Flow Out Flow line Sensor 0 Pit Volumes, Pit Gain/Loss 10 radar pit sensors 0 Pump Pressure Standpipe Transducer 0 Pump stroke counters(3) 2 proximity sensors 0 Rate of penetration Draw Works Encoder 0 RPM PLC feed 0 Torque PLC feed 0 Wits In (LWD Data) LWD Computer to RigWatch 0 Master Computer 3 PiIt eni Eni Petroleum 0107-04 1.2 Crew Unit Number: ML059 Unit Type: Arctic/Steel Mudloggers Years of Days at Sample Days at Technician Days at Experience 0107-04 Catchers 0107-04 0107-04 John Lundy 18 20 Debra Bomar 18 Allan Williams 2 Tollef Winslow 3 25 Dean Kekaualua 18 Howard Lamp 2 Larry Resch 12 9 Emil Opitz 3 4 4 CANRIG Enlisi i Gni Petroleum 0107-04 2 WELL DETAILS 2.1 Well Summary Well: Nikaitchuq 0107-04 API Index#: 50-029-23435-00-00 Field: Nikaitchuq Surface Co-Ordinates: 3201.2' FSL 1568.9' FEL S5 T13N R9E UM Borough: North Slope AFE#: 4661 State: Alaska Primary Targets: OA Sand of the Schrader Bluff Rig Name/Type: NAD 245E/Arctic/Triple Primary Target Depth: 12401' MD: -3837.7' TVDSS Spud Date: December 29, 2010 TD Depth: 12325' MD: -3871.3' TVDSS TD Date: January 13, 2011 Ground Elevation: 12' MSL Days Drilling: 16 RT Elevation: 53.2' MSL Classification: Producer TD Formation: Schrader Bluff OA Sand 2.2 Hole Data Maximum Depth Mud Shoe Depth FIT Hole TD Wight Dev. Casing/ (ppg) Section MD TVD Formation ( Inc) Liner MD TVD (ft) (ft) (PPM (ft) (ft) Conductor 160 160 Recent n/a 0 20" 160 160' n/a 16" Surface 2330 2204 Ugnu 9.2 32.2 13 3/8" 2315 _ 2190.7 12.0 12-1/4" 5618 3681.6 OA Sand 9.1 83.16 9 5/8" 5600.6 _ 3681.6 13.1 Schrader 8-1/2" 12325 3924.6 Bluff, OA 9.4 88.81 5 1/2" 12313 3924.4 n/a Sand 5 CANRIG Beni Eni Petroleum 0107-04 2.3 Well Synopsis The 0107-04 well was spudded on the 29th of December 2010,entering a pre-set conductor pipe at a depth of 160'. New 16"hole was drilled to a depth of 2330'where 13-3/8",681b/ft-L80 surface casing was set at 2315' /2191.8/-2138.6'TVDSS. The float equipment and shoe were drilled out and new hole was drilled to 2350".A Formation Integrity Test was performed to 12.0 ppg. The intermediate section was drilled with a hole diameter of 12-1/4"to a depth of 5619'MD.The hole was back-reamed to the existing casing shoe and circulated clean. After laying down the drilling assembly, 9 5/8": 47lb/foot casing was floated in dry and set at 5600.6' MD/ 3678.7' TVD/-3625.5' TVDSS. An 8.5" bit and drilling assembly were picked up and run in to the surface casing shoe. Casing shoe was drilled out with additional new hole to 5638'where a Formation Integrity Test was performed yielding 13.1 PPG/MWE. Normal drilling was resumed using an 8 1/2" PDC bit and the borehole extended to TD at 12325.0' MD/3924.6' TVD/-3871.3' TVDSS. Production liner was set at 12313'MD/3924.4'TVD/-3871.2'TVDSS. 6 CANRIG VIC enr Eni Petroleum 0107-04 3 GEOLOGICAL DATA 3.1 Target and Offset Well Data Reference Wells OP03- 0107-04 Prognosis Surface PO5PB1 OP12-01 OPI2 PB01 OP26 DSP02 (WP8) TVDSS TVDSS TVDSS TVDSS TVDSS MD c1/-4 -6c7 R -6,;(1 1 -657.7 160.0 SV-3 -910 1 -907 R -911.5 710.1 SV-7 -1162 0 -1169 0 -1163 7 -1,171.6 966.2 SV-1 -1671 1 -1641 5 -1647 0 -164431 -1,670.4 1,234.4 Permafrost RASP -1772 1 -1774 3 -1,725.0 1,769.1 Ilunu Ton(11G41 -1924 2 -1971 9 -1931 5 -1957 7 -1,998.2 1,829.5 13 3/2"Sup -2,120.0 2,276.0 11G-2 Coal Red Marker -2512 7 -2437 7 -7477 0 -7478 7 -2,471.9 2,704.6 I.Komi -3140 3 -3096 9 -1060 0 -3127 5 -3,121.5 3,647.1 Schrader Muff -3387 3 -1107 5 -3341 9 -33740 -3,324.7 4,046.3 N Sernienre Tnn -3349 7 -3346 7 -3,372.4 4,157.5_ N Sand Tnn -3470 7 -3390 5 -3326 4 -33117 6 -3,412.3 4,259.0 N Sand Bottom -3521 5 -3432 8 -3474 4 -3473 3 -3,463.3 4,405.6 N SPnlienrP Race -3477 R -1458 5 -3,508.9 4,561.5 OA Sand Tnn -3554 5 -3518 7 -1516 4 -3,597.3 5,066.6 9 5/R"ICP -3,618.7 5,432.0 ()A7 -3,627.8 6,600.0 (1A3 -3,636.5 6,850.0 Fault 1 -3,724.8 7,949.2 Total Denth -3,837.7 12,401.0 7 CANRIG IA Beni Eni Petroleum 0107-04 3.2 Formation Tops: 3.2.1 Surface and Intermediate Section Zone or Horizon Depth (ft) Current Prognosed Depth (ft) MD TVD TVDSS MD TVD TVDSS 20"Conductor Shoe 160.0 160.0 -106.7 160.0 160.0 -106.7 SV-4 710.6 710.0 -656.7 710.1 711.0 -657.7 SV-3 971.5 967.0 -913.7 966.2 964.8 -911.5 SV-2 1,239.0 1,224.0 -1,170.6 1,234.4 1,224.9 -1,171.6 SV-1 1,778.5 1,721.7 -1,668.4 1,769.1 1,723.7 -1,670.4 Permafrost Base 1,846.0 1,783.1 -1,729.7 1,829.5 1,778.3 -1,725.0 Ugnu Top (UG4) 2,150.0 2,053.1 -1,999.8 2,132.8 2,051.5 -1,998.2 13 3/8"Casing Shoe 2,315.0 2,192.1 -2,138.7 2,276.0 2,173.3 -2,120.0 TD 16" Borehole 2,330.0 2,204.4 -2,151.1 2,276.0 2,173.3 -2,120.0 UG-2 Coal Bed Marker 2,741.0 2,537.7 -2,484.4 2,704.6 2,525.2 -2,471.9 Lower Ugnu 3,591.5 3,136.6 -3,083.3 3,647.1 3,174.8 -3,121.5 Schrader Bluff 4,004.0 3,360.6 -3,307.2 4,046.3 3,378.0 -3,324.7 N Sequence Top 4,109.0 3,408.5 -3,355.2 4,157.5 3,425.7 -3,372.4 N Sand Top 4,222.0 3,444.8 -3,391.4 4,259.0 3,465.6 -3,412.3 N Sand Bottom 4,397.0 3,497.8 -3,444.5 4,405.6 3,516.6 -3,463.3 N Sequence Base 4,565.0 3,547.1 -3,493.8 4,561.5 3,562.2 -3,508.9 OA Sand Top 5,531.0 3,671.1 -3,617.8 5,066.6 3,650.6 -3,597.3 9 5/8"Casing Shoe 5,600.0 3,678.9 -3,625.6 5,432.0 3,672.0 -3,618.7 TD 12 1/4" Borehole 5,618.0 3,680.5 -3,627.2 5,432.0 3,672.0 -3,618.7 8 CANRIG iik eni Ertl (Petroleum 0107-04 3.2.2 Production/Lateral Section 01-07-04 Zone or Horizon Depth (ft) Prognosed Depth (ft) MD TVD TVDSS MD TVD TVDSS OA sbl2 6,243.0 3,701.7 -3,648.4 n/a n/a n/a OA sbl2 6,490.0 3,706.9 -3,653.6 n/a n/a n/a OA sb12 6,760.0 3,721.1 -3,667.8 6,600.0 3,681.1 -3,627.8 OA sbl3 7,014.0 3,743.9 -3,690.6 6,850.0 3,689.8 -3,636.5 OA sbl4 7,565.0 3,781.3 -3,728.0 n/a n/a n/a OA sb14 7,721.0 3,789.7 -3,736.4 n/a n/a n/a Fault#1 7,788.0 3,792.7 -3,739.4 7,949.2 3,778.1 -3,724.8 OA Sand Top 8,260.0 3,838.6 -3,785.3 n/a n/a n/a OA sbl2 8,440.0 3,853.7 -3,800.4 n/a n/a n/a OA sbl3 8,870.0 3,860.7 -3,807.4 n/a n/a n/a OA sbl3 10,074.0 3,858.8 -3,805.5 n/a n/a n/a OA sbl3 10,141.0 3,860.0 -3,806.7 n/a n/a n/a OA sbl4 10,684.0 3,888.2 -3,834.9 n/a n/a n/a OA Sand Bottom 10,939.0 3,900.5 -3,847.2 n/a n/a n/a OA Sand Bottom 11,071.0 _3,903.5 -3,850.2 n/a n/a n/a OA sbl4 11,222.0 3,900.7 -3,847.4 n/a n/a n/a TD 8 1/2" Borehole 12,325.0 3,924.6 -3,871.3 12,401.0 3,891.0 -3,837.7 9 CANRIG eni Enl Petroleum 0107-04 3.3 Lithologic Descriptions/Stratigraphy The Permafrost section of the 0107-04 consists of moderate beds of sand, conglomerate and claystone with thinner clay interbeds,particularly near the surface.This material is almost entirely included in the permafrost section and contained no oil shows: some minor methane hydrates were encountered. PERMAFROST AND RECENT/QUATERNARY DEPOSITS SURFACE TO 2076.5'MD/-1965.8'TVDSS This interval extends from surface down to the top of the Ugnu at 2076.5' MD and is comprised of a thick sequence of sands, conglomerates and claystones with occasional thin to massive siltstone and poorly developed coals and carbonaceous remains. Sand dominates the upper part of the section with claystone becoming predominant with depth Discrete fragments of sandstone were rarely observed, samples were typified by loose sand and conglomeritic pebble fragments with irregular globular clay masses. Clay masses commonly contained trace to abundant sand mechanically worked into the clay by drilling, circulation and shaker action and had a surface coating of imbedded loose sand. Formation consists of moderate to thick beds with locally abundant thinner interbeds. No unforeseen problems were encountered drilling this section, and no marketable hydrocarbons were found. Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 325 20 160 310 0 46 PEAKS Depth TG Cl C2 C3 C4I C4N C5I C5N 1293 136 24070 1463 308 60088 1556 306 63673 1583 310 67617 1778 186 30551 2096 83 16646 1293 136 24070 1463 308 60088 1556 306 63673 1583 310 67617 1778 186 30551 2096 83 16646 2485 79 15073 2731 84 16325 2880 84 16727 2987 67 13108 3353 104 20433 3730 25 5258 TRACE 3750 165 31407 3 3835 63 10882 30 4014 37 6728 17 SV-4 710.6' MD/-656.7'TVDSS SV-3 971.3' MD/-913.7' TVDSS eni Eni Petroleum 0107-04 Sand/sandstone Conglomerate(1000-1090)=medium light to light gray:slight olive secondary hue:soft to dis-aggregated loose sand with occasional loosely aggregated pyrite cemented sandstone:medium upper to medium lower,coarse,very coarse and granule with scattered 3 to 5 mm pebble and pebble fragments:finer material is predominantly slightly frosted clear colorless to translucent white quartz:very abundant dark gray to black chert dominate the coarser material: occasional translucent white quartzite pebble/fragments:trace to common very fine grain crystalline pyrite overgrowth on coarser grains and as cementing agent in loosely aggregated sandstone fragments: trace heavily pyritic black lithics: finer grain material is angular to sub rounded with trace moderately rounded grains: coarser grains and pebbles are slightly to moderately well rounded:all appear slightly frosted: predominantly matrix supported in soft light gray clay: local grain support: interbedded within to moderate beds of light gray clay: no oil indicators:trace calcareous. Clay/Claystone(1090-1180) = light to very light gray with a slight olive secondary hue: soft: silky/clayey to slightly gritty luster: smooth clayey to slightly gritty texture: recovered as irregular rounded masses with adherent sand and re-worked pebbles: grades to and interbedded with associated sand/conglomerate:very slightly calcareous. SV-2 1239.0' MD/-1170.6'TVDSS Sand/Sandstone Conglomerate/Conglomerate (1180-1270) = medium light to light gray dis-aggregated loose grains: poorly sorted: predominantly medium lower to medium upper and coarse grain: common to abundant very coarse and granule:common to abundant 3 to 8 mm pebble and larger pebble fragments:sub- angular to sub-rounded and angular in the finer material:coarser sand tends to be more angular but pebbles are moderately to poorly rounded:trace pyrite overgrowth continues:predominantly translucent white to clear frosted quartz: common to abundant light to medium gray lithics: abundant dark gray to black, gray-brown, light and medium gray and mottled light gray with small black spheroidal inclusions,particularly in the granule and pebble size range:trace olive,and brown grains:trace ping lithics:trace poorly decomposed wood: clay matrix supported in part: interbedded with thin to moderate beds of sandy to clean clay/claystone. Sand/Sandstone ( 1270-1390) = light to medium light gray: dis-aggregated or unconsolidated sand: moderately sorted: medium lower to fine upper and medium upper grain:scattered larger grain material'sub- angular to angular: trace sub-spheroidal grains: trans- lucent white to clear quartz predominate: trace to common dark mafic mineral/lithics:trace dark gray to brownish gray chert:trace brown and olive grains:trace plagioclase feldspar and pyrite: appears to be clay matrix supported in the upper part of the zone becoming grain supported with depth: occasional small claystone fragments. Sand/Sandstone Conglomerate/Conglomerate(1390-1510)=light to medium light gray with a slight olive secondary hue: dis- aggregated loose sand with locally dominant clay matrix fragments: poorly sorted: predominantly medium lower to fine upper in the smaller grain material with locally variable amounts of medium lower to granule and scattered small pebbles: angular to sub-angular in the finer material, sub rounded to moderately rounded in the coarser fraction: pebbles are moderately to slightly rounded:finer sand is predominantly translucent white to clear frosted quartz: common to abundant light to medium gray lithics: abundant dark gray to black, gray-brown, light and medium gray and light blue-gray lithics:trace rose sand and small pyrite masses: interbedded with thin to moderate beds of slightly to very sandy claystone: material appears at least partly clay matrix supported. Sand (1510 - 1570) = medium dark gray to dark gray with salt and pepper appearance and olive gray sub hues: lower fine to upper very fine grading to upper fine to lower fine:spherical to sub discoidal:angular to sub angular: moderately well to well sorted: unconsolidated sand: grain supported: texturally immature: compositionally immature: translucent and milky white quartz: gray and reddish brown lithics: porosity and permeability visually good: no oil indicators. Sand(1570-1660)=medium dark gray to dark gray overall salt and pepper appearance with olive gray sub hues: upper fine to upper very fine grained:sub angular to sub rounded:spherical to sub discoidal:moderately well to well sorted: unconsolidated sand: grain supported: texturally immature: compositionally immature: translucent and milky white quartz: gray and reddish brown lithics: pyrite: porosity and permeability visually good: no oil indicators. Sand(1660-1720)=medium dark gray to dark gray,salt and peppered,olive gray sub hues:bimodal, upper very fine to lower fine, upper medium to lower medium, some pebbles: spherical to sub discoidal: angular to 11 CANRIG eni Eni Petroleum 0107-04 sub rounded: unconsolidated sand: grain supported: texturally immature: compositionally immature: translucent and milky white quartz:pale yellowish orange lithics:black and gray lithics:grain encrusted pyrite: gray pebbles: porosity and permeability visually good: no oil. SV-1 1778.5' MD/-1668.4' TVDSS Sand(1720-1810)=medium dark gray to dark gray,salt and pepper appearance,olive gray sub hues: upper very fine to lower fine grained:spherical to sub discoidal:angular to sub rounded: unconsolidated sand:grain supported: immature compositionally: immature texturally:translucent and milky white quartz: pale yellowish orange lithics, black and grayish black lithics, pyrite, light green lithics: light gray clay, cohesive, clumpy, stiff tenacity, earthy luster, clayey texture: porosity and permeability visually good: no oil. PERMAFROST BASE 1846.0' MD/-1729.7' TVDSS Sand(1810-1900)=medium dark gray to dark gray,salt and pepper appearance,slight olive green sub hue: upper very fine to lower very fine grained: spherical to sub discoidal: sub angular to sub rounded: unconsolidated sand: grain supported:texturally immature: compositionally immature:translucent and milky white quartz with black carbonaceous material, green lithics and pale, yellowish orange lithics: porosity and permeability visually good: no oil. Clay (1900 - 1960) = medium dark gray to medium dark gray with dark greenish gray under tones: soft: cohesive, adhesive and pliable: lumpy to clumpy consistency: flexible to elastic tenacity: earthy fracture: massive cuttings habit:dull to earthy luster:clayey to silty texture: no discernable structure:sand reworked in clay: no oil indicators. Clay(1960-2020)=medium gray to medium light gray with olive gray sub hues:soft:cohesive,adhesive and pliable:clumpy to lumpy consistency:tenacity flexible to elastic:earthy fracture:massive cuttings habit:dull to earthy luster: clayey to silty texture: no discernable structure: sand reworked in clay: no oil indicators. Clay(2020-2080)=medium gray to medium light gray with olive gray to dark greenish gray sub tones:soft: cohesive, adhesive, pliable clay properties: lumpy to clumpy consistency: stiff to elastic tenacity: earthy fracture:massive cuttings habit:dull to earthy luster:smooth to clayey to silty texture:indeterminate structure: translucent and milky white sand grains, very fine grained, also present: no oil indicators. Carbonaceous Siltstone (2080 - 2110) = black to grayish black with reddish brown streaks: friable to moderately hard: splintery fracture:tabular to wedge-like cuttings habit: greasy to resinous luster: laminae or massive structure. UGNU TOP(UG4)2150.0' MD/-1999.8'TVDSS Sand(2110-2170)=medium dark gray to medium gray with dark greenish gray sub hues:lower fine to upper grained:spherical to sub discoidal:angular to sub angular:moderately well sorted: unconsolidated sand:grain supported:texturally immature:compositionally immature:translucent and milky white quartz with black and amber lithics, some chert: clays visible towards the end of the interval: no oil indicators. Sand/Sandstone(2170-2300) = medium to medium dark gray: samples collected as loose dis-aggregated sand with scattered to common loosely indurated sandstone fragments: well to moderately well sorted:fine upper to fine lower and very fine upper grain in the upper part of the zone:scattered to abundant medium and coarse lowed at the base: angular to sub-angular: trace sub spheroidal: about evenly divided between translucent white to clear colorless quartz and medium light to medium gray,dark gray and black lithics:trace to common pyritic black lithics:trace pale blue mineral grains and scattered mottled yellow/black and orange- red jasper: primarily grain supported: trace remnant silica cement overgrowth frosting: some locally matrix supported in clean light brownish gray clay: matrix support becomes dominant with depth:trace calcareous: interbedded with thin sandy to clean light brownish gray clay: no stain, odor, fluorescence or cut(nsofc) 13 3/8" CASING SHOE 2315.0' MD/-2138.7' TVDSS TD 16" BOREHOLE 2330.0' MD/-2151.1'TVDSS 12 CANRIG Tat eni Eni Petroleum 0107-04 Sand (2300 - 2410) = olive gray to light olive gray trending to medium gray: upper fine to lower fine with occasional upper very fine and lower medium grains:sub discoidal to sub prismoidal sphericity:angular to sub rounded: moderate to moderately well sorted: unconsolidated sand: cement missing: grain supported: texturally immature: compositionally immature: quartz sand with dark gray and black lithics: porosity and permeability visually good: no oil indicators. Sand (2410 -2470) = medium dark gray to medium gray with slight olive gray to light olive gray sub tones: lower medium to upper fine grained: spherical to sub discoidal: angular to sub rounded: moderate to moderately well sorted: unconsolidated sand:grain supported:texturally immature:compositionally immature: quartz sand with black and gray lithics, also amber lithics: porosity and permeability good: no oil. Siltstone(2470-2500)=light olive gray to olive gray:soft: poorly indurated: massive cuttings habit:waxy to greasy luster: silty to gritty texture: indeterminate structure: light to moderate brown carbonaceous material present: no oil indicators. Sand (2500-2560)=medium dark gray to medium gray grading to olive gray/light olive gray: lower fine to lower medium with occasional upper very fine and upper medium grains, few pebbles: spherical to sub discoidal:angular to sub angular,rounded pebbles:moderately sorted:unconsolidated sand:grain supported: texturally immature:immature compositionally:quartz sand with black and gray lithics,pyrite,and green lithics: siltstone increases as interval increases, porosity and permeability visually fair: no oil indicators. Sand(2560-2620)=medium gray to medium light gray: lower fine to lower medium with lower very coarse grains: spherical to sub discoidal: angular to sub rounded: moderately sorted: grain supported: texturally immature: immature compositionally: unconsolidated sand: quartz sand with chert, green, black and gray lithics: porosity/permeability visually fair: no oil indicators. Siltstone(2620-2650)=light olive gray to olive gray:soft:poorly indurated:flexible tenacity:massive cuttings habit: greasy to waxy luster: silty texture. Sand(2650-2710)=medium gray to medium light gray with olive gray sub hues:upper very fine to lower fine with coarse grains:spherical to sub discoidal:angular to sub angular:moderately sorted:unconsolidated sand: grain supported:texturally immature:compositionally immature:quartz sand with black,amber and light green lithics and pyrite: porosity and permeability visually fair: no oil. UG-2 COALBED MARKER 2741.0' MD/-2484.4'TVDSS Carbonaceous Shale(2710-2740)=grayish black to black:friable to easily friable:moderately to moderately poorly indurated: crumbly tenacity: irregular fracture: nodular to bladed cuttings habit: greasy to resinous luster: matte texture: laminae structure: alternate layers of grayish black and reddish brown carbonaceous material. Sand(2740-2860)=medium light gray to medium gray with light olive gray sub hues: upper very fine to lower medium grains: spherical to sub discoidal: sub angular to sub rounded: moderately sorted: unconsolidated sand with some sandstone: sandstone matrix siliceous: sandstone matrix supported: texturally immature: compositionally immature: quartz sand / sandstone with gray chert, black lithics, green lithics and pyrite: sandstone porosity/permeability visually tight, sand good: no oil indicators. Sand (2860 -2920) = medium gray to medium dark gray with olive gray sub tones: lower fine with a range from upper very fine to lower medium: spherical to sub discoidal: sub angular to sub rounded: moderately sorted: unconsolidated sand:grain supported:texturally immature:compositionally immature:quartz sand with light gray chert, green lithics and amber lithics: porosity and permeability visually good: no oil indicators. Sand(2920-2950)=medium dark gray to medium gray with olive gray sub hues: lower fine with upper very fine to lower medium grains: spherical to sub discoidal: sub angular to sub rounded: moderately sorted: unconsolidated sand:grain supported:texturally immature:compositionally immature:translucent quartz sand: porosity permeability visually good: no oil indicators. Clay(2950 -2980) = light gray to medium light gray with light olive gray sub tone: cohesive and adhesive: lumpy to clumpy:elastic to stiff to flexible tenacity:earthy fracture:massive cuttings habit:dull to earthy luster: clay texture: massive structure. 13 CANRIG 1 elni Eni Petroleum 0107-04 Carbonaceous Siltstone(2980-3010)=grayish black to black:friable to firm friable:moderately indurated: blocky fracture: tabular cuttings habit: waxy to greasy luster: laminae structure. Sand (3010 -3100) = medium gray to medium light gray with light olive gray sub tones: upper very fine to lower fine coarsening to lower to upper medium: spherical to sub prismoidal: angular to sub angular: moderately to moderately well sorted: unconsolidated sand: texturally immature: compositionally immature: translucent quartz grains with black chert and green lithics,occasional reddish brown carbonaceous material: porosity and permeability visually good: no oil indicators. Sand (3100 -3190) = medium light gray to medium gray with light olive gray sub hues: upper fine to lower medium grading to lower fine to upper fine: spherical to sub prismoidal: angular to sub angular: moderately well to moderately sorted: unconsolidated sand: texturally immature: compositionally immature: grains supported: translucent quart with light green lithics and gray black chert: porosity and permeability visually good: no oil indicators. Sand(3190-3250)=medium light gray to light gray with slight olive gray hue and an overall salt and pepper appearance: upper very fine with some lower fine and lower very fine: spherical to sub discoidal: angular to sub rounded: moderately to moderately well sorted: unconsolidated sand: grain supported: texturally immature: immature compositionally:translucent quartz grains with black and gray chert and slight amounts of reddish brown carbonaceous material: porosity and permeability visually good: no oil. Sand (3250 -3310) = medium dark gray trending to medium light gray as the interval increases: lower fine moving to upper very fine across the interval: spherical to sub discoidal: sub angular to sub rounded: unconsolidated sand: grain supported: translucent quartz with black and gray chert and light green lithics: porosity and permeability visually good: no oil indicators. Sand(3310-3370)=medium light gray to medium gray with slight olive gray tinge:spherical to sub discoidal: sub angular to sub rounded: unconsolidated sand: grain supported: texturally immature: compositionally immature: translucent quartz with black chert and pyrite: porosity and permeability visually good: no oil. Sand(3370-3430)=medium gray to medium light gray with light olive gray sub hue:upper very fine to lower fine: spherical to sub discoidal:sub angular to sub rounded: unconsolidated sand:grain supported:texturally immature: translucent quartz with black and gray chert and green lithics: porosity and permeability visually good: no oil. Sand /Silty Sandstone (3430 -3490) = medium light gray to medium gray: upper fine to upper very fine: spherical to sub discoidal:sub rounded to sub angular: moderately to moderately well sorted: unconsolidated sand: grain supported sand, matrix supported sandstone: texturally immature: compositionally immature: translucent quartz with light green lithics: porosity and permeability in sandstone poor: no oil. Sand / Silty Sandstone (3490 -3580) = light to medium light gray with a slight brownish secondary hue: samples collected as soft silty masses of dis-aggregated sand:fine upper to very fine upper grain:scattered medium grain:sub-angular to sub-spheroidal and angular:translucent white to clear colorless slightly frosted quartz sand: trace dark mafic mineral/lithics: trace pale blue-gray and brown to tan lithics: trace pyrite as individual masses and as very fine crystalline inclusions in black lithics: scattered rose jasper: material is primarily matrix supported in soft light brownish gray silt: occasional thin coal interbeds: trace oil sheen in 3550' sample with no notable stain odor or cut: trace calcareous. LOWER UGNU 3591.5' MD/-3083.3'TVDSS Sand /Silty Sandstone (3580 - 3700) = light to medium light gray with a slight brownish secondary hue: samples collected as relatively clean dis aggregated sand:friable:well to moderately well sorted:sub-angular to sub spheroidal and angular:fine upper to very fine upper grain: scattered medium and coarse: occasional granule size fragments:translucent white to clear colorless quartz predominate:trace dark gray to black mafic mineral:trace carbonaceous material:20%bright yellow fluorescence on sand at 3610':slight brown oil stain and scattered dark brown dead oil blebs with 100% dull gold fluorescence below 3610' cuts bright yellow- white: very slight brown residue ring fluorescence dull gold and cuts back to yellow white: no odor: trace calcareous. 14 CANRIG en1 Eni Petroleum 0107-04 Sand / Silty Sandstone (3700 -3820) = light to medium light gray with a slight brownish secondary hue: samples collected as relatively clean dis-aggregated sand with scattered clean siltstone and silty sandstone fragments: moderately well to moderately sorted:friable in part: sub-angular to angular and sub-spheroidal: fine upper to medium upper and fine lower grain: scattered coarse: translucent white to clear and smoky quartz predominate:trace dark gray to black mafic mineral/lithics:trace pale blue-gray,greenish gray, brown and tan lithic/mineral grains: scattered pyrite, and rose to orange jasper: slight oil stain on some grains: scattered dark brown dead oil blebs:free oil sheen on wash water below 3810': general subdued dull gold to brown fluorescence: immediate cut to medium bright yellow-white: slight brown residue ring with dull gold fluorescence cuts to yellow-white: trace oil odor. Sand/Silty sandstone(3820-3970)=light to medium light gray with a slight brownish secondary hue:dis- aggregated loose sand: moderately well to well sorted: medium lower to medium upper grain predominates: trace fine: scattered coarse: translucent white to smoky to clear colorless quartz predominates: common medium to light gray lithics:common dark gray to black lithic/mafic mineral grains:trace pale blue,brown and tan grains: trace pyrite and jasper: primarily grain supported: locally matrix supported in light brownish gray clay/silt: interbedded with thin sandy siltstone: 20 to 30%of sample surface is very weak to slight dull gold to brown fluorescence: cuts readily to slightly milky yellow-white: slight brownish residue with dull gold fluorescence cuts back to yellow-white: trace oil stain: occasional free oil blebs: no odor. Sand / Silty Sandstone (3970 -4090) = light to medium light gray with a slight brownish secondary hue: samples consist of irregular clayey/silty sand- stone masses, small clean silt fragments and loose dis- aggregated sand:moderately well to well sorted:medium lower to fine upper and medium upper grain:angular to sub-angular and sub-spheroidal:translucent white,smoky and clear colorless quartz:some slightly frosted: trace to abundant dark to medium gray and black mineral/lithics grains:trace pyrite:trace pale blue,brown and tan lithic/mineral grains:scattered pale rose and bright orange jasper:primarily matrix supported in light to very light clay/silt: 30 to 40%dull to very dull gold mineral fluorescence:cuts readily to medium bright yellow-white: very slight brownish residue ring with dull gold fluorescence no notable odor:trace visible oil stain:scattered free oil blebs: SCHRADER BLUFF 4004.0' MD/-3307.2'TVDSS Drill Rate(ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 328 16 161 1304 0 193 PEAKS Depth TG Cl C2 C3 C41 C4N C51 C5N 4057 56 14784 43 4255 424 22241 1002 616 616 1082 527 170 4274 238 46802 625 347 341 236 273 82 4520 263 11960 507 157 185 74 136 20 5080 250 42750 474 330 223 320 239 197 5370 191 29171 312 229 179 267 212 196 5551 1304 193330 3436 2848 1848 2624 1672 1435 5579 1171 172852 3110 2406 1749 2484 1508 1290 5596 1108 159927 2878 2411 1621 2303 1395 1194 The Schrader Bluff formation is the zone of interest in this well. At this location, it consists of two main sands, the"N"Sand and the"OA"Sand. The Schrader Bluff is an Upper Cretaceous turbidite deposit formed as sand lobes. In general, the"OA"Sands contain viscous crude with an API gravity between 16°and 19°. The"N" Sand was encountered at 4222' MD. N SEQUENCE TOP 4109.0' MD/-3355.2'TVDSS 15 CANRIG eni En' Petroleum 0107-04 Sandy Siltstone(4090-4170)=light to medium light brownish gray:soft:gritty to slightly clayey/silty texture: dull earthy to gritty luster: hydrophilic: easily lost in sample washing: moderately cohesive: slightly adhesive: contains moderate to abundant fine lower to very fine upper and medium lower sand grains:grades to similar silty sandstone in the same mineral logic suite:30%dull to very dull gold mineral fluorescence:cuts readily to medium bright yellow-white:very slight brownish residue ring with dull gold fluorescence no notable odor:trace visible oil stain: scattered free oil blebs: Sandy Siltstone(4170-4290)=light to medium light brownish gray:soft to dis-aggregated: moderately well sorted:fine upper to very fine upper and medium lower grain:scattered coarse and angular pebble fragments to 8mm:primarily translucent white to smoky and colorless clear quartz sand:common to abundant dark gray to black lithic/mineral grains:trace pale blue-gray, brown and tan lithics:trace to scattered pyrite:trace pale rose jasper and tan to off white shell fragments: primarily matrix supported in soft light gray-brown clay/silt: locally grain supported: 30 to 100% dull gold to brownish gold sample fluorescence cuts to slightly milky yellow-white:slight brownish residue fluoresces dull gold and cuts readily to yellow-white:trace brown oil stain on sand and in silty sandstone fragments: no odor: very slightly calcareous. N SAND TOP 4222.0' MD/-3391.4'TVDSS Sand/Siltstone(4290-4410)= light to medium light brownish gray:soft to dis-aggregated: moderately well sorted: fine upper to very fine upper and medium lower grain: scattered coarse grain: primarily translucent white to slightly smoky and colorless clear quartz:common to abundant dark gray to black lithic/mineral grains: trace pale blue-gray,brown and tan lithics:scattered pyrite:trace pale rose jasper:trace tan to off white shell fragments may be siderite:trace to common hard well indurated sandstone with good visible porosity below 4360': material appears primarily matrix supported: locally grain supported, silica cements: 100% dull to medium gold sample fluorescence cuts immediately to milky yellow-white:slight brownish residue fluoresces dull gold and cuts readily to milky yellow-white: trace oil stain on sand: scattered hard sandstone fragments heavily stained: no discernable odor: slightly to very slightly calcareous. N SAND BOTTOM 4397.0' MD/-3444.5' TVDSS Sand/Siltstone(4410-4540)= light to medium light brownish gray: soft to dis-aggregated loose sand and irregular silty/sandy masses:moderately well to well sorted:friable in part:very fine upper grain predominates: scattered medium lower:occasional granule size moderately rounded chert fragment:sub-rounded:common sub-angular and sub-spheroidal: translucent white to clear colorless quartz predominate: trace dark gray to black mafic mineral: no oil odor: no grain staining: 80%sand grains even yellow gold fluorescence, siltstone does not fluoresce: immediate bright bluish white blooming cut fluorescent: light amber cut:no visible residual cut: residual fluorescent cut bright bluish white: porosity and permeability visually good. N SEQUENCE BASE 4565.0' MD/-3493.8' TVDSS Sand / Siltstone (4540 -4630) = olive gray to light olive gray: upper very fine to lower very fine grained: spherical to sub discoidal:sub angular to sub rounded:moderately well sorted:unconsolidated sand:texturally immature:compositionally immature:translucent quartz with black mafics:very slight oil odor:very light brown stain: 80% patchy dull yellow gold fluorescence: instantaneous blooming bright bluish white fluorescent cut: slight light amber cut:bluish white residual fluorescent cut: no residual cut:free oil visible on shakers:porosity and permeability visually good. Sand / Siltstone (4630 -4720) = light olive gray to olive gray: lower very fine to upper very fine grained: spherical to sub discoidal: sub rounded to sub angular: moderately well to well sorted: unconsolidated sand: texturally immature: compositionally immature: translucent quartz with black and gray lithics, reddish brown carbonaceous material,and pyrite:very slight oil odor:slight light brown stain:sample fluorescence decreases from 80%to 20%patchy dull yellow across the interval:medium blooming to streaming bright bluish white cut: clear cut: no residual cut: faint white residual cut: porosity and permeability visually good. Sand/Siltstone(4720-4810) = olive gray to light olive gray: upper very fine to lower fine with occasional lower medium and upper fine grains: spherical to sub discoidal: sub angular to sub rounded: moderately to moderately well sorted: unconsolidated sand: texturally immature: compositionally immature: translucent quartz with black lithics and light gray chert: sand decreases as interval increases: no oil odor: very slight brown stain:very faint,30%,evenly distributed,dull yellow sample fluorescence:very slow streaming sample 16 CANRIG Yak anti Eni Petroleum 0107-04 cut, bright, bluish white: no visible cut: no residual cut: residual fluorescent cut yellow gold: porosity and permeability visually fair: free oil at shakers. Sand/Siltstone(4810-4900)=light gray to very light gray with olive gray sub hue: upper very fine to lower fine with occasional medium grained: spherical to sub discoidal: sub rounded to sub angular: moderately sorted: unconsolidated sand mixed with silt:matrix supported:texturally immature:compositionally immature: no oil odor: no oil stain: trace, patchy, dull yellow gold fluorescence: very faint streaming yellow cut fluorescence: no visible cut:no residual cut:slight yellow residual cut:oil at shakers:porosity and permeability visually poor. Siltstone (4900 -4960) = medium light gray to light gray with slight olive gray tinge: soft: poorly indurated: indeterminate fracture, siltstone dissolves in drilling fluid: massive cuttings habit: dull to earthy luster: silty to clayey texture: indeterminate structure: splotchy dull yellow sample fluorescence from sand: no oil odor: no cut: no residual cut:very faint blooming white cut: no stain: dull yellow residual fluorescence: oil on shakers. Siltstone(4960-5070)=medium light gray to light gray with light olive gray sub hue: soft: poorly indurated: indeterminate fracture: massive cuttings habit: dull to earthy luster: silty to clayey texture: indeterminate structure: no oil odor: no stain:splotchy dull yellow sample fluorescence from sand: no visible cut: no residual cut: very faint blooming white fluorescence cut. Sand(5070-5110)=medium light gray to medium gray with light olive gray sub hue: lower very fine to lower fine grained: spherical to sub discoidal: sub angular to sub rounded: well sorted: unconsolidated sand: translucent quartz with reddish brown carbonaceous material, pyrite and green lithics:moderate oil odor: light amber stain on 100%of grains: 100%even, gold yellow fluorescence: instantaneous blooming to streaming bluish white fluorescent cut:clear visible cut: no residual visible cut:dull yellow residual fluorescence:porosity and permeability visually fair. Sand/Siltstone(5140-5200)=medium gray to medium light gray with light olive gray sub hues: upper very fine to lower very fine grained: sub discoidal to spherical: sub rounded to sub angular: well sorted: unconsolidated sand:translucent quartz with black carbonaceous lithics and green lithics:very faint oil odor: light amber stain 30% of grains: light even dull yellow fluorescence: instantaneous streaming bright white fluorescent cut: no visual cut: no visual residual cut: light yellow residual fluorescence: free oil in samples. Sand/Siltstone(5200-5290)=medium light gray to medium gray with light olive gray sub tones: upper very fine to lower very fine with occasional medium grain: spherical to sub discoidal: sub rounded to sub angular: unconsolidated sand: translucent quartz with black lithics and reddish brown lithics: very faint oil odor: very faint oil stain on 20%of grains: 10% patchy dull yellow sample fluorescence: slow streaming dull yellow cut fluorescence: no visible cut: no visible residual cut: light yellow residual fluorescence: porosity and permeability visually fair. Sand(5290-5380)=olive gray to light olive gray:upper very fine to lower fine:spherical to sub discoidal:sub rounded to sub angular: unconsolidated sand: moderately well to well sorted: grain supported: texturally immature: compositionally immature: translucent quartz with black carbonaceous material and gray chert, glauconite:faint oil odor: 30%light amber oil grain stain:70%patchy bright yellow gold sample fluorescence: instantaneous blooming to streaming, bright bluish white fluorescent cut: faint light brown visual cut: no residual visual cut: medium straw residual fluorescence cut: free oil at shakers and in sample: porosity and permeability visually good. Sand (5380 -5470) = olive gray to light olive gray: upper very fine to lower very fine with some lower fine grains:spherical to sub discoidal:sub rounded to sub angular:moderately well to well sorted: unconsolidated sand: grain supported: texturally immature: compositionally immature: translucent quartz with black and reddish brown carbonaceous material and green lithics:very faint oil odor:trace grain stain:patchy bright gold yellow fluorescence: streaming bright white to bluish white fluorescent cut: very faint light brown visual cut: light dull yellow residual fluorescence: free oil in sample: porosity and permeability visually good. Sand(5470-5550)=olive gray: upper very fine to lower very fine:spherical to sub discoidal:sub rounded to sub angular: moderately well to well sorted: unconsolidated sand: texturally immature: compositionally immature:translucent quartz with black and green lithics:slight oil odor:trace oil stain:70%even bright yellow 17 CANRIG 1eni Esti Petroleum 0107-04 sample fluorescence: immediate blooming bright bluish white fluorescent cut: faint light brown visual cut: medium straw residual fluorescence: oil at shakers. OA SAND TOP 5531.0' MD/3617.8' TVDSS Sand(5550-5620)=olive gray to light olive gray: lower fine to upper very fine drifting to upper fine:spherical to sub discoidal: sub rounded to sub angular: well sorted: unconsolidated sand: compositionally immature: texturally immature:translucent quartz with black carbonaceous material and glauconite:moderately strong oil odor:50%dark brown oil grain stain: 100%even bright yellow sample fluorescence:instantaneous streaming blue white fluorescent cut: light brown visual cut: no visual residual cut: heavy blue white residual fluorescence: free oil on shakers and in sample. TD 9 5/8" BOREHOLE 5618.0' MD/-3627.2'TVDSS Sand(5618-5800)=light to very light gray with a slight greenish to brownish secondary hue:dis-aggregated loose sand friable: well sorted: fine upper to fine lower and very fine upper grain: scattered medium upper: sub-angular to sub-spheroidal and angular: translucent white to colorless clear quartz predominate: trace opaque white and slightly smoky quartz:trace dark gray to black mafic mineral/lithics:trace to scattered brown and pale blue gray lithic/mineral grains: trace small pyrite masses: trace tan to light brown shell fragments: apparently grain supported: trace cement remnant frosting on some grains: no visible matrix cemented fragments or matrix remnants: 100% dull greenish yellow sample fluorescence mottled with occasional masses which fluoresce dull yellow: pale slightly milky greenish yellow cut fluorescence: trace to no visible residue: slight medium blue-white residue fluorescence cuts to greenish yellow: occasional slight visible oil stain: no odor above oil base mud odor (OBMO): very calcareous - note: running 40 lbs./bbl. calcium carbonate. Sand(5800-5940)=light-medium light gray with a slight olive secondary hue loose dis-aggregated sand:no durable sandstone fragments noted: friable:well to moderately well sorted: fine upper to fine lower and very fine upper grain: scattered medium lower: sub-angular to sub-spheroidal to angular: translucent white to colorless clear and occasionally opaque white quartz predominate: trace dark gray to black mafic mineral grains are gene5r4ally sub-spheroidal to slightly rounded:trace brown:tan,pale blue and occasional greenish mineral/lithics:trace small pyrite masses and finely ground shell fragments: 100%dull green-yellow sample fluorescence mottled with occasional masses which fluoresce dull yellow: pale slightly milky greenish yellow cut fluorescence:trace to no visible residue: slight medium blue-white residue fluorescence cuts to greenish yellow:occasional slight visible oil stain: no oil odor above background:continue 40 lb./bbl.calcium carbonate. Sand(5940-6090)=light-medium light gray with a slight olive secondary hue loose dis-aggregated sand:no well indurated sandstone fragments noted:friable:well to moderately well sorted:fine upper to fine lower and very fine grain: scattered medium grain: primarily clear colorless and translucent white quartz:trace opaque white and smoky quartz: common to trace brown lithic/ mineral grains: trace black and dark gray mafic mineral/lithics:trace pale blue and light gray lithics and occasional tan to off white shell fragments trace small pyrite masses: no discern- able matrix: trace remnant cement frosting: 100% dull greenish yellow sample fluorescence mottled with dull yellow:cuts to pale greenish yellow:trace to no visible residue:slight blue-white residue fluorescence: occasional slight brownish oil stain: Drill Rate(ft/hr) Total Gas(units) Maximum Minimum Average Maximum Minimum Average 387 12 231 838 0 277 PEAKS Depth TG Cl C2 C3 C41 C4N C51 C5N 5761 784 133944 994 343 201 235 79 41 6041 839 186366 1464 569 293 348 168 84 6099 786 128018 1132 530 282 311 165 105 18 CANRIG IA eni Eni Petroleum 0107-04 6419 659 116525 808 313 194 237 164 110 6521 726 130006 1064 329 210 247 155 101 6616 732 131340 1032 317 195 217 168 109 6715 614 107361 808 232 160 203 131 79 6807 490 88088 652 202 144 169 113 68 6903 631 117298 865 240 183 375 160 101 6996 182 33358 205 75 58 59 57 37 7077 208 39215 204 61 51 60 31 29 7160 401 75986 1031 119 86 95 72 45 7553 448 80175 466 109 86 93 71 43 7688 326 63698 349 97 71 76 74 32 7783 322 62298 339 71 168 61 79 70 7988 134 25851 131 65 79 103 112 76 8156 68 13264 44 17 19 34 26 22 8308 389 76653 404 85 69 75 83 47 8448 515 100283 596 94 70 74 59 47 8542 560 116174 630 122 75 82 116 85 9039 501 96868 596 61 67 78 29 5 9230 602 113480 674 87 102 109 73 12 9497 715 139575 896 96 87 78 62 27 9990 706 137502 922 83 126 136 12 43 10181 623 122240 834 85 76 80 47 9 10277 652 136131 896 109 105 104 141 70 10662 484 100226 609 102 81 82 82 55 10931 317 57789 341 63 39 45 48 24 11122 239 58136 352 99 90 117 72 37 11245 341 77733 469 98 66 73 90 83 11719 563 111357 839 115 94 100 57 37 OA SBL2 6243.0' MD/-3648.4'TVDSS Sand(6090-6210)=light-medium light gray with a slight olive secondary hue loose dis-aggregated sand:no well indurated sandstone fragments: trace hard brown claystone fragments: friable: well to moderately well sorted: sub-angular to angular and sub-spheroidal:fine lower to fine upper and very fine predominate:trace medium lower and larger grains: translucent white to clear colorless quartz predominate: common smoky quartz: trace to abundant light gray lithics: trace dark gray to black mafic mineral/lithics: trace to scattered orange jasper:trace pale blue-gray, brown and tan lithics:occasional hard tabular medium brown laminated claystone fragments: appears entirely grain supported: 100% dull greenish yellow sample fluorescence:fair dull milky greenish yellow cut:trace to no residue fluoresces dull blue-white when fresh changes to dull gold after time: caco3 contamination continues. Siltstone/Sandy Siltstone ( 6190 -6310) = gray with a slight brownish secondary hue: hard to very firm: irregular to tabular fragments: dull earthy to gritty luster: silty to very sandy texture: slightly fissile in part: moderately cohesive: slightly adhesive: hydrophilic expands readily when water wet: very slightly to very sandy: grades to and interbedded with associated sandstone:slightly calcareous: 100%dull greenish yellow fluorescence: larger fragments fluoresce dull yellow when broken: murky dull blue-white cut fluorescence: slight brownish residual ring: residue fluoresces blue-white and cuts to milky yellow. Siltstone/Sandy Siltstone (6310 - 6400) = gray with a slight brownish secondary hue: hard to very firm: irregular to tabular fragments: dull earthy to gritty luster: silty to very sandy texture: slightly fissile in part: moderately cohesive: slightly adhesive: hydrophilic expands readily when water wet: very slightly to very sandy: grades to and interbedded with associated sandstone:slightly calcareous: 100%dull greenish yellow fluorescence: larger fragments fluoresce dull yellow when crushed: murky dull blue-white cut fluorescence: slight brownish residual ring: residue fluoresces blue-white and cuts to milky yellow. 19 CANRIG en! Eni Petroleum 0107-04 Siltstone (6400 - 6490) = light olive gray to olive gray: firm friable to moderately hard: moderately to moderately well indurated: irregular fracture:sub tabular to sub wedge like cuttings habit:dull to earthy luster: silty to gritty texture: massive structure: upper very fine to lower fine grained,translucent quartz sand present: slight oil odor: light brown grain staining on 30%of grains: 100%even, light green sample fluorescence with 30% patching bright green sample fluorescence: instantaneous blue white cut fluorescence trending to blue white streaming fluorescence: light amber cut: no residual cut: medium bright white residual fluorescence: porosity permeability visually fair. OA SBL2 6490.0' MD/-3653.6' TVDSS Siltstone/Sand (6490-6580) =olive gray to light olive: firm friable to moderately hard: moderately well to moderately indurated: irregular fracture: sub tabular cuttings habit: dull to earthy luster: silty to gritty texture: massive structure:sand is upper very fine to lower fine,spherical to sub discoidal,sub angular to sub rounded, well sorted, unconsolidated sand, translucent quartz: slight oil odor: slight grain stain: sample fluorescence 100%light even green:streaming,dull, blue white cut fluorescence:light amber white light cut: no residue cut: white to dull yellow residual fluorescence: porosity and permeability visually poor. Sand(6580-6670)=grayish black to dark gray with slight olive gray sub hues: upper very fine to lower very fine grained: spherical to sub discoidal: sub angular to sub rounded:well to very well sorted: unconsolidated sand: grain supported: compositionally sub mature: texturally immature: translucent quartz with black carbonaceous material and light green lithics: slight oil odor: very slight oil odor: slight amber grain stain: sample fluoresces even light green: cut fluorescence streaming bright blue white:white light cut light amber: no residual stain: residual fluorescence faint bluish white: porosity and permeability visually good: Sand(6670-6750)=grayish black to dark gray: upper very fine to lower very fine:sub discoidal to spherical: sub angular to sub rounded:well sorted: unconsolidated sand:grain supported:compositionally sub mature: texturally immature:translucent quartz with black carbonaceous material and shell fragments:slight oil odor: faint oil stain: even 100% bright green sample fluorescence with patchy very bright green: instantaneous streaming to blooming bluish white cut: light brown visible cut: no residual cut: bluish white residual fluorescence: porosity and permeability visually good. OA SBL2 6760.0' MD/-3667.8' TVDSS Siltstone (6750 - 6880) = medium dark gray to dark gray: firm friable to moderately hard: moderately to moderately well indurated: irregular fracture:sub tabular to sub wedge like cuttings habit:dull to earthy luster: silty to gritty texture: laminae structure, two to three grain thick sand beds interbedded in siltstone: slight to moderately slight oil odor: no grain stain: even light green sample fluorescence with more intense green to golden yellow patchy fluorescence:very slow streaming becoming blooming blue white sample cut:very light brown visible cut: no visible residual cut: patchy blue white residual fluorescence: porosity and permeability visually poor. Sand(6880-6920)=dark gray to medium dark gray with slight olive gray sub hues: upper very fine to lower very fine grained: spherical to sub discoidal: sub angular to sub rounded: well sorted: unconsolidated sand: sub mature compositionally:texturally immature:translucent quartz with glauconite and black carbonaceous material: slight oil odor: very faint oil stain: even light green with patchy golden yellow sample fluorescence: instantaneous streaming to blooming blue white fluorescence cut: light brown sample cut: no visible residual cut: even bright residual cut: porosity and permeability visually good. Siltstone(6920-7000)=dark gray to grayish black:firm friable to moderately hard:moderately to moderately well indurated: blocky fracture: sub tabular to sub nodular cuttings habit: dull to earthy luster: silty to gritty texture:massive structure:slight oil odor:brown stain when fracturing siltstone: 100%even bright yellow green fluorescence: instantaneous blooming bright bluish white sample fluorescence: dark brown visual cut: no visual residual cut: bright white residual fluorescence. Sand /Sandstone (7000 -7120) = dark gray to grayish black with olive gray sub hues: upper very fine to lower very fine: spherical to sub discoidal: sub angular to sub rounded: well sorted: unconsolidated sand, friable to firm friable sandstone:grains supported sandstone/sand:texturally immature:compositionally sub mature:translucent quartz with glauconite, dark black and brown carbonaceous material, and disseminated pyrite: moderate to moderately strong oil odor: light amber grain stain on sandstone and sand: even bright 20 CANRIG Eni Petroleum 0107-04 green sample fluorescence with patchy bright golden yellow fluorescence: instantaneous blooming bluish white fluorescence cut in sand and sandstone: dark brown visual cut: no visual residual cut: bright white residual fluorescence: porosity and permeability visually good. OA SBL3 7014.0' MD/-3690.6'TVDSS Sand (7120 -7240) = medium light gray to light gray with olive gray sub hue: lower fine to upper very fine grained: spherical to sub prismoidal: sub angular to sub rounded: well sorted: sand is unconsolidated: grain supported:texturally immature:compositionally sub mature:translucent quartz with black carbonaceous lithics and glauconite:slight oil odor:amber grain staining on some grains: 100%even light green fluorescence with occasional patchy golden yellow fluorescence: instantaneous blooming milky white cut:very faint light brown sample cut: no residual cut: medium bright bluish white residual sample fluorescence: porosity and permeability visually good. Sand (7240 -7330) = medium gray to medium light gray with light olive gray sub tones: upper very fine to lower very fine grained: spherical to sub discoidal: sub rounded to sub angular: well sorted: unconsolidated sand:grain supported:texturally immature: immature compositionally:translucent quartz with glauconite,black carbonaceous material and pale yellow orange lithics: slight oil odor: very faint amber grain staining: 100% even bright green sample fluorescence:instantaneous bright blue white sample cut:light brown sample cut:no residual cut: bluish white residual sample fluorescence: porosity and permeability visually good. Sand (7330 -7420) = medium gray to medium light gray with light olive gray sub tones: upper very fine to lower very fine grained: spherical to sub discoidal: sub angular to sub rounded: well sorted: unconsolidated sand:grain supported:texturally immature: immature compositionally:translucent quartz with glauconite,black carbonaceous material and pale yellow orange lithics: slight oil odor: very faint amber grain staining: 100% even bright green sample fluorescence:instantaneous bright blue white sample cut:light brown sample cut:no residual cut: bluish white residual sample fluorescence: porosity and permeability visually good. Sand/Sandstone(7420-7530)=medium dark gray to dark gray with light olive green sub hue: upper very fine to lower very fine grained: spherical to sub discoidal: sub rounded to sub angular: well sorted: unconsolidated sand, firm friable to moderately hard sandstone: grain supported: texturally immature: compositionally immature: translucent quartz with black and brownish black carbonaceous material, and glauconite:very slight oil odor:slight amber grain staining on sand grains,sandstone grain staining 100%dark brown:sand sample fluorescence 100%green,sandstone golden yellow:instantaneous bright blooming bluish white cut: light brown visual cut: no residual visual cut: bright blue white residual fluorescence: porosity and permeability visually good. OA SBL4 7565.0' MD/-3728.0' TVDSS Sand (7530-7600) = medium gray to medium light gray with light olive gray sub tones: lower fine to upper very fine grained: spherical to sub discoidal: sub rounded to sub angular:well sorted: unconsolidated sand: translucent quartz with glauconite and shell fragments: slight oil odor: very light oil stain: patchy dull green sample fluorescence: instantaneous blooming bluish white cut:very faint light brown visual cut:no residual cut: faint white residual fluorescence: porosity/permeability visually good. Siltstone(7600-7680)=dark gray to grayish black:firm friable to moderately hard:moderately to moderately well indurated: earthy fracture: sub tabular to sub wedge like cuttings habit: dull to earthy luster:silty to gritty texture: laminae to thin structure, very fine grain sand beds, 5 to 10 grains thick alternate with siltstone at times: moderate oil odor: brown grain stain: even bright green fluorescence with 30% patchy golden yellow fluorescence: instantaneous blooming bright white cut: light brown cut: no visible residual cut: medium white residual fluorescence. OA SBL4 7721.0' MD/-3736.4' TVDSS FAULT 1 7788.0' MD/-3739.4'TVDSS Sand / Sandstone (7680 -7810) = medium gray to medium dark gray: upper very fine to lower very fine grained:spherical to sub discoidal:sub rounded to sub angular:well sorted: unconsolidated sand,firm friable to moderately hard sandstone 7725 -7740:grain supported:texturally immature:compositionally immature: translucent quartz with glauconite and black carbonaceous material: sandstone has HCL reactive cement: 21 CANRIG eni Eni Petroleum 0107-04 slight oil odor: dark brown oil stain, especially sandstone: even green sample fluorescence, sandstone gold yellow: instantaneous dull bluish white fluorescence cut: light brown visible cut: no visible residue: moderate white residual fluorescence: porosity/permeability visually good. Siltstone/Silty Shale(7810-7930)=medium to medium dark gray: hard to very firm: non to coarsely fissile: waxy to dull earthy luster:silty to slightly sandy texture:irregular to tabular cuttings habit:cuttings are generally large and have a somewhat cupped appearance:material is inter-bedded with thin to very thin fine to very fine grained sand:locally has a slightly sandy appearance: 100%dull greenish yellow sample fluorescence:freshly broken fragments have a more yellow fluorescence:cuts readily to milky blue-white/greenish white:slight clear brown residue fluoresces blue-white and cuts readily back to blue-white: slight oil odor at the shakers no detectable odor other than OBM background from samples:slight stain and trace free oil in the 7910'sample: very slightly calcareous. Siltstone/Silty Shale(7930-8020)=medium to medium light gray: hard to very firm: non to coarsely fissile: waxy to dull earthy luster: silty to slightly sandy texture: irregular to lenticular and tabular cuttings habit: cuttings appear water worn/eroded from circulation: coarsely fissile: slightly sandy in part: material is more nearly shale in this interval:waxy to silty and gritty luster:occasional 2 to 8 mm tan,aragonitic shell fragment 100% dull to medium yellow-green sample fluorescence: immediate cut to milky blue-white with a slight greenish cast: slight clear brown residue fluoresces medium blue-white and cuts immediately to milky blue- white: very slightly calcareous. Siltstone/Silty Shale (8020 - 8110) = medium gray: hard to very firm: coarsely fissile: generally coarsely fissile locally moderately fissile:waxy to silty luster:silty to slightly sandy/gritty texture: irregular to tabular and lenticular cuttings habit: cuttings have a slightly cupped appearance from PDC bit action: some fragments display moderate to extensive erosion from circulation: hydrophilic: slightly adhesive: moderately cohesive: very slightly calcareous: cuttings are coated with fine grain calcium carbonate mud additives and fine sand: 100%dull greenish yellow to medium yellow sample fluorescence: immediate cut to milky blue-white with a slight greenish cast: slight clear brown residue fluoresces medium blue-white and cuts immediately to milky blue-white. Siltstone/Silty Shale(8110-8230)=medium gray: hard to very firm:coarsely fissile:some moderately fissile waxy to silty and slightly sandy/gritty texture: irregular to tabular and lenticular cuttings habit:cuttings have a slightly cupped appearance from PDC bit action:some fragments display moderate to extensive erosion from circulation: hydrophilic: slightly adhesive: moderately cohesive: very slightly calcareous: cuttings are coated with fine grain calcium carbonate mud additives and fine sand: 100%dull greenish yellow to medium yellow sample fluorescence: immediate cut to milky blue-white with a slight greenish cast:slight clear brown residue fluoresces medium blue-white and cuts immediately to milky blue-white,gradually becomes medium gold with time. OA SAND TOP 8260.0' MD/-3785.3' TVDSS Sand/Sandstone(8230 -8410) = medium to medium light gray with a slight olive secondary hue: soft dis- aggregated sand with variable amounts of firm to slightly hard friable sandstone fragments:well to moderately well sorted: fine lower to fine upper and very fine upper grain: scattered medium lower and medium upper grain: sub- angular to angular and sub-rounded: clear colorless to translucent white and smoky quartz predominate:abundant light to medium gray lithic/mineral grains:trace dark gray to black mafic mineral/lithics: trace brown grains: scattered small pyrite masses:trace to locally common tan shell fragments: mixed grain and matrix support: some sandstone fragments display moderate amounts of brown silt: friable in part: samples contain variable amounts of medium gray siltstone/shale as previously described: 100and mottled dull greenish yellow and dull yellow sample fluorescence: blooming cut to milky blue-white: slight clear brownish residue fluoresces blue-white: no notable oil odor above OBM background: fair brown oil stain in freshly broken fragments: safe-carb contamination continues. OA SBL2 8440.0' MD/-3800.4'TVDSS Sand/Sandstone(8410 -8570) = medium to medium light gray with a slight olive secondary hue: soft dis- aggregated sand with variable amounts of firm to very hard friable sandstone fragments:well to moderately well sorted:fine lower to fine upper and very fine upper grain: scattered medium lower grain: sub-angular to 22 CANRIG Pill Eni Petroleum 0107-04 angular and sub-rounded:translucent white to clear and slightly smoky quartz predominate:abundant light to medium gray lithic/mineral grains:trace dark gray to black mafic mineral/lithics:trace brown grains:scattered small pyrite masses: trace to locally abundant tan shell fragments: mixed grain and matrix support: some sandstone fragments display moderate amounts of brown silt: friable in part: 100% mottled dull greenish yellow and dull yellow sample fluorescence: blooming cut to milky blue-white: slight clear brownish residue fluoresces blue-white: no notable oil odor above OBM background: fair brown oil stain in freshly broken fragments: safe-carb contamination continues. Sand/Sandstone(8570 -8690) = medium to medium light gray with a slight olive secondary hue: soft dis- aggregated sand: locally recovered as angular hard to very hard calcareous sandstone fragments with some loose sand:well to moderately well sorted:friable in part:fine upper to fine lower and very fine grain:scattered medium: sub-angular to angular and sub-spheroidal: occasional samples with common moderately well rounded:translucent white to clear colorless quartz predominate: common light to medium gray lithics:trace dark gray to black mafic mineral grains:trace brown and brownish gray lithics:occasional small pyrite masses and red-orange jasper flakes: material appears primarily grain supported where friable: harder material is partially silt matrix sup-ported and calcareous: 100%mottled dull greenish yellow sample fluorescence with slow streaming to blooming cut to milky blue-white: slight clear brownish residue fluoresces blue-white: no notable oil odor above OBM background: lower zone has less oil stain and appears tight. Sand/Sandstone(8690-8800)= medium to medium light gray with a slight brown secondary hue: hard to very firm to dis-aggregated:well to moderately well sorted:friable in part:fine upper to fine lower and very fine upper grain:scattered medium:sub-angular to angular and sub-rounded:clear color-less to translucent white quartz pre-dominate:common light to medium gray lithic/mineral grains:trace dark gray to black mafic mineral grains:scattered to trace brown lithics:occasional small red-orange jasper flakes and pyrite masses:generally slightly silty grades to clean well sorted sandstone: locally grain supported: 100%mottled dull greenish yellow sample fluorescence with slow streaming to blooming cut to milky blue-white: slight clear brownish residue fluoresces blue-white: no notable oil odor above OBM background: slightly to moderately calcareous. OA SBL3 8870.0' MD/-3807.4'TVDSS Sand/Sandstone(8800-8950)= medium to medium light gray with a slight brown secondary hue: hard to very firm to dis-aggregated:well to moderately well sorted:friable in part:fine upper to fine lower and very fine upper grain:scattered medium:sub-angular to angular and sub-rounded:clear color-less to translucent white quartz pre-dominate:common light to medium gray lithic/mineral grains:trace dark gray to black mafic mineral grains:scattered to trace brown lithics:occasional small red-orange jasper flakes and pyrite masses:generally slightly silty grades to clean well sorted sandstone: locally grain supported:occasional very thin siltstone and tuff/ash interbeds: 100%100%mottled dull greenish yellow sample fluorescence:slow streaming to blooming cut to milky blue-white: slight clear brownish residue fluoresces blue-white: no notable oil odor above OBM background:visible oil streaming from some cuttings when wet with base oil:slightly to moderately calcareous. Sand/Sandstone(8950-9040)=medium dark gray to medium gray with light olive gray sub hues: lower fine to upper very fine grained:spherical to sub discoidal:sub rounded to sub angular:well sorted:unconsolidated sand: grain supported: texturally immature: compositionally immature: translucent quartz with black carbonaceous material and glauconite: faint oil odor: slight grain staining: 100% even dull green sample fluorescence:instantaneous blooming bright bluish white cut fluorescence:light brown sample cut:no residual cut: bright white residual sample fluorescence: porosity and permeability visually good. Sand (9040-9130)=dark gray to grayish black with light olive gray sub tones: upper very fine to lower very fine:spherical to sub discoidal:sub rounded to sub angular:well sorted: unconsolidated sand:grain supported: texturally immature: compositionally immature: translucent quartz with black carbonaceous material and glauconite: faint oil odor: slight grain staining: 100% even dull green sample fluorescence: instantaneous blooming bright blue white cut fluorescence: light brown sample cut: no residual cut: bright white sample residual fluorescence: porosity and permeability visually good. Sand(9130-9220)=dark gray to grayish black with light olive gray sub tones: upper very fine to lower very fine:spherical to sub discoidal:sub angular to sub rounded:well sorted:unconsolidated sand:grain supported: texturally immature: compositionally immature: translucent quartz with black carbonaceous material and glauconite: faint oil odor: slight grain staining: 100% even dull green sample fluorescence: instantaneous 23 CANRIG Taft eni Eni Petroleum 0107-04 blooming bright blue white cut fluorescence: light brown sample cut: no residual cut: bright white sample residual fluorescence: porosity and permeability visually good. Sand (9220-9310)=dark gray to grayish black with light olive gray sub hues: upper very fine to lower very fine:spherical to sub discoidal:sub rounded to sub angular:well sorted:unconsolidated sand:grain supported: texturally immature: compositionally immature: translucent quartz with black carbonaceous material and glauconite: faint oil odor: slight grain staining: 100% even dull green sample fluorescence: instantaneous blooming bright blue white cut fluorescence: light brown sample cut: no residual cut: bright white sample residual fluorescence: porosity and permeability visually good. Sand (9310-9400)= grayish black to dark gray with olive gray sub hues: upper very fine to lower very fine grained:spherical to sub discoidal:sub rounded to sub angular:well to very well sorted: unconsolidated sand: grain supported:texturally immature:compositionally immature:translucent quarts with glauconite and black carbonaceous material: very faint oil odor: slight grain staining: 100%even dull green sample fluorescence: blooming bright bluish white cut fluorescence: light brown sample cut: no residual cut: bright white sample residual fluorescence: porosity and permeability visually good. Sand (9400-9490)= dark gray to grayish black with olive gray sub hues: upper very fine to lower very fine grained:spherical to sub discoidal:sub rounded to sub angular:well to very well sorted: unconsolidated sand: grain supported:texturally immature:compositionally immature:translucent quartz with black carbonaceous material and glauconite: very faint oil odor: slight grain staining: 100% even dull sample fluorescence: blooming bright blue white sample cut: no residual cut:bright white sample residual fluorescence:porosity and permeability visually good. Sand (9490-9580) = grayish black to dark gray with olive gray sub hues: upper very fine to lower very fine grained:spherical to sub discoidal:sub rounded to sub angular:well to very well sorted:unconsolidated sand: grain supported:texturally immature:compositionally immature:translucent quarts with glauconite and black carbonaceous material: very faint oil odor: slight grain staining: 100%even dull green sample fluorescence: blooming dull bluish white cut fluorescence: very faint brown sample cut: no residual cut: dull white sample • residual fluorescence: porosity and permeability visually good. Sand (9580-9670) = grayish black to dark gray with olive gray sub tones upper very fine to lower very fine grained:spherical to sub discoidal:sub angular to sub rounded:well to very well sorted: unconsolidated sand: grain supported:texturally immature:compositionally immature:translucent quarts with glauconite and black carbonaceous material: very faint oil odor: slight grain staining: 100%even dull green sample fluorescence: blooming dull bluish white cut fluorescence: very faint brown sample cut: no residual cut: dull white sample residual fluorescence: porosity and permeability visually good. Sand (9670-9760) = grayish black to dark gray with olive gray sub hues: upper very fine to lower very fine grained:spherical to sub discoidal:sub rounded to sub angular:well to very well sorted: unconsolidated sand: grain supported:texturally immature:compositionally immature:translucent quarts with glauconite and black carbonaceous material:very faint oil odor: slight grain staining: 100%even dull green sample fluorescence: blooming dull bluish white cut fluorescence: very faint brown sample cut: no residual cut: dull white sample residual fluorescence: porosity and permeability visually good. Sand (9760-9850)=dark gray to grayish black with olive gray sub tones: upper very fine to lower very fine grained:spherical to sub discoidal:sub rounded to sub angular:well to very well sorted:unconsolidated sand: grain supported:texturally immature:compositionally immature:translucent quarts with glauconite and black carbonaceous material: very faint oil odor: slight grain staining: 100%even dull green sample fluorescence: blooming dull bluish white cut fluorescence: very faint brown sample cut: no residual cut: dull white sample residual fluorescence: porosity and permeability visually good. Sand (9850-9940) = grayish black to dark gray with olive gray sub hues: upper very fine to lower very fine grained:spherical to sub discoidal:sub rounded to sub angular:well to very well sorted:unconsolidated sand: grain supported:texturally immature:compositionally immature:translucent quarts with glauconite and black carbonaceous material: very faint oil odor: slight grain staining: 100%even dull green sample fluorescence: blooming dull bluish white cut fluorescence: no sample cut: no residual cut: dull white sample residual fluorescence: porosity and permeability visually good. 24 CANRIG -Leni Esti Petroleum 0107-04 Sand(9940-10030)=dark gray to grayish black with olive gray sub tones: upper very fine to lower very fine grained:spherical to sub discoidal:sub rounded to sub angular:well to very well sorted:unconsolidated sand: grain supported:texturally immature:compositionally immature:translucent quarts with glauconite and black carbonaceous material: very faint oil odor: slight grain staining: 100%even dull green sample fluorescence: blooming dull bluish white cut fluorescence: no sample cut: no residual cut: dull white sample residual fluorescence: porosity and permeability visually good. OA SBL3 10074.0' MD/-3805.5'TVDSS Sand(10030-10150)=dark gray to grayish black with olive gray sub tones: upper very fine to lower very fine grained:spherical to sub discoidal:sub rounded to sub angular:well to very well sorted:unconsolidated sand: grain supported:texturally immature:compositionally immature:translucent quarts with glauconite and black carbonaceous material:very faint oil odor: slight grain staining: 100%even dull green sample fluorescence: blooming dull bluish white cut fluorescence: light brown sample cut:no residual cut:dull white sample residual fluorescence: porosity and permeability visually good. OA SBL3 10141.0' MD/-3806.7' TVDSS Sand(10150-10240)=grayish black to dark gray with olive gray sub hues: upper very fine to lower very fine grains:spherical to sub discoidal:sub rounded to sub angular:well to very well sorted: unconsolidated sand: grain supported:texturally immature:compositionally immature:translucent quarts with glauconite and black carbonaceous material: very faint oil odor: slight grain staining: 100%even dull green sample fluorescence: streaming dull bluish white cut fluorescence: no sample cut: no residual cut: dull white sample residual fluorescence: porosity and permeability visually good. Sand(10240-10330)=dark gray to grayish black with olive gray sub tones: upper very fine to lower very fine grained:spherical to sub discoidal:sub rounded to sub angular:well to very well sorted: unconsolidated sand: grain supported:texturally immature:compositionally immature:translucent quarts with glauconite and black carbonaceous material: very faint oil odor: slight grain staining: 100%even dull green sample fluorescence: blooming dull bluish white cut fluorescence: light brown sample cut: no residual cut:dull white sample residual fluorescence: porosity and permeability visually good. Sand/Sandstone(10330-10480)= medium to medium light gray: slight brownish secondary hue: samples recovered as loose dis-aggregated sand with variable amounts of hard medium upper grain size shattered angular well cemented sandstone fragments:well to moderately well sorted:fine lower to very fine upper and fine upper grain trace to scattered medium grain sand: common to trace medium grain size sandstone fragments: scattered coarse: sub-angular to angular and sub-spheroidal:scattered moderately well and well rounded:translucent white to clear colorless quartz predominate:common medium and light gray lithic/mineral grains: trace to common brown grains: trace blue-gray and gray-green lithics: occasional red-orange jasper and small pyrite masses:material appears to be primarily grain supported and well indurated with some areas of good porosity: 100%dull to medium dull yellow sample fluorescence with a slight greenish cast:slow cut to dull slightly milky blue-white:slight clear brownish residue with a medium blue-white fluorescence cuts back to milky blue-white: residue fluorescence becomes more yellow over time and cuts to yellow white:slight oil stain on some grains and occasional fragments: no discernable odor above OBM: moderately calcareous. Sand/Sandstone(10480-10630)= medium to medium light gray: slight brownish secondary hue: samples recovered as loose dis-aggregated sand:friable in part:well to moderately well sorted:fine lower to very fine upper and fine upper: trace to scattered medium grain size well cemented shattered sandstone fragments: scattered medium grain and coarse sand: sub-angular to angular and sub-rounded: scattered moderately rounded and well-rounded grains:translucent white to clear colorless quartz predominate:common medium and light gray lithic/mineral grains: trace to common brown grains: trace blue-gray and dark green lithics: occasional red-orange jasper and small pyrite masses: material appears to be primarily grain supported and well indurated with some areas of good porosity: 100%dull yellow sample fluorescence with a slight greenish cast poor cut to dull slightly milky blue- white: trace clear brownish residue with a medium blue-white fluorescence cuts back to milky blue-white: slight oil stain on some grains and occasional fragments: no discernable odor above OBM: moderately calcareous. OA SBL4 10684.0' MD/-3834.9' TVDSS 25 CANRIG L eni Enl Petroleum 0107-04 Sand/Sandstone(10630-10750)=medium to medium dark gray:slight brownish secondary hue: samples recovered as loose dis-aggregated sand:friable in part:moderately well to well sorted:fine lower to fine upper and very fine grain:trace medium grain:sub-angular to angular and sub-spheroidal:trace moderately rounded: predominantly clear to translucent white quartz:common to abundant light to medium gray and brownish gray lithic/mineral grains:trace dark gray to black,green and pale blue-gray:100%dull yellow sample fluorescence with a slight greenish cast: poor cut to dull slightly milky blue- white: trace clear brownish residue with a medium blue-white fluorescence cuts back to milky blue-white:slight oil stain on some grains and occasional fragments: no discernable odor above OBM: moderately calcareous. Siltstone (10750-10860) = medium dark gray: very firm to hard: sandy to clean silty texture: dull earthy to gritty luster: interbedded clean siltstone and variably sandy siltstone grading to silt sandstone:common micro- thin carbonaceous lamina:sandy material is oil stained an shows some visible porosity:coarsely fissile in part: contains very fine upper to fine lower grain sand in the same mineralogical relationships as the adjacent sandstone: 100%dull greenish yellow sample fluorescence with a good streaming cut to medium-dull blue- white: slight brownish residue fluoresces medium blue-white when fresh: cuts back to blue-white: residue fluorescence becomes more yellow with time: slightly to moderately calcareous. Siltstone/Sandstone(10860-11030)=medium to medium light gray with a slight brownish secondary hue: firm to hard irregular slightly eroded fragments and disaggregated sand:moderately well to well sorted:friable in part:very fine upper to fine lower and fine upper:sub-angular to sub-rounded and angular:trace moderately well rounded: predominantly translucent white to clear colorless and smoky quartz:abundant light to medium gray lithic/mineral grains: trace dark gray to black lithic/ mineral grains: trace soft black carbonaceous inclusions:trace to abundant micro-thin carbonaceous lamina:trace dark green and medium blue-gray lithic/ mineral grains: trace brick red jasper: abundant pyrite in part: mixed grain and matrix support: well to moderately well and loosely indurated: silty to very silty: grading to sandy siltstone: trace larger grain sandstone with abundant carbonaceous inclusions has very good visible porosity and is loosely indurated with pyrite as a secondary cement: no visible stain: freshly broken fragments show no interior oil stain: no odor above OBM background: 100% mottled dull greenish yellow and yellow sample fluorescence: fair slow streaming cut:slight brownish residue fluoresces dull blue white becoming more yellow with time:cuts to milky yellow-white. OA SAND BOTTOM 10939.0' MD/-3847.2'TVDSS Siltstone/Sandstone(11030-11200)=medium to medium light gray with a slight brownish secondary hue: firm to hard irregular slightly eroded fragments and disaggregated sand:moderately well to well sorted:friable in part:very fine upper to fine upper and fine lower sub-angular to sub-rounded and angular:trace moderately well rounded: predominantly translucent white to clear colorless and smoky quartz:abundant light to medium gray lithic/mineral grains: trace dark gray to black lithic/ mineral grains: trace soft black carbonaceous inclusions:trace to abundant micro-thin carbonaceous lamina:trace dark green and medium blue-gray lithic/ mineral grains:trace shell fragments:abundant pyrite:mixed grain and matrix support:well to moderately well and loosely indurated: silty to very silty:grading to sandy siltstone:trace loosely indurated material has good visible porosity and displays abundant pyrite as a secondary cement: no visible oil stain on fragments, sand grains or freshly broken fragments: no discernable odor above OBM background: 100%dull mottled greenish yellow and yellow sample fluorescence: fair slow streaming cut: good brownish residue fluoresces dull blue white becoming yellow with time: cuts to milky yellow-white: slightly to moderately calcareous. OA SAND BOTTOM 11071.0' MD/-3850.2'TVDSS OA SBL4 11222' MD/-3847.4'TVDSS Sand/Sandstone(11200-11350)=medium to medium light gray:slight brownish secondary hue: loose dis- aggregated sand and well indurated sandstone and siltstone fragments:very fine upper to fine lower and fine upper grain with trace to common medium grain:sub-angular to angular and sub-rounded:clear to translucent white and smoky quartz predominate:trace to common light to medium gray:trace e dark gray to black mafic mineral/lithics: common dark and medium green mineral: trace brown and tan lithics: trace carbonaceous grains and small to medium grain size pyrite masses: primarily well indurated in the upper section becoming more friable with depth: 100%medium to dull yellow fluorescence:good fast streaming cut to milky blue-white: good clear brown residue dries to a medium yellow-white fluorescence and cuts to milky yellow white: no odor: slight oil on some grains in the 11230' sample: slightly to moderately calcareous. 26 CANRIG eni En! Petroleum 0107-04 Sand/Sandstone (11350 - 11430) = medium light to medium gray: dis-aggregated to hard well indurated sandstone:well sorted:friable in part: upper fine to lower fine with occasional lower medium grains:spherical to sub discoidal: sub rounded to sub angular: moderately well sorted: grain supported sandstone: texturally immature: compositionally immature: translucent quartz with black carbonaceous material and glauconite: slight to slightly fair oil odor: light brown to amber grain stain on sandstone, very light brown stain on sand grains: 100%light green fluorescence:blooming bright blue white fluorescence cut:light brown to amber visual cut: light brown visual residual cut: bright white residual fluorescent cut: porosity and permeability visually good. Sand(11430-11530)=dark gray to medium dark gray with greenish gray sub hue: upper very fine to lower very fine with some lower fine grains:spherical to sub discoidal:sub rounded to sub angular:well sorted:sand is unconsolidated: grain supported: texturally immature: compositionally immature: translucent quartz with black carbonaceous lithics and glauconite: faint oil odor: slight stain on grains: 100% even light green fluorescence: blooming bright blue white fluorescence cut: light brown visual cut: light brown visual residual cut: bright white residual fluorescence cut: porosity and permeability visually good. Sand(11530-11620)=medium dark gray to dark gray with light olive gray sub hue: upper very fine to lower very fine: spherical to sub discoidal: sub rounded to sub angular: well sorted: sand is unconsolidated: grain supported: texturally immature: compositionally immature: translucent quartz with glauconite and black carbonaceous material: faint oil odor: slight stain on grains: 100% light even green fluorescence: bright blooming blue white fluorescence cut: light brown visual cut: bright white residual fluorescence cut: porosity and permeability visually good. Sand(11620-11710)=dark gray to medium dark gray with olive gray sub tones: upper very fine to lower very fine:spherical to sub discoidal:sub rounded to sub angular:well sorted:unconsolidated sand:grain supported: texturally immature: compositionally immature: translucent quartz with glauconite and black carbonaceous material:faint oil odor:slight stain on grains: 100%light even green fluorescence: bright blooming blue white fluorescence cut: light brown visual cut: bright white residual fluorescence cut: porosity and permeability visually good. Sand(11710-11800)=medium dark gray to dark gray with olive gray sub hues: upper very fine to lower very fine: spherical to sub discoidal: sub rounded to sub angular: well sorted: sand is unconsolidated: grain supported: texturally immature: compositionally immature: translucent quartz with glauconite and black carbonaceous material: faint oil odor: slight stain on grains: 100% light even green fluorescence: bright blooming blue white fluorescence cut: light brown visual cut: bright white residual fluorescence cut: porosity and permeability visually good. Sand(11800-11890)=medium dark gray to dark gray with light olive gray sub tones:upper very fine to lower very fine: spherical to sub discoidal: sub rounded to sub angular: well sorted: unconsolidated sand: grain supported:texturally immature:compositionally immature:translucent quarts with black carbonaceous material and glauconite: 100%light even green fluorescence: bright blooming blue white fluorescence cut: light brown visual cut: bright white residual fluorescence cut: porosity and permeability visually good. Sand(11890-11980)=medium dark gray to dark gray with olive gray sub tones: upper very fine to lower very fine: spherical to sub discoidal: sub rounded to sub angular: well sorted: sand is unconsolidated: grain supported: texturally immature: compositionally immature: translucent quartz with glauconite and black carbonaceous material: faint oil odor: slight stain on grains: 100% light even green fluorescence: bright blooming blue white fluorescence cut:light brown visual cut:bright white residual fluorescence cut:light brown visual residual cut: bright white residual fluorescence: porosity and permeability visually good. Sand(11980-12070)=medium dark gray to dark gray with light olive gray sub hues:upper very fine to lower very fine grained: spherical to sub discoidal: sub rounded to sub angular: well sorted: unconsolidated sand: compositionally immature: texturally immature: translucent quartz with glauconite and black carbonaceous material: faint oil odor: slight light brown grain stain: 100% light even green sample fluorescence: bright to moderate bright blooming blue white fluorescence cut: light brown visual cut:very light brown visual residual cut: bright white residual fluorescence: porosity and permeability visually good. Sand(12070-12160)=dark gray to medium dark gray with light olive gray sub tones:upper very fine to lower very fine grained: spherical to sub discoidal sub rounded to sub angular: well sorted: unconsolidated sand: 27 CANRIG eni Eni Petroleum 0107-04 compositionally immature: texturally immature: translucent quartz with black carbonaceous material and glauconite:faint oil odor:slight light brown grain stain: 100%even green sample fluorescence:moderate bright blooming blue white fluorescence cut: very light brown visual cut: very light brown visual residual cut: moderate white residual fluorescence: porosity and permeability visually good. Sand(12160-12250)=medium dark gray to dark gray with olive gray sub hues: upper very fine to lower very fine: spherical to sub discoidal: sub rounded to sub angular: well sorted: sand is unconsolidated: compositionally immature texturally immature: translucent quartz with glauconite and black carbonaceous material: faint oil odor: slight light brown grain stain: 100% even green sample fluorescence: moderate dull blue white fluorescence cut:very light brown visual cut:very light brown residual cut: moderate white residual fluorescence: porosity and permeability visually good. Sand(12250-12325)=medium dark gray to dark gray with olive gray sub tones: upper very fine to lower very fine grained sand: spherical to sub discoidal: sub rounded to sub angular:well sorted: unconsolidated sand: compositionally immature: texturally immature: translucent quartz with black carbonaceous material and glauconite:faint oil odor:slight light brown grain stain: 100%even green sample fluorescence:moderately dull blue white fluorescence cut:very light brown visual cut:very light brown residual cut:moderate white residual fluorescence: porosity and permeability visually good. TD 12325.0' MD/-3871.3' TVDSS 28 CANRIG eni Eni Petroleum 0107-04 3.4 Connection Gas Summary 1 Unit=0.05% Methane Equivalent Depth(ft) Background Units C-1 C-2 C-3 C-4 C-5 Gas Above MD TVDSS (Units) Background (ppm) (ppm) (ppm) (ppm) (ppm) Note: No Connection Gas noted. The well was drilled slightly over balanced. 3.5 Trip/Wiper Gas Summary Depth at Trip(ft) Trip To Depth (ft) Max Gas Pumps Off Comments MD TVDSS MD TVDSS (units) (hours) 5618 -3627.2 Surf - 128 29 Run 9 5/8" Casing 12325 -3871.3 5542 - 61 15 Clean and Condition Hole 29 CANRIG eni Eni Petroleum 0107-04 3.6 Sampling Program and Sample Dispatch Sample Program Dry samples: (2 sets) Every 30'from 1000'to TD (13250' MD). Set Processed As I Frequency* Interval* Dispatched to Washed, dried, stored Fugro Data Solutions vials. A Reference Samples. 30' 1000'to 13250' 3311 S. US Hwy 77 Set Owner: ENI Schulenburg, TX 78956 Washed, dried, stored AOGCC vials. B Reference Samples. 30' 1000'to 13250' 333 W. 7TH Ave., Suite 100 Set Owner: State of Alaska Anchorage, AK 99501 Sample frequency and interval may be altered locally according to on-site geologist. 30 CANRIG eni Eni Petroleum 0107-04 4 PRESSURE AND FORMATION STRENGTH DATA 4.1 Pore Pressure Gradient Evaluation Formation Primary Secondary Top Of Interval (ft) Pore Pressure Trend Indicators Lithology(%) Lithology(%) (EMW, ppq) MD TVDSS Min Max Trend Permafrost Sd/Cgl 60% Sltst/Clyst 40% Surface Surface 8.8 9.3 Up(SL) BG,CG, MW, ECD Ugnu Sd/Cgl 60% Clyst/Sltst/Sh 2150 -2000 8.9 9.3 Up(SL) BG,CG,TG, MW 40% *Schrader Bluff Sd/Sltst 80% Sltst 20% 4004 -3307 9.2 9.4 Even BG, CG, TG, MW 4.2 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight(MW) and effective circulating density(ECD), including increases in background gas(BG),appearance and trends of connection gas(CG), lost circulation(LC),and magnitudes of trip gas(TG)and wiper gas(WG). Regional pore pressure trends from sonic data,provided by client,and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Canrig, and then modified using the indicators described above, and DXC and resistivity (RES) data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD—(0.6-((.001*TLGSU)+(0.05*DX))) The formula has certain limitations, such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However,the formula proved useful in helping establish a PPG range,when establishing trends, as with DXC data,with data points in shale intervals. 31 CANRIG VAC eni Eni Petroleum 0107-04 5 DRILLING DATA 5.1 Daily Activity Summary 12/26/2010: Mobilization move and spot drill module over hole center and set down on mats, shim/level rig. Place mats in-line for utility module. Move and mate up utility module, shim/level. Set down on mats. Mobilization berm around rig. R/U de-gasser and flowlines same. R/U interconnects same. Put steam and air on-line throughout rig. Secure walkways / doorways. Lower cellar box and curtains. Secure Lampson curtains.Assemble mud Pumps caps/valves. N/U riser and spacer spools install riser/pitcher nipple riser in shed. PU Vetco starting head. Lower to well bay for prep and set on conductor. Install riser and flow line n/u riser and flow line.Test upper and lower well head seals t/500psi(Vetco rep)install hole fill and bleeder lines. Install aluminum hatch and drip liner around riser. Install catch can and curtain around riser. Rinse out mud pits, prep f/building spud mud. Calibrate and test gas alarms. Rig up assist spotting CCB and cuttings tank. Thaw out cuttings tank and heat coil.Service top drive,crown and block sheaves,draw works.Load pipe shed with drill pipe.Calibrate Canrig block height. Hang rig tongs. Install elevators. Install mouse hole in r.t.prep rig floor f/PU drill pipe 12/28/2010: Pick up drill pipe finish loading and strapping 5"drill pipe pick up drill pipe P/U 189 joints 5"drill pipe m/u in mouse hole. Rack stands back in derrick. Drifting every joint. Mix 300BBLS spud mud. Load pipe shed w/14 joints 5" HWDP and jar, strap. Pick up drill pipe P/U and rack back 5"HWDP.Tag bottom @ 103' build volume weight finish building spud mud-690BBLS. 8.7ppg vis 138, continue thawing out cuttings tank. Continue R/U CCB. Load 57joints 13 3/8 casing in shed. Load BHA in shed. Prep rig floor tools f/P/U BHA. Rig up continue. R/U CCB and thawing out cuttings tank. Repair blower on #4scr. P/U and stand back jars/HWDP. P/U small BHA items and stage on floor. 12/29/2010: Working as directed by operator PU motor. Pooh, lines. -42F weather, standing by. Reaming/washing P/U M/U mud motor, stand HWDP. Clean out conductor t/160'450GPM 300psi 1k-torque 25rpm. PU t/motor. Waiting on weather stand by due to cold weather-430. CCB continue to run heat trace lines per mi-Swaco. Rig up continue. R/U CCB lines. Finish containment around CCB and cuttings tank area. Finish drifting and strapping casing. Repair generator at the WIF.Prespud meeting.Pick up BHA circulate and condition bring on Pumps. Check circ system,cuttings tank etc,shallow test MWD/gyro P/Pulse,take survey rotary drilling f/160't/505'up weight 80 down weight 80 rot weight 80 40rpm torque 3/2 WOB 15-25k 516GPM 690psi on 550psi off mud weight 8.9 ECD 9.05 BHA weight @ jars 70k. art 2.35 ast .32 jars 2.7. 12/30/2010: Slide drilling cycling Pumps for gyro survey per gyro rep. drilling. sliding/rotating f/505' t/1185'@500GPM 120SPM 750psi-on 700psi-off 40rpm 3500torque-on1000torque-off 85up-weight 85dwn- weight 85rot-weight 15-25k-WOB gyro survey every connection.Adt-7.87hrs ast-5.14hrs art-2.73hrs. rotary drilling f/1185't/1849'up weight 105 down weight 100 rot weight 102 40rpm torque 5/3 WOB 10-30k 635GPM 1225psi on 1110psi off. Mud weight 9.3ppg ECD 9.89.art 2.63 ast 2.60 jars 15.8.trip out of hole pooh t/1738' b/d td R/U cement hose t/circ. downtime-top drive troubleshoot td, loose wire on encoder, reconnect wire, function test top drive, working properly. Replace guard and safety wire. 12/31/2010: Slide drilling f/1849't/2185'650GPM 150SPM 1200psi-on 1150psi-off 40 rpm 3.4k-torque-on 2- 3k-torque-off 15-25WOB 105 up-weight 100dwn-weight 100 rot-weight sliding and rotating on occasion per dd. washing 30' up/down before conn. Downtime-top drive electrician c/o top drive encoder. Circ through circ hose 2 BPM 140psi. rotary drilling continue drilling f/2185't/2330'T.D.650GPM 150SPM 1250psi-on 1150psi- off 3k-torque-off 3.5-torque-on 110up-weight 105dwn-weight 103rot-weight 40rpm back reaming 30'up/down adt-3.32 ast-1.35 art-1.97 9.1 ppg 9.92ECD 2206TVD circulate and condition CBU+3 times and Pump 40bbl hi-vis sweep @ 650GPM 150SPM 1170psi 40rpm 2800torque reciprocating pipe till shakers clean per mud man. Back reaming back reaming f/2330't/2025'635 GPM 40rpm 1050psi 2.5-4.5torque trip out of hole back ream out f/2025't/585'(HWDP)50 rpm 635 GPM. Circulate and condition circ hole clean.600-700GPM.Trip out of hole t/BHA. Lay down BHA rack back jars and collars. L/d BHA. Clean rig floor. Rig up/down to run casing dummy run 13 3/8 hanger, verified by Vetco rep. Rig up/down to run casing R/U t/run casing. 32 CANRIG eni En! Petroleum 0107-04 01/01/2011: Run casing m/u 13-3/8 68#1-80 BTC casing check float equipment.t/2,315'average torque=7000 fill on fly top off every 10 joints. Break circ @1,880 GPM=84 psi=230, m/u landing joint, install a total of 18 cents. Start taking weight f/1,175 t/1,400 15-25 k. Circulate and condition mud, reciprocate pipe. Up=170 down=150,GPM=212 psi=160 stage Pumps up. Install cement lines r/d franks tool,blow down top drive, R/U cement head. Primary cementing Pump 5 BBLS H2O.Pressure test cement lines t/4000psi. Pump 100 BBLS 10.1 mud push,drop bottom plug pump 495 BBLS 10.7 lead cement,81 BBLS 12.5 tail,kick top plug out with 10 BBLS H2O, switch over to rig pumps. Cement back @ 570 strokes. Primary cementing continues. Displacing cement w/ rig pump. Bump plug @3215 strokes. Hold 900psi (500 over)f/5 min. bleed off and Check floats holding-good. 264 BBLS cement returns t/surface. Rig up/down to run casing b/d lines. R/D cement head. R/d casing elev.rinse out and I/d landing joint.Flush out stack and flowline w/50bb1 retarder pill. L/d casing tools. ND riser and spacer spools,nipple up bops n/u well head and well head valves. N/u riser and stack. Install bell nipple. Working as directed by operator install lifting rams f/stack. P/U stack and check for clearance. 27"clearance between riser and well head. 01/02/2011: Nipple up BOP', remove one BOP picking cylinder.Torque up n/u flow line, install choke and kill lines, install turn buckles, hole fill and bleed off lines.Thaw out mouse hole install mouse hole. PU test tools R/U testing equipment, install test plug. waiting on weather phase 3 weather called at 06:30 waiting on weather phase 3 weather,suspend rig work until 20:00 PU test tools m/u test jt.fill stack and choke manifold, purge air out of lines, test bops 250/3500 (including annular) 5 min each, record on chart. 01/03/2011: Test BOP,choke,top drive,dart,tiw.As per AOGCC.250 psi low 3500 psi high for 5 mins each. Witness waived by Bob Noble, AOGCC. Test tool R/D testing equipment. Blow down, P/U test plug. Install/remove wear bushing install wear ring, id=12-1/4. Pick up 3rd party tools P/U BHA#3 from beaver slide. Nipple up BOPE, install Katch-Kan. Pick up BHA M/U bit power drive, receiver,flex,arc, non-magnetic ILS stab,telescope, nm stab, 1 stand flex dc f/drk float saver sub,hyd jars,HWDP,4 stand drill pipe and ghost reamer. t/1040' test power drive with 94' hanging to see pads. @ 650 GPM, psi=660, trip in hole f/1,040 t/ 2,230' tagged set 8k down. Pick up t12,189'. Circulate and condition, CBU GPM=650 psi=1140 up=110 down=95 rot=102 rpm=25 torque=3-4 pressure test casing/shoe pressure test 13-3/8 casing t/2500psi.for 30 mins. Good test, blow down, drilling cement and float equipment f/2230 t/2232' up=115 down=100 rot=110 WOB=2-6 GPM=550 psi=780 rpm=40 torque=3-4/4-5. Drilling cement drill out cement plugs,float collar,shoe track,shoe collar.drill 20'new hole t/2350'50 rpm torque 3-5k WOB 5-10k 650 GPM 1100psi 750 GPM 1450 psi. Pull into shoe,circulate and condition CBU,even mud weight in/out 9.3ppg.660 GPM 1150 psi formation integrity test (FIT) 12.0ppg EMW. Change out mud system displace hole t/8.9ppg 45 vis LSND mud take SPR's #1 mp 35 SPM 120 psi 45 SPM 145 psi #2mp 35 SPM 120 psi 45 SPM 145 SPM. Down link t/ powerdrive.Shut down t/clean pit#7,shakers.Take on new mud f/vacuum trucks,rotary drilling drill f/2350 t/ 2955md 2706, up weight 128 down weight 105 rot weight 115 140 rpm torque 5/4 WOB 2-10k 859GPM 1440psi ECD 9.31 ppg mud weight 8.8 adt 3.58 jars 22.68 01/04/2011 Rotary drilling f/2'955' t/4020 TVD/3372 up=140 down=108 rot=125 WOB=5-15 GPM=855 psi=1650/1675 rpm=100 torque=6000/6500 ECD=9.45 bit hrs=7.51 jar hrs=30.8 SPR 1and2 SPM=35/45 psi=70/100 70/100 and=3720 TVD=3213 mud weight=8.9 rotary drilling f/4020't/5157md 3632TVD up weight 142 down weight 100 rot weight 120 120 rpm torque 7/6 WOB 10-12k 851 GPM 2030psi ECD 10.01 mud weight 9.3 adt 9.31 jars 40.1SPR @ 4965md/3624TVD mud weight 9.2ppg #1mp 35SPM 110psi 45SPM 140psi#2mp 110psi 45SPM 140psi: 01/05/2011 Rotary drilling 5,157' t/5,618' TVD/3682 up=138 down=95 rot=110 WOB=10-14 GPM=855 psi=2160/2120 rpm=120 torque=6/7 ECD=10.3 bit hrs=3.36 jar hrs=43.40 SPR 1 and 2 SPM=35/45 psi=120/150 120/150md=5618TVD=3682 mud weight=9.3 1,322 units of gas back @ 5,612'shut down and monitor well, static, circulate and condition CBU 3 x rot and reciprocate, stand one back every bu. rot=110 GPM=855 psi=2120 rpm=120 torque=5-6 f/5,618't15,348'monitor well for 10 mins. Back reaming back ream f/5,348 t/3,338'up=135 down=105 rot=120 GPM=855 psi=1860 rpm=120 torque=4-5,trip out of hole continue BROOH.t/2315'up weight 120 down weight 100 rot weight 110 120rpm torque 3k 850GPM 1650psi circulate and condition circ until clean 850GPM 1650psi 75rpm 3k torque trip out of hole flow check well-static. Pump slug. Pooh t/BHA, lay down BHA, change rams. Pull wear ring. R/U test jt. set test plug. rilds. monitor open annulus change rams change top rams t/9 5/8 pipe rams test bops test 9 5/8 pipe rams 250/3500 5 min each 33 CANRIG eni Eni Petroleum 0107-04 record on chart. Rig up/down to run casing Pump out stack.P/U hanger/landing joint,make dummy run,verify landed by Vetco rep, rig up/down to run casing P/U and R/U Tesco casing running equip: 01/06/2011 Rig up/down to run casing R/U Tesco casing running equip. Pre job safety pre job safety meeting with all hands and Tesco, hands.We talked about the what ifs. We went over the Tesco procedure for using their tool. Run casing m/u shoe. Run casing 9 5/8 casing f/4404 t/5606 up weight 100 down weight 68. M/u hanger and land out. Rig up/down to run casing r/d Tesco equip, R/U cement head. Blow air through choke/gas buster to verify open. Circulate and condition fill casing w/rig Pump start out @ 1 BPM bleed air through choke. Fill pipe w/ —415BBLS. install cement lines remove cement head, blow down lines, R/U elevators, load cement plugs, verified by co rep circulate and condition, break circ on up stoke break over weight stage up t/5BPM 260psi 7 BPM 350psi primary cementing cement: 01/07/2011 Primary cementing, pump 82 BBLS mud push, 252 BBLS DeepCrete 12.5 ppg slurry. Drop top plug w/10 BBLS h20. Switch over to rig Pumps. GPM=279 psi=850 slow Pumps down U126 GPM psi=720 bump plug on stk's 3942' psi up U1240psi held f/3 mins bleed off check floats. Ok. Reciprocate pipe up=255 down=150. cip@01:24. Rig up/down to run casing r/d cement head, elevators, blow down cement line and mud line. Put 5"elevators on. Test wellhead install 9-5/8 pack-off. Test t/5000psi f/10 mins. Good test. Rig up/down to run casing clear floor of cement head and casing tools. install/remove wear bushing install wear ring id=9-1/8 change rams c/o top rams f/9-5/8"t/4-1/2"-7" pick up drill pipe load and strap 5"drill pipe into shed. Steam pipe out blowed full of snow, con't cleaning pits and surface equipment. pick up drill pipe m/u mule shoe, RIH 1x1 t/701'up=50 down=45 pick up drill pipe PU 5"DP 1x1 from 701'-5008'159 joints in hole 140k up 90k down service rig service td/blocks/draw works circulate and condition prime Pump#3 circ thru bleeder over top of hole 80 SPM 1200psi Pump functioned ok trip out of hole from 5008'-2754'140k up 90k down pick up drill pipe f/2754-4214'RIH with last 39 joints from shed 1x1 130k up 90k down trip out of hole clean off rig floor/Put stripping rubber in: 01/08/2011 Trip out of hole f/t/98' cut drilling line slip and cut 67'of line. service top drive service top drive, draw works, blocks, crown. grease top drive rail. trip out of hole Pull stripping rubber, blow down mud line. stand back one stand l/d mule shoe. install/remove wear bushing Pull wear ring. PU test tools R/U to test bop w/5-1/2 test joint.fill BOPE and choke w/h20 test bops test BOPE, choke, dart,tiw,top drive,w/5.5and 3.5, test joints. 250psi low 3500psi high. Koomey test. as per AOGCC. got a 250 psi low on annular with 3.5 test joint.attempted 7 times.Worked annular many times-no hi test.Witnessed waived by Jeff Jones AOGCC. test bops function test annular on 2"pipe/PU test joint attempt to test annular after functioning/test failed/blow down lines drain stack Pull test plug/L/D test joint nipple down bops and Katch Kan/nipple down flow line, N/D flow nipple change rams break head off annular preventer/Pull element/ Put new seals in /Put new element in/set cap in tighten down: 01/09/2011 Change rotating head/rubber line up cap line up bolt on annular. Remove potato masher. Install bell nipple. Ud potato masher and joint of DP. Test bops P/U 3-1/2 test joint m/u test plug and set,fill BOPE with H20, test BOPS test annular w 3.5 and 5.5 test joints. 250 psi low 3500psi high for 5 mins each as per AOGCC. Witness waived by Jeff Jones. L/D test tool r/d testing equipment and freeze protect. test Pump. linstall/remove wear bushing install wear ring nipple up bops install Katch-Kan. pick up BHA calibrate blocks for Schlumberger and mud logger. pick up BHA m/u bit,Xceed,ARC,Telescope, nm ils stab,Sonicvision, nm stab, 3 nm flex dc, 3 HWDP, hyd jars, 5 HWDP. t/579 test MWD tools GPM=508 psi=700 trip in hole RIH f 579- 1890' circulate and condition fill pipe/circ 550 GPM 1000psi 130 SPM/send downlink to tool trip in hole RIH f/1890-2300' trip in hole TIH log @ 900'/hr max 2313-Tag cement@ 5496'wash down f/4940- 5496 250 GPM 500 psi trip out of hole rack back stand#53/blow down td/ru head pin test hoses pressure test casing/shoe test 9 5/8 casing to 3000 psi/Pump 5 SPM 48strokes total oa press 300psi/charted 30 min/ bled down/mud weight 9.2# pressure test casing/shoe blow down/R/D test lines: 01/10/2011 Pressure test casing/shoe blow down kill and cement line. Stage trucks for displacement. Displace to oil base displace f/LSND mud t/OBM 9.1. GPM=475 psi=1470 rot and reciprocate pipe. Up=140 down=90 rot=110 rpm=50 torque=5800 cleaning rig/platform clean surface equipment and pit 7.transfer OBM f/raw mud t/pits drilling cement drilling plugs, float equip and cement f/5,511' U5,618' up=130 down=100 rot=110 GPM=385 psi=1160 WOB=2-12 rpm=40-60 torque-3800/4-5 rotary drilling f/5618 t/5648' TVD/ 34 CANRIG CC eni Gni Petroleum 0107-04 up=125/down=90/ rot=105/WOB=6-8/ GPM=610/ psi=2150/2160 rpm=110torque=4/5-6 circulate and condition CBU rot and reciprocate pipe. Rot=110 GPM=610 psi=2130 rpm=60 torque=4 pressure test casing/shoe R/U perform lot w/9.2 mud weight, pressure up 940 psi bleed off t/840psi EMW=13.6. R/d blow down. rotary drilling f/5,643't/5,841'TVD/3694 up=120 down=90 rot=105 WOB=6-8 GPM=610 psi=2150/2160 rpm=100 torque=4/5-6 ECD=10.81 bit hrs=1.15jsr hrs=73.9 SPR land 2 SPM=35/45 psi=185/270 and=5744 TVD=3696 mud weight=9.2 rotary drilling f/5841'-7245(3761 TVD)5-15k WOB 144 SPM/610 GPM 2230 psi on 2240 psi off/7000k torque on 6200k torque off/128k up 82k down 105k rot/mud weight 9.2/10.7 ECD SPR @ 6504(3705TVD)35/45 strokes#1 200/285#3 200/285 SPR @ 7175(3754TVD)35/45 strokes#1 190/250#3 190/260 adt 6.2 jars 80.1: 01/11/2011 Rotary drilling f/7,245' t/8611 TVD/3861 up=145 down=75 rot=105 WOB=8-12 GPM=610 psi=2440/2470 rpm=120 torque=6900/9000 ECD=11.35 bit hrs=8 jar hrs=88.1 SPR land3 SPM=35/45 psi=270/350, 265/350 and=8328 TVD=3853 mud weight=9.2 no losses of mud on this tour. rotary drilling f/ 8611 -9765(3863TVD)WOB 5-20k/144 SPM/610 GPM/2580 psi on ,2570 psi off/8600 torque on 7800 torque off/135k up, 70k down, 104k rot/120 rpm/ECD 11.4 mud weight 9.4 SPR @ 9091(3860 TVD)mud weight 9.4#35/45 SPM#1 300/380#3 290/380 adt 8.11 jars 96.2: 01/12/2011 Rotary drilling 1/9,765' t/10,914' TVD/3901 up=148 down=60 rot=100 WOB=8-12 GPM=610 psi=2800/2820 rpm=120 torque=8400/9000 ECD=11.71 SPR land3 SPM=35/45 psi=335/440 md=10,434' TVD=3,874'mud weight=9.4 bit hrs=8.36 jar hrs=104.5 rotary drilling f/10914(3901 TVD)-12254(3922)WOB 4-20k/144 SPM/2950 psi on 2940 off/l l k torque on,8900 torque off/145k up,48k down 103k rot/80-120 rpm / 11.76 ECD 9.4 mud weight SPR @ 11101(3906TVD) 35/45 #1 350/450 #2 360/450 SPR @ 11871(3908TVD)35/45#1 360/480#2 370/480 adt 7.62 jars 112.1 jars 13: 01/13/2011 Rotary drilling 1/12,254' t/12,325' TVD/3,925' up=150 down=could not slide down. rot=103 WOB=8-20 ECD=11.71 GPM=610 psi=3000/3020 rpm=120 torque=9000/11,200' bit hrs=.66 jar hrs=112.8 SPR land 2 SPM=35/45 psi=360/450 350/450 md=12,325' TVD=3,925' mud weight=9.4 sv two feet off bottom. Strap last stand out, circulate and condition CBU 1-1/2x stand one stand back. CBU 6 x's standing one stand back every bu. Rot and reciprocate up=145 down=55 rot=104 rpm=140/120 torque=11,300/8900 GPM=610 psi=2800 ECD=11.40 1/12,325't/11,680' monitor well f/10 mins static back reaming back ream 1/11,680't/9191 up=130 down=70 rot=100 GPM=610 psi=2400 rpm=120 torque=7100 ECD=10.99 SLM out total losses for tour 21 BBLS back reaming f/ 9191 - 7630(3783TVD) 610 GPM / 144 SPM 2220psi 6200 torque back ream slow thru shale 8367-7788 125k up 80k down 100k rot mud weight 9.4 ECD 10.89 fluid losses 50 BBLS: 01/14/2011 Back reaming back ream 1/7,630't/5,554'up=118 down=92 rot=104GPM=610 psi=1920 rpm=120 torque=4800 ECD=10.90 packing off @ 1/6960' t/6952' f/6485' t/6475' circulate and condition CBU 4x up inside 9-5/8 shoe and=5554'rot and Reciprocate, up=118 down=92 rot=104 rpm=80 torque=4500 GPM=610 psi=1880, back reaming back ream, 1/5,554' t/3927 ' up=115 down=105 rot=110 rpm=80 torque=3000 GPM=610 psi=1680 back reaming f 3927' -3640 144 SPM 610 GPM 1650 psi 2700 torque 115k up 110k down 110 rot circulate and condition monitor well for flow/Pump dry job trip out of hole pooh from 3640'- 480 115k up 110k down SLM DP, lay down BHA, stand back HWDP,jars, non mag flex collars/bo Id sonic, nm stab , Telescope,ARC,Xceed, 8.5 bit pick up BHA clean up rig floor/swap out BHA/change out saver sub pick up BHA mu bit sub/hole opener to stand of flex collars/RIH w/HWDP,jars trip in hole RIH to 5453' fill pipe every 25 stands 110k up 90k down 22:30 00:00 1.50 9.a cut drilling line cut / slip 45' service drawworks service td blocks/crown: 01/15/2011 Trip in hole on elev. 1/5452' 12,325'bottom. Encountered no tight spots, proper displ. Fill pipe every 20 stands. 90-80k-dwn-weight, circulate and condition circ and reciprocate pipe. 600GPM 2400psi 120rpm 8.6k-torque till shakers clean, per mi and kandm rep.circ 300GPM 60rpm 800psi 9.4ppg in/out.Wait on 9.5ppg Faze away mud/trucks. Prep 5.5 liner w/swell packers in shed. Prep active pits for displacement. circulate and condition rot reciprocate pipe/60 rpm8400k torque/ 120k rot76 SPM 322 GPM wait on faze away breaker fluid displace to completion fluid spot faze away breaker fluidity 9.5# Pump 510 BBLS/262 GPM 60 SPM 480 psi/rec rot 60 rpm 118k rot 9.4k torque when fluid out bit/Pump 60 BBLS faze pro 9.4# same parameters/Pump 11.4#dry job/monitor well trip out of hole 12325-5600 pooh to intermediate shoe 35 CANRIG Vai Levi Eni Petroleum 0107-04 1 min per stand Pulling speed 165k up 80k down/monitor well @ shoe trip out of hole continue to pooh from 5600-2294 98k up: 01/16/2011 Trip out of hole pooh f/2294't/382'losing 6bph, lay down BHA, rack back HWDP/jar.Lid 3 flex d/c bit sub, hole opener. Rig up/down to run casing PJSM. P/U R/U GBR liner running equip. tongs, slips, elevators, torque turn equip. per GBR. Pre job safety PJSM running torque turn 5.5 slotted liner. Run liner RIH w/5.5 17#1-80 slotted liner and swell packers per program.t/2448'losing 3-5bph. run liner RIH w/5.517# Hydril 521 liner f/2488-6912' m/u liner setting sleeve mu liner hanger fill w/pal mix/wait 30 min for mix to set up 112k up 90k down / rig down GBR casing equipment trip in hole RIH w/5.5 17# Hydril 521 liner, liner hanger on 5"DP. Pump 50 strokes on stand#1 43 SPM down 102k rot 2,600 torque get rot weights,torque values every 5 stands fill pipe every 10 stands. 01/17/2011 Trip in hole with 5.5"f/10,300'liner to 12200'taking weight. Reaming/washing kelly up and ream in hole from 12200'to bottom at 12325'tag same, pick up to 12313' setting depth. Rotate weight=122k, so weight=112k, rpm=25, torque=9500 ft/lbs, circulate and condition circ. drill pipe volume + (100 BBLS) at 5 BPM with 400 psi to ensure flow path free. Circulate and condition drop ball and Pump down at 6 BPM(for 63 BBLS-500 psi)slow Pump to 2 BPM(225 psi)and land ball in seat. psi up to 3000 and slack off to 70k,psi up to 4000, bleed off to zero. Close annular and pressure up annulus to 1500 and hold for 10 minutes (chart record same)-ok. Bleed off pressure up to 400 psi and pull stinger out, psi dropped to zero-ok. lay down 2 singles DP. Set t.o.l @ 5372'and 12,313-shoe depth. Displace to water base prepare to displace cased hole over to 9.0 ppg inhibited brine.circ 7BPM 400psi 30rpm reciprocating pipe till 9.0 brine surf/surf 360BBLS per mud man. monitor hole 10min-static. .f lay down drill pipe 1/d drill pipe, proper hole fill. 123joints I/d lay down drill pipe f/ 1500-surface Id 46 joints 5" DP/LD liner setting tool service top drive trip in hole to 4400'w/5" HWDP,jars/43 stands from derrick 125k up/110k down f lay down drill pipe f/4400-278'LD 129 joints DP trip in hole RIH w/30 stands DP from derrick on top of HWDP RIH to 3128'110k up 100k down lay down drill pipe LD f 3128-2650 LD 15 joints.: 36 CANRIG liiii eni Eni Petroleum 0107-04 5.2 Survey Data Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+), S(-) E(+),W(-) (°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 113.26 0.11 344.78 113.26 0.10 0.10 -0.03 0.10 171.41 0.22 354.40 171.41 0.27 0.27 -0.05 0.19 263.16 0.24 336.73 263.16 0.62 0.62 -0.15 0.08 362.32 0.21 333.48 362.32 0.97 0.97 -0.31 0.03 455.02 0.34 357.19 455.02 1.39 1.40 -0.40 0.18 546.98 2.32 47.59 546.95 2.94 2.92 0.96 2.31 639.64 4.68 48.71 639.43 6.77 6.69 5.19 2.55 734.15 7.49 53.28 733.39 13.14 12.91 13.02 3.01 829.39 8.86 56.06 827.67 21.13 20.72 24.08 1.50 891.10 10.60 59.04 888.49 26.86 26.29 32.89 2.93 987.55 13.18 59.18 982.86 37.36 36.49 49.94 2.68 1081.36 15.15 59.37 1073.82 49.42 48.22 69.68 2.10 1177.35 18.49 58.26 1165.69 64.24 62.62 93.42 3.50 1272.64 20.34 57.32 1255.55 81.60 79.51 120.21 1.97 1368.18 22.33 56.77 1344.54 101.02 98.42 149.38 2.09 1462.49 23.09 55.68 1431.54 121.79 118.67 179.64 0.92 1559.76 21.87 55.53 1521.42 143.33 139.68 210.33 1.26 1655.47 23.89 53.28 1609.59 165.53 161.36 240.56 2.30 1750.65 24.75 53.69 1696.33 189.40 184.68 272.06 0.92 1847.92 24.40 54.37 1784.79 213.73 208.44 304.80 0.46 1943.45 25.30 57.00 1871.47 236.92 231.05 337.96 1.49 2039.10 27.67 57.57 1957.08 260.58 254.10 373.85 2.49 2135.98 31.81 57.83 2041.18 286.96 279.77 414.47 4.28 2230.78 32.20 58.13 2121.57 314.34 306.41 457.07 0.44 2350.77 35.01 55.00 2221.50 351.93 343.04 512.43 2.75 2405.36 35.44 53.36 2266.10 370.80 361.47 537.96 1.90 2500.59 35.94 47.27 2343.47 406.99 396.92 580.66 3.77 2595.71 36.09 41.35 2420.43 447.65 436.90 619.68 3.66 2691.67 35.72 35.19 2498.18 492.38 481.03 654.51 3.78 2787.74 37.89 28.99 2575.13 541.65 529.77 684.98 4.48 2882.88 40.22 24.86 2649.01 595.55 583.22 712.06 3.67 2980.47 41.82 21.20 2722.65 654.92 642.15 737.08 2.96 3075.87 43.43 19.45 2792.85 715.88 702.73 759.50 2.10 3171.07 44.33 18.09 2861.47 778.72 765.21 780.73 1.37 3266.74 45.88 17.53 2928.99 843.59 829.73 801.45 1.67 3361.46 48.41 16.04 2993.41 910.41 896.21 821.49 2.91 3457.61 51.26 15.31 3055.42 981.48 966.95 841.33 3.02 3553.79 53.20 14.63 3114.33 1055.26 1040.39 860.96 2.09 37 CANRIG Irai leni_Eni Petroleum 0107-04 Surveys(continueinued) Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+),S(-) E(+),W(-) (°/100ft) 3649.68 55.17 14.19 3170.44 1130.89 1115.70 880.30 2.09 3744.61 56.00 14.49 3224.09 1207.09 1191.57 899.70 0.91 3840.89 57.01 14.01 3277.22 1285.25 1269.39 919.46 1.13 3935.95 58.01 13.73 3328.29 1363.41 1347.23 938.68 1.08 4031.17 63.16 12.58 3375.04 1444.47 1427.98 957.53 5.51 4128.10 69.56 12.17 3413.88 1531.48 1514.67 976.54 6.61 4225.02 71.70 11.43 3446.03 1621.29 1604.16 995.24 2.32 4320.37 72.28 11.36 3475.51 1710.48 1693.05 1013.15 0.61 4414.37 73.07 11.23 3503.50 1798.77 1781.05 1030.73 0.85 4509.91 73.87 10.99 3530.68 1888.94 1870.93 1048.38 0.87 4606.18 75.00 10.39 3556.51 1980.35 1962.05 1065.58 1.32 4702.28 77.47 8.19 3579.38 2072.70 2054.16 1080.63 3.40 4796.98 80.88 5.53 3597.17 2165.21 2146.49 1091.73 4.54 4893.60 84.27 3.76 3609.65 2260.81 2241.96 1099.48 3.95 4988.09 85.65 4.70 3617.95 2354.78 2335.83 1106.42 1.76 5083.88 84.68 5.44 3626.03 2449.99 2430.90 1114.86 1.27 5181.14 84.48 6.42 3635.21 2546.45 2527.21 1124.86 1.02 5276.30 84.82 7.69 3644.09 2640.67 2621.23 1136.50 1.38 5371.98 84.04 7.73 3653.37 2735.24 2715.60 1149.27 0.82 5467.90 83.38 7.98 3663.88 2829.90 2810.05 1162.30 0.74 5547.58 83.16 7.15 3673.22 2908.52 2888.49 1172.72 1.07 5681.40 86.63 6.73 3685.13 3041.07 3020.78 1188.82 5681.40 5776.81 89.54 7.68 3688.32 3135.86 3115.37 1200.78 5776.81 5872.13 88.18 5.50 3690.21 3230.70 3210.04 1211.72 5872.13 5968.43 88.26 3.81 3693.20 3326.75 3305.97 1219.53 5968.43 6064.46 88.26 1.88 3696.12 3422.68 3401.83 1224.29 6064.46 6159.49 88.17 1.64 3699.08 3517.66 3496.77 1227.21 6159.49 6255.95 88.09 358.26 3702.23 3614.04 3593.17 1227.13 6255.95 6351.98 89.37 356.57 3704.36 3709.85 3689.07 1222.80 6351.98 6446.91 88.62 355.90 3706.02 3804.43 3783.78 1216.56 6446.91 6542.61 88.79 357.51 3708.18 3899.84 3879.29 1211.07 6542.61 6638.17 86.03 357.25 3712.50 3995.10 3974.65 1206.70 6638.17 6734.90 85.89 358.60 3719.32 4091.45 4071.07 1203.21 6734.90 6829.16 85.70 2.38 3726.23 4185.43 4165.06 1204.01 6829.16 6924.48 84.18 2.27 3734.64 4280.35 4259.92 1207.86 6924.48 7020.17 84.06 1.28 3744.44 4375.53 4355.06 1210.81 7020.17 7115.66 84.88 358.93 3753.65 4470.56 4450.10 1210.99 7115.66 7212.02 87.08 359.21 3760.40 4566.62 4546.21 1209.43 7212.02 7307.58 86.95 359.22 3765.38 4662.00 4641.63 1208.12 7307.58 7403.51 86.42 359.45 3770.92 4757.73 4737.39 1207.01 7403.51 38 CANRIG tglot eni Ertl Petroleum 0107-04 Surveys(continued) Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+), S(-) E(+),W(-) (°/100ft) 7403.51 86.42 359.45 __3770.92 4757.73 4737.39 1207.01 0.60 7498.87 86.44 2.51 3776.86 4852.90 4832.54 1208.63 3.20 7595.66 85.78 2.77 3783.43 4949.42 4929.00 1213.08 0.73 7691.33 87.91 2.26 3788.69 5044.91 5024.43 1217.27 2.29 7786.25 87.70 0.17 3792.33 5139.75 5119.25 1219.28 2.21 7881.86 85.28 357.91 3798.18 5235.12 5214.66 1217.69 3.46 7977.92 83.85 356.42 3807.28 5330.52 5310.16 1212.96 2.14 8073.46 82.78 356.38 3818.40 5425.11 5404.87 1207.00 1.12 8169.64 83.96 355.74 3829.51 5520.29 5500.17 1200.44 1.39 8265.26 84.84 356.65 3838.84 5615.11 5595.13 1194.12 1.32 8360.74 84.30 357.45 3847.88 5709.94 5690.05 1189.23 1.01 8457.55 87.67 359.99 3854.65 5806.41 5786.58 1187.08 4.35 8552.43 87.20 359.91 3858.90 5901.18 5881.36 1187.00 0.50 8648.76 90.02 1.38 3861.24 5997.47 5977.64 1188.08 3.30 8744.22 90.26 0.88 3861.00 6092.93 6073.09 1189.96 0.58 8839.96 90.06 359.51 3860.74 6188.66 6168.82 1190.29 1.45 8935.35 89.92 358.81 3860.75 6284.00 6264.20 1188.89 0.75 9031.48 91.10 358.33 3859.90 6380.03 6360.30 1186.49 1.33 9126.85 90.89 358.93 3858.24 6475.31 6455.62 1184.21 0.67 9222.66 88.91 358.62 3858.41 6571.04 6551.41 1182.16 2.09 9318.57 89.54 0.02 3859.71 6666.90 6647.30 1181.03 1.60 9413.81 89.86 2.52 3860.20 6762.13 6742.51 1183.14 2.65 9509.48 88.22 2.09 3861.81 6857.76 6838.08 1186.98 1.77 9605.31 89.74 2.24 3863.51 6953.55 6933.83 1190.60 1.59 9701.25 90.73 2.32 3863.12 7049.46 7029.69 1194.42 1.04 9796.92 90.42 0.95 3862.16 7145.12 7125.31 1197.15 1.47 9892.04 90.89 0.09 3861.07 7240.23 7220.42 1198.01 1.03 9988.13 91.05 3.41 3859.44 7336.28 7316.44 1200.95 3.46 10084.95 89.68 3.37 3858.83 7433.01 7413.08 1206.67 1.42 10179.95 87.77 2.86 3860.94 7527.92 7507.92 1211.83 2.08 10274.66 86.80 1.99 3865.43 7622.49 7602.43 1215.83 1.38 10371.56 86.15 3.09 3871.39 7719.17 7699.05 1220.12 1.32 10466.69 86.86 3.32 3877.19 7814.06 7793.86 1225.43 0.78 10562.70 87.17 4.09 3882.19 7909.83 7889.53 1231.62 0.86 10659.26 87.18 2.60 3886.94 8006.19 7985.81 1237.25 1.54 10754.21 86.63 3.47 3892.07 8100.94 8080.49 1242.27 1.08 10849.63 88.06 3.75 3896.49 8196.15 8175.61 1248.27 1.53 10945.80 86.73 3.69 3900.86 8292.11 8271.48 1254.51 1.38 39 CANRIG iiit eni Eni Petroleum 0107-04 11041.80 89.81 3.33 3903.76 8387.97 8367.24 _ 1260.38 3.23 11137.70 90.72 3.16 3903.32 8483.79 8462.99 1265.81 0.97 Surveys(continued) Measured Inclination Azimuth True Vertical Latitude Departure Dogleg Depth Vertical Section (ft) (ft) Rate (ft) (deg) (deg) Depth (ft) (ft) N(+), S(-) E(+),W(-) (°/100ft) 11232.80 92.70 3.12 3900.48 8578.78 8557.90 1271.01 2.08 11328.50 91.39 0.82 3897.06 8674.39 8653.47 1274.30 2.76 11424.20 89.72 358.51 3896.14 8770.05 8749.16 1273.74 2.98 11520.00 88.04 358.25 3898.01 8865.73 8844.90 1271.03 1.77 11616.01 87.82 358.31 3901.48 8961.57 8940.80 1268.15 0.24 11712.41 88.20 358.26 3904.82 9057.80 9037.10 1265.27 0.40 11807.53 88.65 358.02 3907.44 9152.77 9132.13 1262.18 0.54 11902.72 87.56 357.83 3910.59 9247.77 9227.21 1258.74 1.16 11998.66 87.66 356.99 3914.59 9343.44 9322.96 1254.41 0.88 12094.45 87.73 356.64 3918.44 9438.89 9418.53 1249.09 0.37 12190.66 88.46 357.37 3921.64 9534.82 9514.55 1244.07 1.07 12262.28 88.81 357.31 3923.34 9606.27 9586.08 1240.74 0.50 12325.00 88.81 357.31 3924.65 9668.85 9648.71 1237.80 0.00 40 CANRIG . . . . . . . . . . . . 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ENI Petroleum OI-11-01 Nikaitchuq,Oliktok Point,Alaska DEPTH INTERVAL: 6243 TO 12325 (MD) TOTAL FTG: 6082 3648.4 TO 3871.3 {TVD) BIT INFORMATION: BIT TYPE- Hycalog RST616M-F8 AVERAGES: BEFORE DURING AFTER Average Maximum ROP(fph) 135.4 230.2 545.2 n/a WOB 6.2 5.8 22.3 n/a RPM 96.9 113.8 123.7 n/a MUD WT 9.2 9.3 9.45 n/a CHLORIDE n/a TOTAL GAS 171.3 268.1 815.5 n/a Cl (ppm) 28862.9 50985.5 155438.4 n/a C2(ppm) 240.7 340.2 2948.2 n/a C3(ppm) 173.1 85.4 3686.2 n/a C4(ppm) 87.4 58.8 3214.3 n/a C5(ppm) 102.6 62.2 374.7 n/a RATIO ROP INCREASE TO GAS INCREASE: 409/644 SAMPLE CUTTINGS FLUORESENCE%: COLOR INTENSITY: CUT: MUD FLUORESCENCE: FORMATION DESCRIPTION: SHOW RATING: (T,P,F,G) LOGGING GEOLOGIST(S): John Lundy; Emil Opits ENI Petroleum DAILY WELLSITE REPORT CANRIG 01 07-04 REPORT FOR Cormier/Beauchamp/Buchanan DATE December 26,2010 DEPTH 0 PRESENT OPERATION Prep Rig Floor to Pick Up Drill Pipe TIME 24:00:00 YESTERDAY 0 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MW NO FLUID VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY MOBILIZATION MOVE AND SPOT DRILL MODUAL OVER HOLE CENTER&SET DWN ON MATS,SHIM/LEVEL RIG.PLACE MATS IN-LINE FOR ULTILITY MODUAL.MOVE AND MATE UP ULTILITY MODUAL,SHIM/LEVEL.SET DWN ON MATS.MOBILIZATION BURM AROUND RIG.R/U DE-GASSER AND FLOWLINES SAME.R/U INNERCONNECTS SAME.PUTSTEAM AND AIR ON-LINE THROUGH OUT RIG. SECURE WALKWAYS/DOORWAYS.LOWER CELLAR BOX AND CURTAINS.SECURE LAMPSON CURTAINS.ASSEMBLE MUD PUMPS DAILY CAPSNALVES.NU RISER AND SPACER SPOOLS INSTALL RISER/PITCHER NIPPLE RISER IN SHED.P/U VETCO STARTING HEAD. ACTIVITY LOWER TO WELLBAY FOR PREP AND SET ON CONDUCTOR.INSTALL RISER AND FLOWLINE N/U RISER AND FLOW LINE.TEST UPPER SUMMARY AND LOWER WELL HEAD SEALS T/500PSI(VETCO REP)INSTALL HOLE FILL AND BLEEDER LINES.INSTALL ALUMINUM HATCH AND DRIP LINER AROUND RISER.INSTALL CATCH CAN AND CURTAIN AROUND RISER.RINSE OUT MUD PITS,PREP F/BUILDING SPUD MUD.CALIBRATE AND TEST GAS ALARMS.RIG UP ASSIST SPOTTING CCB AND CUTTINGS TANK.THAW OUT CUTTINGS TANK AND HEAT COIL.SERVICE TOP DRIVE,CROWN AND BLOCK SHEAVES,DRAWWORKS.LOAD PIPE SHED WITH DRILL PIPE.CALIBRATE CANRIG BLOCK HEIGHT.HANG RIG TONGS.INSTALL ELEVATORS.INSTALL MOUSEHOLE IN R.T.PREP RIG FLOOR F/P/U D.P. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML$2180, RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANRIG 01 07-04 REPORT FOR Cormier/Beauchamp/Buchanan DATE December 27,2010 DEPTH 0 PRESENT OPERATION PREPING FOR WELL TIME 24:00:00 YESTERDAY 0 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MW NO MUD REPORT VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY PICK UP DRILL PIPE FINISH LOADING AND STRAPPING 5"D.P PICK UP DRILL PIPE P/U 189 JTS 5"D.P M/U IN MOUSE HOLE.RACK DAILY STDS BACK IN DRK.DRIFTING EVERY JT.MIX 300BBLS SPUD MUD.LOAD PIPESHED W/14 JTS 5"HWDP&JAR,STRAP.PICK UP ACTIVITY DRILL PIPE P/U AND RACK BK 5"HWDP.TAG BTM @ 103'BUILD VOLUME WEIGHT FINISH BUILDING SPUD MUD-690BBLS.8.7PPG VIS SUMMARY 138 CONT.THAWING OUT CUTTINGS TANK.CONT R/U CCB.LOAD 57JTS 13 3/8 CSG IN SHED.LOAD BHA IN SHED.PREP RIG FLOOR TOOLS F/P/U BHA.RIG UP CONT.R/U CCB AND THAWING OUT CUTTINGS TANK.REPAIR BLOWER ON#4SCR.P/U AND STD BACK JARS/HWDP.P/U SMALL BHA ITEMS AND STAGE ON FLOOR. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$2980, RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANRIG 01 07-04 REPORT FOR Cormier/Beauchamp/Buchanan DATE December 28,2010 DEPTH 0 PRESENT OPERATION Waiting on weather TIME 24:00:00 YESTERDAY 0 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MW NO MUD REPORT VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY PICK UP BHA P/U LIFT SUBS,STAB STAGE ON DRILL FLOOR.P/U D/C RACK BACK.WORKING AS DIRECTED BY OPERATOR FINISH BURMING AND SECURING CCB MODUALS.OFF LOAD HOT H2O IN RAW MUD PITS TO THAW.STEAM/THAW SLOP TANK.PICK UP BHA P/U/M/U BHA#1.1.83 MOTOR,16"BIT,XO,HWDP.WORKING AS DIRECTED BY OPERATOR THAW CUTTINGS TANK.CK VENTS TO ALL RIG TANKS,ENSURING NO ICE PLUGS.SECURE CURTAINS AROUND LAMPSONS.WORKING AS DIRECTED BY OPERATOR FILL HOLE, DAILY ACTIVITY CHECKING FOR LEAKS.CIRC ACROSS THE TOP OF HOLE,NO LEAKS.CONTINUE THAWING/EMPTYING SLOP TANK.CONT R/U LINES SUMMARY F/CCB T/G&I UNIT.PER SWACO REPS.RIG UP CONT T/THAW OUT CUTTINGS TANK AND R/U CCB.CALIBRATE SCHLUMBERGER BLOCK HEIGHT.CUT DRILLING LINE CUT N SLIP 75'DRLG LINE RIG UP CONT.R/U CCB AND CUTTINGS TANK.PROCESS\13 3/8 CSG. SET AND TEST CROWN 0 MATIC.CALIBRATE CANRIG AND SCHLUMBERGER BLOCK HEIGHT RIG UP CONT.R/U CCB.CLEAN SUCTION SCREENS ON#1 AND#2MP'S.CHANGE OIL IN#1 GENERATOR.REPLACE BAD HOSE ON VAC SYSTEM.C/O JERK LINES ON M/U AND B/O CATHEADS. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$2845, RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANING 01 07-04 REPORT FOR Cormier/Beauchamp/Buchanan DATE Dec 29,2010 DEPTH 506 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 160 24 HOUR FOOTAGE 346 CASING INFORMATION 20"@ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 455.02 0.34 357.19 455.02 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" HUGHES MX1 MILLTOOTH 6080470 1X16 3X20 160 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 327.9 © 162 24.3 @ 164 139.1 51.26 FT/HR SURFACE TORQUE 3248 @ 473 637 @ 306 1731.2 0.00 AMPS WEIGHT ON BIT 29 @ 502 -11 @ 161 10.5 19.57 KLBS ROTARY RPM 44 @ 316 0 @ 410 34.9 0.00 RPM PUMP PRESSURE 786 @ 495 12 @ 163 605.1 683.53 PSI DRILLING FLUIDS REPORT DEPTH MW 8.8 VIS 107 PV 32 YP 20 FL 8 Gels 15/22/30 CL- 1300 FC 2/- SOL 3.5 SD - OIL /97 MBT 21 pH 9.4 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 0 @ 506 0 @ 506 0.0 TRIP GAS 0 CUTTING GAS 0 @ 506 0 @ 506 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 0 @ 506 0 @ 506 0.0 CONNECTION GAS HIGH 0 ETHANE(C-2) 0 @ 506 0 @ 506 0.0 AVG 0 PROPANE(C-3) 0 @ 506 0 @ 506 0.0 CURRENT 0 BUTANE(C-4) 0 @ 506 0 @ 506 0.0 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 0 @ 506 0 @ 506 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY WORKING AS DIRECTED BY OPERATOR PULL MOTOR OOH,LINES.-42 WEATHER,STANDING BY.REAMING/WASHING P/U M/U MUD MOTOR,STD HWDP.CLEAN OUT CONDUCTOR T/160'450GPM 300PSI 1K-TIO 25RPM.PUH T/MOTOR.WAITING ON WEATHER STAND DAILY BY DUE TO COLD WEATHER-43°.CCB CONT TO RUN HEAT TRACE LINES PER MI-SWACO.RIG UP CONT.R/U CCB LINES.FINISH ACTIVITY CONTAINMENT AROUND CCB AND CUTTINGS TANK AREA.FINISH DRIFTING AND STRAPPING CASING.REPAIR GENERATOR AT THE SUMMARY WIF.PRESPUD MEETING.PICK UP BHA CIRCULATE AND CONDITION BRING ON PUMPS.CK CIRC SYSTEM,CUTTINGS TANK ETC, SHALLOW TEST MWD/GYRO PULSE,TAKE SURVEY ROTARY DRILLING F/160'T/505'UP WT 80 DN WT 80 ROT WT 80 40RPM TQ 3/2 WOB 15-25K 516GPM 690PS1 ON 550PS1 OFF MWT 8.9 ECD 9.05 BHA WT @ JARS 70K.ART 2.35 AST.32 JARS 2.7. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3045, RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANRIG 01 07-04 REPORT FOR Cormier/Beauchamp/Buchanan DATE Dec 30,2010 DEPTH 1850 PRESENT OPERATION DRILLING AHEAD TIME 24:00:00 YESTERDAY 506 24 HOUR FOOTAGE 1344 CASING INFORMATION 20"@160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1750.65 24.60 54.09 1696.85 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" HUGHES MX1 MILLTOOTH 6080470 1x16 3x20 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 506.6 @ 1359 41.9 @ 619 129.8 251.96892 FT/HR SURFACE TORQUE 13671 @ 1098 0 @ 1041 1472.3 0.00000 AMPS WEIGHT ON BIT 38 @ 685 0 @ 1063 17.9 23.67940 KLBS ROTARY RPM 48 @ 1236 0 @ 882 17.9 0.00000 RPM PUMP PRESSURE 1378 @ 1742 542 @ 687 863.4 0.00000 PSI DRILLING FLUIDS REPORT DEPTH MW 9.1 VIS 94 PV 23 YP 20 FL 7.5 Gels 19/33/44 CL- 2300 FC 2/NA SOL 4.5 SD - OIL /96 MBT 24 pH 9.1 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 310 @ 1580 0 @ 965 61.5 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 64711 @ 1580 0 @ 965 11548.5 CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 61.5 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 20 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION SAND=MEDIUM DARK GRAY TO DARK GRAY,SALT AND PEPPER APPEARANCE,OLIVE GRAY SUB HUES;UPPER VERY FINE TO LOWER FINE GRAINED;SPHERICAL TO SUB DISCOIDAL;ANGULAR TO SUB ROUNDED;UNCONSOLIDATED SAND;GRAIN LITHOLOGY SUPPORTED;IMMATURE COMPOSITIONALLY;IMMATURE TEXTURALLY;TRANSLUCENT AND MILKY WHITE QUARTZ;PALE YELLOWISH ORANGE LITHICS,BLACK AND GRAYISH BLACK LITHICS,PYRITE,LIGHT GREEN LITHICS;LIGHT GRAY CLAY, COHESIVE,CLUMPY,STIFF TENACITY,EARTHY LUSTER,CLAYEY TEXTURE;POROSITY AND PERMEABILITY VISUALLY GOOD;NO OIL. PRESENT SAND 100% LITHOLOGY - SLIDE DRILLING CYCLING PUMPS FOR GYRO SURVEY PER GYRO REP.DRLG.SLIDING/ROTATING F/505'T/1185'@500GPM 12OSPM DAILY 750PSI-ON 700PSI-OFF 40RPM 3500TQ-ON1000TQ-OFF 85UP-WT 85DWN-WT 85ROT-WT 15-25K-WOB GYRO SURVEY EVERY ACTIVITY CONNECTION.ADT-7.87HRS AST-5.14HRS ART-2.73HRS.ROTARY DRILLING F/1185'T/1849'UP WT 105 DN WT 100 ROT WT 102 SUMMARY 40RPM TO 5/3 WOB 10-30K 635GPM 1225PSI ON 1110PSI OFF.MWT 9.3PPG ECD 9.89.ART 2.63 AST 2.60 JARS 15.8.TRIP OUT OF HOLE POOH T/1738'B/D TD R/U CMT HOSE T/CIRC.DOWNTIME-TOP DRIVE TROUBLESHOOT TD,LOOSE WIRE ON ENCODER, RECONNECT WIRE,FUNCTION TEST TOP DRIVE,WORKING PROPERLY.REPLACE GUARD AND SAFETY WIRE. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$2980, RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANS 0I 07-0a REPORT FOR Cormier/Smith/Buchanan DATE Dec 31,2010 DEPTH 2330 PRESENT OPERATION Running Casing TIME 24:00:00 YESTERDAY 1850 24 HOUR FOOTAGE 480 CASING INFORMATION 20"@ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2230.78 32.20 58.13 2121.57 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 16" HUGHES MX1 MILLTOOTH 6080470 1x163x20 160 2330 2170 19.1 1-1-WT-A-E-IN-NO-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 1107.0 @ 1851 69.7 @ 2041 179.7 155.27527 FT/HR SURFACE TORQUE 13028 @ 2299 1978 @ 1861 2317.4 4119.88770 AMPS WEIGHT ON BIT 28 @ 2319 0 @ 2082 13.2 24.84097 KLBS ROTARY RPM 44 @ 21770 @ 2135 24.5 38.66217 RPM PUMP PRESSURE 1525 @ 2317 1078 @ 1916 1262.8 1455.89197 PSI DRILLING FLUIDS REPORT DEPTH 2330/2206 MW 9.3 VIS 111 PV 21 YP 22 FL 7.1 Gels 21/32/43 CL- 2300 FC 2/NA SOL 5.5 SD - OIL 28/9 MBT 28 pH 9.0 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 93 @ 1862 16 @ 1850 54.0 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 18566 @ 1862 3042 @ 1850 10681.2 CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 54 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SANDSTONE 40%,CONGLOMERATE SANDSTONE 20%,SAND 30%,CLAYSTONE 10%. SAND/SANDSTONE=MEDIUM TO MEDIUM DARK GRAY;SAMPLES COLLECTED AS LOOSE DIS-AGGREGATED SAND WITH SCATTERED TO COMMON LOOSELY INDURATED SANDSTONE FRAGMENTS;WELL TO MODERATELY WELL SORTED;FINE UPPER TO FINE LOWER AND VERY FINE UPPER GRAIN IN THE UPPER PART OF THE ZONE;SCATTERED PRESENT TO ABUNDANT MEDIUM AND COARSE LOWED AT THE BASE;ANGULAR TO SUB-ANGULAR;TRACE SUB SPHEROIDAL;ABOUT EVENLY DIVIDED BETWEEN TRANSLUCENT WHITE LITHOLOGY TO CLEAR COLORLESS QUARTZ AND MEDIUM LIGHT TO MEDIUM GRAY,DARK GRAY AND BLACK LITHICS;TRACE TO COMMON PYRITIC BLACK LITHICS;TRACE PALE BLUE MINERAL GRAINS AND SCATTERED MOTTLED YELLOW/BLACK AND ORANGE-RED JASPER;PRIMARILY GRAIN SUPPORTED;TRACE REMNANT SILICA CEMENT OVERGROWTH FROSTING;SOME LOCALLY MATRIX SUPPORTED IN CLEAN LIGHT BROWNISH GRAY CLAY;MATRIX SUPPORT BECOMES DOMINANT WITH DEPTH;TRACE CALCAREOUS;INTERBEDDED WITH THIN SANDY TO CLEAN LIGHT BROWNISH GRAY CLAY;NO STAIN,ODOR,FLUORESCENCE OR CUT(NSOFC). SLIDE DRILLING DRLG F/1849'T/2185'650GPM 150SPM 1200PSI-ON 1150PSI-OFF 40RPM 3.4K-TQ-ON 2-3K-TO-OFF 15-25WOB 105UP-WT 100DWN-WT 100ROT-WT SLIDING AN ROTATING ON OCCATION PER DD.WASHING 30'UP/DWN BEFORE CONN.DOWNTIME-TOP DRIVE ELECTRICIAN C/O TOPDRIVE ENCODER.CIRC THROUGH CIRC HOSE 2BPM DAILY 140PSI.ROTARY DRILLING CONT DRLG F/2185'T/2330'T.D 650GPM 150SPM 1250PSI-ON 1150PSI-OFF 3K-TO-OFF 3.5-TO-ON 110UP-WT 105DWN-WT 103ROT-WT 40RPM BACK ACTIVITY REAMING 30'UP/DWN ADT-3.32 AST-1.35 ART-1.97 9.1 PPG 9.92ECD 2206TVD CIRCULATE AND CONDITION CBU+3 TIMES&PUMP 4OBBL HI-VIS SWEEP @ 650GPM 150SPM 1170PSI SUMMARY 40RPM 2800T0 RECIPROCATING PIPE TILL SHAKERS CLEAN PER MUD MAN.BACK REAMING BACK REAMING F/2330'T/2025'635GPM 40RPM 1050PSI 2.5-4.5T0 TRIP OUT OF HOLE BACK REAM OUT F/2025'T/585'(HWDP)50 RPM 635GPM.CIRCULATE AND CONDITION CIRC HOLE CLEAN.600-700GPM.TRIP OUT OF HOLE T/BHA LAY DOWN BHA RACK BACK JARS AND COLLARS.L/D BHA.CLEAN RIG FLOOR.RIG UP/DOWN TO RUN CASING DUMMY RUN 13 3/8 HANGER,VERIFIED BY VETCO REP,RIG UP/DOWN TO RUN CASING R/U T/ RUN CASING. CANRIG PERSONNEL ON BOARD 4 DAILY COST RIGWATCH$2,980, DML$1,450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANRIG 0107-0a � REPORT FOR Cormier/Smith/Buchanan DATE Jan 1,2011 DEPTH 2330 PRESENT OPERATION NIPPLE UP BOPS. TIME 24:00:00 YESTERDAY 2330 24 HOUR FOOTAGE 0 CASING INFORMATION 16"@ 160' 13 3/8"@ 2315' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NO BIT DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 2330/2206 MW 9.4 VIS 65 PV 21 YP 16 FL 7.4 Gels 18/20/29 CL- 2300 FC 2/NA SOL 5.6 SD - OIL /94 MBT 28 pH 9.0 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY RUN CASING M/U 13-3/8 68#L-80 BTC CASING CHK FLOAT EQUIPMENT.T/2,315'AVE TQ=7000 FILL ON FLY TOP OFF EVERY 10 JTS. BREAK CIRC @1,880 GPM=84 PSI=230,M/U LANDING JOINT,INSTALL A TOTAL OF 18 CENTS.START TAKING WT F/1,175 T/1,400 15-25 K CIRCULATE AND CONDITION CIRC&CONDITION MUD RESIP PIPE.UP=170 DN=150,GPM=212 PSI=160 STAGE PUMPS UP.INSTALL CMNT LINES R/D FRANKS TOOL,BLOW DN TOP DRIVE,R/U CEMT HEAD.PRIMARY CEMENTING PUMP 5 BBLS H2O PT CEMT LINES DAILY T/4000PSI.PUMP 100 BBLS 10.1 MUD PUSH,DROP BTM PLUG PUMP 495 BBLS 10.7 LEAD CEMT,81 BBLS 12.5 TAIL,KICK TOP PLUG ACTIVITY OUT WITH 10 BBLS H2O,SWITCH OVER TO RIG PUMPS.CEMT BACK @ 570 STKS.PRIMARY CEMENTING CONT.DISPLACING CMT W/ SUMMARY RIG PUMP.BUMP PLUG @3215 STKS.HOLD 900PSI(500 OVER)F/5 MIN.BLEED OFF AND CK FLOATS HOLDING-GOOD.264BBLS CMT RETURNS T/SURFACE.RIG UP/DOWN TO RUN CASING B/D LINES.R/D CEMENT HEAD.RID CSG ELEV.RINSE OUT AND LID LNDG JT. FLUSH OUT STACK AND FLOWLINE W/5OBBL RETARDER PILL.L/D CSG TOOLS ND RISER AND SPACER SPOOLS NIPPLE UP BOPS N/U WELL HEAD AND WELL HEAD VALVES.N/U RISER AND STACK.INSTALL BELL NIPPLE.WORKING AS DIRECTED BY OPERATOR INSTALL LIFTING RAMS F/STACK.P/U STACK AND CK FOR CLEARANCE.27"CLEARANCE BETWEEN RISER AND WELL HEAD. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$2980, RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANRIG 01 07-04 REPORT FOR Cromier/Smith/Buchanan DATE Jan 2 2011 DEPTH 2330 PRESENT OPERATION TESTING BOPS TIME 24:00:00 YESTERDAY 2330 24 HOUR FOOTAGE 0 CASING INFORMATION 16"@ 160' 13 3/8"@ 3215' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NO BIT DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 2330/2206 MW 9.4 VIS 65 PV 21 YP 16 FL 7.4 Gels 18/20/29 CL- 2300 FC 2/NA SOL 5.6 SD - OIL /94 MBT 28 pH 9.0 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY NIPPLE UP BOPS REMOVE ONE BOPE PICKING CYLINDER.TQ UP N/U FLOW LINE,INSTALL CHOKE&KILL LINES,INSTALL TURN DAILY BUCKLES,HOLE FILL&BLEED OFF LINES.THAW OUT MOUSE HOLE INSTALL MOUSE HOLE.PU TEST TOOLS R/U TESTING ACTIVITY EQUIPMENT,INSTALL TEST PLUG.WAITING ON WEATHER PHASE 3 WEATHER CALLED AT 06:30 WAITING ON WEATHER PHASE 3 SUMMARY WEATHER,SUSPEND RIG WORK UNTIL 20:00 PU TEST TOOLS M/U TEST JT.FILL STACK AND CHOKE MANIFOLD,PURGE AIR OUT OF LINES TEST BOPS 250/3500(INCLUDING ANNULAR)5 MIN EACH,RECORD ON CHART. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$2980, RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANRIG 01 07-04 REPORT FOR Cromier/Smith/Buchanan DATE Jan 03,2011 DEPTH 2955 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 2330 24 HOUR FOOTAGE 625 CASING INFORMATION 16"@ 160' 13 3/8"@ 3215' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2882.88 40.02 25.39 2649.05 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12 1/4" Hycalog MSX619S-A2C 227307 1x155x14 2330 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 400.0 @ 2441 41.2 @ 2736 210.4 205.21625 FT/HR SURFACE TORQUE 11239 @ 2862 2045 @ 2568 4581.3 5002.29688 AMPS WEIGHT ON BIT 24 @ 2330 0 @ 2351 4.8 22.07759 KLBS ROTARY RPM 141 @ 2898 38 @ 2330 123.2 140.58327 RPM PUMP PRESSURE 1467 @ 2944 1069 @ 2399 1376.6 1426.57813 PSI DRILLING FLUIDS REPORT DEPTH 2400/2206 MW 8.9 VIS 42 PV 10 YP 18 FL 8.9 Gels 8/8/9 CL- 620 FC 1/NA SOL 3 SD - OIL 2/95 MBT - pH 9.5 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 83 @ 2881 2 @ 2331 35.5 TRIP GAS 0 CUTTING GAS 0 @ 2955 0 @ 2955 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 16779 @ 2883 450 @ 2331 7087.7 CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 35.5 PROPANE(C-3) @ @ CURRENT 35 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 40 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND100 SAND=MEDIUM GRAY TO MEDIUM DARK GRAY WITH OLIVE GRAY SUB TONES;LOWER FINE WITH A RANGE FROM UPPER VERY PRESENT FINE TO LOWER MEDIUM;SPHERICAL TO SUB DISCOIDAL;SUB ANGULAR TO SUB ROUNDED;MODERATELY SORTED; LITHOLOGY UNCONSOLIDATED SAND;GRAIN SUPPORTED;TEXTURALLY IMMATURE;COMPOSITIONALLY IMMATURE;QUARTZ SAND WITH LIGHT GRAY CHERT,GREEN LITHICS AND AMBER LITHICS;POROSITY AND PERMEABILITY VISUALLY GOOD;NO OIL INDICATORS. TEST BOPS TEST BOP,CHOKE,TOP DRIVE,DART,TIW.AS PER AOGCC.250PSI LOW 3500PSI HIGH FOR 5 MINS EACH.WITNESS WAIVED BY BOB NOBLE AOGCC.TEST TOOL R/D TESTING EQUIPMENT.BLOW DN,PULL TEST PLUG.INSTALL/REMOVE WEAR BUSHING INSTALL WEAR RING,ID=12-1/4 PICK UP 3RD PARTY TOOLS P/U BHA#3 FROM BEAVER SLIDE.NIPPLE UP BOPS INSTALL KATCH-KAN PICK UP BHA M/U BIT POWER DRIVE,RECEIVER,FLEX,ARC,NM ILS STAB,TELESCOPE,NM STAB,1 STD FLEX DC F/DRK FLOAT SAVER SUB,HYD JARS,HWDP,4 STD DP GOAST REAMER.T/1040'TEST POWER DRIVE WITH 94'HANGING TO SEE PADS.@ 650 GPM,PSI=660 TRIP IN HOLE F/1,040 T/2,230'TAGGED SET 8K DOWN.PICK UP T/2,189'CIRCULATE AND CONDITION CBU GPM=650 DAILY PSI=1140 UP=110 DN=95 ROT=102 RPM=25 TQ=3-4 PRESSURE TEST CSG/SHOE PRESSURE TEST 13-3/8 CASING T/2500PSI.FOR 30 ACTIVITY MINS.GOOD TEST,BLOW DOWN DRILLING CEMENT DRLG CEMT&FLOAT EQUIPMENT F/2230 T/2232'UP=115 DN=100 ROT=110 SUMMARY WOB=2-6 GPM=550 PSI=780 RPM=40 TQ=3-4/4-5 DRILLING CEMENT DRILL OUT CMT PLUGS,FLOAT COLLAR,SHOE TRACK,SHOE COLLAR.DRILL 20'NEW HOLE T/2350'50RPM TQ 3-5K WOB 5-10K 650GPM 1100PSI 750GPM 1450PSI.PULL INTO SHOE CIRCULATE AND CONDITION CBU,EVEN MUD WT IN/OUT 9.3PPG.660GPM 1150PSI FORMATION INTEGRITY TEST(FIT)12.0PPG EMW CHANGE OUT MUD SYSTEM DISPLACE HOLE T/8.9PPG 45 VIS LNSD MUD TAKE SPR'S#1 MP 35SPM 120PSI 45SPM 145PSI#2MP 35SPM 120PSI 45SPM 145SPM.DOWN LINK T/POWERDRIVE.SHUT DN T/CLEAN PIT#7,SHAKERS.TAKE ON NEW MUD F/VAC TRUCKS ROTARY DRILLING DRILL F/2350 T/2955MD 2706 TVD UP WT 128 DN WT 105 ROT WT 115 140 RPM TQ 5/4 WOB 2-10K 859GPM 1440PSI ECD 9.31 PPG MWT 8.8 ADT 3.58 JARS 22.68 CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$2980, RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANRIG 01 07-04 REPORT FOR Cromier/Smith/Buchanan DATE Jan 04,2011 DEPTH 5157 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 2955 24 HOUR FOOTAGE 2202 CASING INFORMATION 20"@ 160' 13 3/8"@ 2315' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5181.14 8.22 7.00 3636.16 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12 1/4" HycalogMSX619S-A2C 227307 1x155x14 2330 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 279.3 @ 3073 15.6 @ 4391 148.8 115.31590 FT/HR SURFACE TORQUE 14320 @ 4394 3409 @ 3069 6138.7 5161.10205 AMPS WEIGHT ON BIT 26 @ 4103 0 @ 3152 8.3 14.42439 KLBS ROTARY RPM 143 @ 3919 77 @ 4365 128.4 117.42101 RPM PUMP PRESSURE 2078 @ 5157 1110 @ 3065 1699.6 2078.39575 PSI DRILLING FLUIDS REPORT DEPTH 4913/3649 MW 9.3 VIS 55 PV 13 YP 25 FL 5.6 Gels 11/15/22 CL- 200 FC 1/NA SOL 6 SD - OIL 2/92 MBT 14 pH 9.2 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 423 @ 4255 0 @ 4041 63.8 TRIP GAS 0 CUTTING GAS 0 @ 5157 0 @ 5157 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 72241 @ 4255 41 @ 4041 10872.2 CONNECTION GAS HIGH 0 ETHANE(C-2) 1001 @ 4255 0 @ 3715 89.5 AVG 63.8 PROPANE(C-3) 616 @ 4255 0 @ 4127 37.6 CURRENT 159 BUTANE(C-4) 1081 @ 4255 0 @ 3965 65.8 CURRENT BACKGROUND/AVG 100 PENTANE(C-5) 697 @ 4255 0 @ 3965 50.3 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND 70%,SILTSTONE 30% SAND=MEDIUM LIGHT GRAY TO MEDIUM GRAY WITH LIGHT OLIVE GRAY SUB HUE;LOWER VERY FINE TO LOWER FINE GRAINED; SPHERICAL TO SUB DISCOIDAL;SUB ANGULAR TO SUB ROUNDED;WELL SORTED;UNCONSOLIDATED SAND;TRANSLUCENT PRESENT QUARTZ WITH REDDISH BROWN CARBONACEOUS MATERIAL,PYRITE AND GREEN LITHICS;MODERATE OIL ODOR;LIGHT AMBER LITHOLOGY STAIN ON 100%OF GRAINS;100%EVEN,GOLD YELLOW FLUORESCENCE;INSTANTANEOUS BLOOMING TO STREAMING BLUISH WHITE FLUORECENT CUT;CLEAR VISIBLE CUT;NO RESIDUAL VISBLE CUT;DULL YELLOW RESIDUAL FLUORESCENCE;PROSOSITY AND PERMEABILITY VISUALLY GOOD. DAILY ACTIVITY ROTARY DRILLING F/2'955'T/4020 TVD/3372 UP=140 DN=108 ROT=125 WOB=5-15 GPM=855 PSI=1650/1675 ROTARY DRILLING SUMMARY F/4020'T/5157MD 3632TVD UP WT 142 DN WT 100 ROT WT 120 120RPM TO 7/6 WOB 10-12K CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$2980; RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANR1G 01 07-04 REPORT FOR Cromier/Smith/Buchanan DATE Jan 05,2011 DEPTH 5618 PRESENT OPERATION Rig Up to Run Casing TIME 24:00:00 YESTERDAY 5157 24 HOUR FOOTAGE 461 CASING INFORMATION 20"@ 160' 13 3/8"@2215' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5547.58 83.16 7.15 3673.22 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12 1/4" Hycalog MSX619S-A2C 227307 1x15 5x14 2330 5618 3288 24.3 1-1-CT-A-X-I-ER-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 204.8 @ 5593 79.1 @ 5349 148.3 182.48724 FT/HR SURFACE TORQUE 9052 @ 5604 4760 @ 5348 6991.2 8426.60840 AMPS WEIGHT ON BIT 17 @ 5539 2 @ 5541 11.2 4.73801 KLBS ROTARY RPM 122 @ 5543 117 @ 5175 119.4 120.64318 RPM PUMP PRESSURE 2174 @ 5539 1579 @ 5457 2042.7 2062.56616 PSI DRILLING FLUIDS REPORT DEPTH 5618/3674 MW 9.4 VIS 51 PV 15 YP 22 FL 5.4 Gels 11/14/20 CL- 200 FC 1/NA SOL 7 SD - OIL 2/91 MBT 20 pH 9.1 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 1304 @ 5551 39 @ 5330 228.3 TRIP GAS 0 CUTTING GAS 0 @ 5618 0 @ 5618 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 193330 @ 5551 6124 @ 5330 34893.5 CONNECTION GAS HIGH 0 ETHANE(C-2) 3435 @ 5551 62 @ 5330 510.1 AVG 100 PROPANE(C-3) 2848 @ 5551 43 @ 5330 413.3 CURRENT 0 BUTANE(C-4) 4471 @ 5551 85 @ 5330 712.8 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 3107 @ 5551 76 @ 5330 519.2 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND 100% SAND=OLIVE GRAY TO LIGHT OLIVE GRAY;LOWER FINE TO UPPER VERY FINE DRIFTING TO UPPER FINE;SPHERICAL TO SUB DISCOIDAL;SUB ROUNDED TO SUB ANGULAR;WELL SORTED;UNCONSOLIDATED SAND;COMPOSITIONALLY IMMATURE; PRESENT TEXTURALLY IMMATURE;TRANSLUCENT QUARTZ WITH BLACK CARBONACEOUS MATERIAL AND GLAUCONITE;MODERATELY LITHOLOGY STRONG OIL ODOR;50%DARK BROWN OIL GRAIN STAIN;100%EVEN BRIGHT YELLOW SAMPLE FLUORESCENCE; INSTANTANEOUS STREAMING BLUE WHITE FLUORESCENT CUT;LIGHT BROWN VISUAL CUT;NO VISUAL RESIDUAL CUT;HEAVY BLUE WHITE RESIDUAL FLUORESCENCE;FREE OIL ON SHAKERS AND IN SAMPLE. ROTARY DRILLING 5,157'T/5,618'TVD/3682 UP=138 DN=95 ROT=110 WOB=10-14 GPM=855 PSI=2160/2120 RPM=120 TQ=6/7 ECD=10.3 BIT HRS=3.36 JAR HRS=43.40 SPR 1&2 SPM=35/45 PSI=120/150 120/150MD=5618TVD=3682 MWT=9.3 1,322 UNITS OF GAS BACK @ 5,612'SHUT DN AND MONITOR WELL.STATIC CIRCULATE AND CONDITION CBU 3 X ROT&RESIP,STAND ONE BACK EVERY BU. DAILY ROT=110 GPM=855 PSI=2120 RPM=120 TQ=5-6 F/5,618'T/5,348'MONITOR WELL FOR 10 MINS.BACK REAMING BACK REAM F/5,348 ACTIVITY T/3,338'UP=135 DN=105 ROT=120 GPM=855 PSI=1860 RPM=120 TQ=4-5 TRIP OUT OF HOLE CONT.BROOH.T/2315'UP WT 120 DN WT SUMMARY 100 ROT WT 110 120RPM TQ 3K 850GPM 1650PSI CIRCULATE AND CONDITION CIRC UNTIL CLEAN 850GPM 1650P51 75RPM 3K TQ TRIP OUT OF HOLE FLOW CK WELL-STATIC.PUMP SLUG.POOH T/BHA LAY DOWN BHA CHANGE RAMS PULL WEAR RING.R/U TEST JT. SET TEST PLUG.RILDS.MONITOR OPEN ANNULUS CHANGE RAMS CHNG TOP RAMS T/9 5/8 PIPE RAMS TEST BOPS TEST 9 5/8 PIPE RAMS 250/3500 5 MIN EACH RECORD ON CHART.RIG UP/DOWN TO RUN CASING PUMP OUT STACK.P/U HANGER/LNDG JT,MAKE DUMMY RUN,VERIFY LANDED BY VETCO REP RIG UP/DOWN TO RUN CASING P/U AND R/U TESCO CSG RUNNING EQUIP. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$2980, RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANRIG 01 07-04 REPORT FOR Cromier/Smith/Buchanan DATE Jan 06,2011 DEPTH 5618 PRESENT OPERATION Cementing TIME 24:00:00 YESTERDAY 5618 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2315' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NO BIT DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 5618/3674 MW 9.3 VIS 44 PV 15 YP 11 FL NA Gels NA CL- 200 FC NA/NA SOL 6.5 SD NA OIL 2/92 MBT NA pH 9.3 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 128 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) @ @ CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 0 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY - RIG UP/DOWN TO RUN CASING R/U TESCO CSG RUNNING EQUIP.PRE JOB SAFETY PRE-JOB SAFETY MEETING WITH ALL HANDS& TESCO,HANDS.WE TALKED ABOUT THE WHAT IFS.WE WENT OVER THE TESCO PROCEDURE FOR USING THEIR TOOL.RUN DAILY CASING M/U SHOE RUN CASING 9 5/8 CSG F/4404 T/5606 UP WT 100 DN WT 68.M/U HANGER AND LAND OUT.RIG UP/DOWN TO RUN ACTIVITY CASING RID TESCO EQUIP,R/U CEMENT HEAD.BLOW AIR THROUGH CHOKE/GAS BUSTER TO VERIFY OPEN.CIRCULATE AND SUMMARY CONDITION FILL CSG W/RIG PUMP START OUT @ 1 BPM BLEED AIR THROUGH CHOKE.FILL PIPE W/-415BBLS.INSTALL CMNT LINES REMOVE CEMENT HEAD,BLOW DOWN LINES,R/U ELEVATORS,LOAD CMT PLUGS,VERIFIED BY CO REP CIRCULATE AND CONDITION BRK CIRC ON UP STOKE BRK OVER WT STAGE UP T/5BPM 260PSI 7 BPM 350PSI PRIMARY CEMENTING CEMENT CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$2980, Rigwatch$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANRIG 0107-0a REPORT FOR Keener/Smith/Buchanan DATE Jan 07,2011 DEPTH 5618 PRESENT OPERATION Picking Up Drill Pipe TIME 24:00:00 YESTERDAY 5618 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2315'9 5/8"@ 5606' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NO BIT DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 5618/3674 MW 9.3 VIS 45 PV 15 YP 13 FL 5.8 Gels 8/13/17 CL- 200 FC 1/NA SOL 6.5 SD NA OIL 2/92 MBT 20 pH 9.1 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) @ @ CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 0 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY PRIMARY CEMENTING PUMP 82 BBLS MUD PUSH,252 BBLS DEEP CRETE 12.5 PPG SLURRY.DROP TOP PLUG W/10 BBLS H20. SWTICH OVER TO RIG PUMPS.GPM=279 PSI=850 SLOW PUMPS DN T/126 GPM PSI=720 BUMP PLUG ON STK'S 3942'PSI UP T/1240PSI HELD F/3 MINS BLEED OFF CHK FLOATS.OK.RESIP PIPE UP=255 DN=150.CIP@01:24.RIG UP/DOWN TO RUN CASING R/D CEMT HEAD,ELEVATORS,BLOW DOWN CEMT LINE&MUD LINE.PUT 5"ELEVATORS ON.TEST WELLHEAD INSTALL 9-5/8 PACK-OFF.TEST DAILY T/5000PSI F/10 MINS.GOOD TEST.RIG UP/DOWN TO RUN CASING CLEAR FLOOR OF CEMT HEAD&CASING TOOLS.INSTALL/REMOVE ACTIVITY WEAR BUSHING INSTALL WEAR RING ID=9-1/8 CHANGE RAMS C/O TOP RAMS F/9-5/8"T/4-1/2"-7"PICK UP DRILL PIPE LOAD&STRAP SUMMARY 5"DRILL PIPE INTO SHED.STEAM PIPE OUT BLOWED FULL OF SNOW,CON'T CLEANING PITS&SURFACE EQUIPMENT.PICK UP DRILL PIPE M/U MULE SHOE,RIH 1X1 T/701'UP=50 DN=45 PICK UP DRILL PIPE PU 5"DP 1X1 FROM 701'-5008'159 JTS IN HOLE 140K UP 90K DWN SERVICE RIG SERVICE TD/BLOCKS/DRAWWORKS CIRCULATE AND CONDITION PRIME PUMP#3 CIRC THRU BLEEDER OVER TOP OF HOLE 80 SPM 1200PSI PUMP FUNCTIONED OK TRIP OUT OF HOLE FROM 5008'-2754'140K UP 90K DWN PICK UP DRILL PIPE F/2754-4214'RIH WITH LAST 39 JTS FROM SHED 1X1 130K UP 90K DWN TRIP OUT OF HOLE CLEAN OFF RIG FLOOR/PUT STRIPPING RUBBER IN. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$2980, Rigwatch$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANRIG 01 07-04 REPORT FOR Keener/Smith/Buchanan DATE Jan 08,2011 DEPTH 5618 PRESENT OPERATION Preping to test bag. TIME 24:00:00 YESTERDAY 5618 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2315'9 5/8"@ 5606' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NO BIT DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 5618/3674 MW 9.1 VIS 45 PV 15 YP 13 FL 5.8 Gels 8/13/17 CL- 200 FC 1/NA SOL 6.5 SD NA OIL 2/92 MBT 20 pH 9.1 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) @ @ CONNECTION GAS HIGH 0 ETHANE(C-2) @ @ AVG 0 PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY TRIP OUT OF HOLE F/T/98'CUT DRILLING LINE SLIP&CUT 67'OF LINE.SERVICE TOP DRIVE SERVICE TOP DRIVE,DRAWWORKS, BLOCKS,CROWN.GREASE TOP DRIVE RAIL.TRIP OUT OF HOLE PULL SRIPPING RUBBER,BLOW DN MUD LINE.STAND BACK ONE STAND UD MULE SHOE.INSTALUREMOVE WEAR BUSHING PULL WEAR RING.PU TEST TOOLS R/U TO TEST BOP W/5-1/2 TEST DAILY JOINT.FILL BOPE&CHOKE W/H20 TEST BOPS TEST BOPE,CHOKE,DART,TIW,TOP DRIVE,W/5.5&3.5,TEST JOINTS.250PSI LOW ACTIVITY 3500PSI HIGH.KOOMEY TEST.AS PER AOGCC.GOT A 250 PSI LOW ON ANNULAR WITH 3.5 TEST JOINT.ATTEMPTED 7 TIMES. SUMMARY WORKED ANNULAR MANY TIMES-NO HI TEST.WITNESSED WAIVED BY JEFF JONES AOGCC.TEST BOPS FUNCTION TEST ANNULAR ON 2"PIPE/PU TEST JT ATTEMP TO TEST ANNULAR AFTER FUNCTIONING/TEST FAILED/BLOW DWN LINES DRAIN STACK PULL TEST PLUG/LD TEST JOINT NIPPLE DOWN BOPS ND KATCH KAN/NIPPLE DWN FLOW LINE,ND FLOW NIPPLE CHANGE RAMS BRK HEAD OFF ANNULAR PREVENTER/PULL ELEMENT/PUT NEW SEALS IN/PUT NEW ELEMENT IN/SET CAP IN TIGHTEN DWN CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3060, RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANRIG 0107-04 REPORT FOR Keener/Smith/Buchanan DATE Jan 09,2011 DEPTH 5618 PRESENT OPERATION Preparing to Swap Mud TIME 24:00:00 YESTERDAY 5618 24 HOUR FOOTAGE 0 CASING INFORMATION 20"@ 160' 13 3/8"@ 2315'9 5/8"@ 5606' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" Hycalog RSR616M F8 E140123 6x14 5618 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 5618/3682 MW 9.1 VIS 50 PV 14 YP 14 FL 6.8 Gels 3/3/4 CL- 125000 FC NA/1 SOL 10 SD - OIL 61/39 MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY CHANGE ROTATING HEAD/RUBBER LINE UP CAP LINE UP BOLT ON ANNUALER.REMOVE POTATO MASHER.INSTALL BELL NIPPLE. L/D POTATO MASHER&JOINT OF DP.TEST BOPS P/U 3-1/2 TEST JOINT M/U TEST PLUG&SET,FILL BOPE WITH H2O TEST BOPS TEST ANNUALER W 3.5&5.5 TEST JOINTS.250 PSI LOW 3500PSI HIGH.FOR 5 MINS EACH.AS PER AOGCC.WITNESS WAIVED BY JEFF JONES.LD TEST TOOL R/D TESTING EQUIPMENT&FREEZE PROTECT.TEST PUMP.INSTALL/REMOVE WEAR BUSHING INSTALL DAILY WEAR RING NIPPLE UP BOPS INSTALL KATCH-KAN.PICK UP BHA CALIBRATE BLOCKS FOR SCHLUMBERGER&MUD LOGGER.PICK ACTIVITY UP BHA M/U BIT,XCEED,ARC,TELESCOPE,NM ILS STAB,SONICVISION,NM STAB,3 NM FLEX DC,3 HWDP,HYD JARS,5 HWDP.T/579 SUMMARY TEST MWD TOOLS GPM=508 PSI=700 TRIP IN HOLE RIH F 579-1890'CIRCULATE AND CONDITION FILL PIPE/CIRC 550 GPM 1000PSI 130 SPM/SEND DOWNLINK TO TOOL TRIP IN HOLE RIH F/1890-2300'TRIP IN HOLE TIH LOG @ 900'/HR MAX 2313-TAG CEMENT@ 5496'WASH DWN F/4940-5496 250 GPM 500 PSI TRIP OUT OF HOLE RACK BACK STD#53/BLW DWN TD/RU HEAD PIN TEST HOSES PRESSURE TEST CSG/SHOE TEST 9 5/8 CSG TO 3000 PSI/PUMP 5 SPM 48STKS TOTAL OA PRESS 300PSI/CHARTED 30 MIN/BLED DWN/MWT 9.2#PRESSURE TEST CSG/SHOE BLW DWN/RD TEST LINES CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3060; RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CABG 01 07-04 REPORT FOR Keener/Smith/Buchanan DATE Jan 10,2011 DEPTH 7245 PRESENT OPERATION DRILLING AHEAD TIME 24:00:00 YESTERDAY 5619 24 HOUR FOOTAGE 1626 CASING INFORMATION 20"@ 160' 13 3/8"@ 2315 9 5/8"@ 5606' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7212.02 87.05 358.84 3760.71 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" Hycalog RSR616M F8 E140123 6x14 5618 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 369.6 @ 6183 44.1 @ 6758 255.3 235.45108 FT/HR SURFACE TORQUE 10033 @ 6198 3634 @ 6201 6266.6 7096.56494 AMPS WEIGHT ON BIT 21 @ 5644 0 @ 6902 4.3 2.24129 KLBS ROTARY RPM 121 @ 7111 57 @ 5651 109.7 120.50607 RPM PUMP PRESSURE 2265 @ 7129 1542 @ 6350 2125.7 2237.18091 PSI DRILLING FLUIDS REPORT DEPTH 6905/3720 MW 9.2 VIS 58 PV 19 YP 19 FL 6.5 Gels 5/5/6 CL- 100000 FC NA/1 SOL 9 SD - OIL 59/41 MBT - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 838 @ 6041 0 @ 5665 370.9 TRIP GAS 0 CUTTING GAS 0 @ 7245 0 @ 7245 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 186366 @ 6041 5 @ 5659 65870.4 CONNECTION GAS HIGH 0 ETHANE(C-2) 1464 @ 6042 0 @ 5665 514.5 AVG 370 PROPANE(C-3) 736 @ 6137 0 @ 5665 195.1 CURRENT 297 BUTANE(C-4) 705 @ 6136 0 @ 5665 250.9 CURRENT BACKGROUND/AVG 350 PENTANE(C-5) 395 @ 6189 0 @ 5665 133.5 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND 100% SAND=MEDIUM LIGHT GRAY TO LIGHT GRAY WITH OLIVE GRAY SUB HUE;LOWER FINE TO UPPER VERY FINE GRAINED; SPHERICAL TO SUB PRISMOIDAL;SUB ANGULAR TO SUB ROUNDED;WELL SORTED;SAND IS UNCONSOLIDATED;GRAIN PRESENT SUPPORTED;TEXTURALLY IMMATURE;COMPOSITIONALLY SUB MATURE;TRANSLUCENT QUARTZ WITH BLACK CARBONACEOUS LITHOLOGY LITHICS AND GLAUCONITE;SLIGHT OIL ODOR;AMBER GRAIN STAINING ON SOME GRAINS;100%EVEN LIGHT GREEN FLUORESCENCE WITH OCCASIONAL PATCHY GOLDEN YELLOW FLUORESCENCE;INSTANTANEOUS BLOOMING MILKY WHITE CUT; VERY FAINT LIGHT BROWN SAMPLE CUT;NO RESIDUAL CUT;MEDIUM BRIGHT BLUISH WHITE RESIDUAL SAMPLE FLUORESCENCE; POROSITY AND PERMEABILITY VISUALLY GOOD. PRESSURE TEST CSG/SHOE BLOW DN KILL&CEMT LINE.STAGE TRUCKS FOR DISPLACEMENT.DISPLACE TO OIL BASE DISPLACE F/LSND MUD T/OBM 9.1.GPM=475 PSI=1470 ROT&RECIP PIPE.UP=140 DN=90 ROT=110 RPM=50 TQ=5800 CLEANING RIG/PLATFORM CLEAN SURFACE EQUIPMENT&PIT 7.TRANSFER OBM F/RAW MUD T/PITS DRILLING CEMENT DRLG PLUGS,FLOAT EQ&CEMT F/5,511'T/5,618'UP=130 DN=100 ROT=110 GPM=385 PSI=1160 WOB=2-12 RPM=40-60 TQ-3800/4-5 ROTARY DRILLING DRLG F/5618 DAILY T/5648'TVD/UP=125/DN=90/ROT=105/WOB=6-8/GPM=610/PSI=2150/2160 RPM=110TQ=4/5-6 CIRCULATE AND CONDITION CBU ROT& ACTIVITY RESIP PIPE.ROT=110 GPM=610 PSI=2130 RPM=60 TQ=4 PRESSURE TEST CSG/SHOE R/U PERFORM LOT W/9.2 MWT,PRESSURE UP SUMMARY 940 PSI BLEED OFF T/840PSI EMW=13.6.R/D BLOW DOWN.ROTARY DRILLING F/5,643'T/5,841'TVD/3694 UP=120 DN=90 ROT=105 WOB=6-8 GPM=610 PSI=2150/2160 RPM=100 TQ=4/5-6 ECD=10.81 BIT HRS=1.15 JSR HRS=73.9 SPR l&2 SPM=35/45 PSI=185/270 MD=5744 TVD=3696 MWT=9.2 ROTARY DRILLING F/5841'-7245(3761 TVD)5-15K WOB 144 SPM/610 GPM 2230 PSI ON 2240 PSI OFF/ 7000K TQ ON 6200K TQ OFF/128K UP 82K DWN 105K ROT/MWT 9.2/10.7 ECD SPR @ 6504(3705TVD)35/45 STKS#1 200/285#3 200/ 285 SPR @ 7175(3754TVD)35/45 STKS#1 190/250#3 190/260 ADT 6.2 JARS 80.1. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3060; RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANRIG 01 07-04 REPORT FOR Keener/Smith/Buchanan DATE Jan 11,2011 DEPTH 9765 PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 7246 24 HOUR FOOTAGE 2519 CASING INFORMATION 16"@ 160' 13 3/8"@ 2315 9 5/8"@ 5606' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 96701.25 90.69 2.56 3863.15 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" Hycalog RSR616M F8 El 40123 6x14 5618 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 545.2 @ 7373 15.0 @ 7735 225.6 187.40085 FT/HR SURFACE TORQUE 13686 @ 8687 4142 @ 7511 8032.9 8460.90137 AMPS WEIGHT ON BIT 21 @ 7850 0 @ 9287 6.0 1.43541 KLBS ROTARY RPM 123 @ 9765 58 @ 8612 117.2 123.47021 RPM PUMP PRESSURE 2640 @ 9391 927 @ 9210 2395.1 2432.26025 PSI DRILLING FLUIDS REPORT DEPTH 9425/3861 MW 9.4 VIS 55 PV 19 YP 19 FL 7.9 Gels 6/7/8 CL- 90000 FC NA/1 SOL 11.5 SD - OIL 66/34 MBT - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 714 @ 9497 0 @ 8903 258.4 TRIP GAS 0 CUTTING GAS 0 @ 9765 0 @ 9765 0.0 WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 139575 @ 9497 94 @ 8903 48481.7 CONNECTION GAS HIGH 0 ETHANE(C-2) 2948 @ 8749 0 @ 8903 294.9 AVG 258.4 PROPANE(C-3) 3686 @ 8749 0 @ 8903 66.3 CURRENT 28 BUTANE(C-4) 3218 @ 8749 0 @ 8903 100.9 CURRENT BACKGROUND/AVG 500 PENTANE(C-5) 588 @ 9664 0 @ 8903 70.7 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND 100% SAND=GRAYISH BLACK TO DARK GRAY WITH OLIVE GRAY SUB HUES;UPPER VERY FINE TO LOWER VERY FINE GRAINED; SPHERICAL TO SUB DISCOIDAL;SUB ROUNDED TO SUB ANGULAR;WELL TO VERY WELL SORTED;UNCONSOLIDATED SAND; PRESENT GRAIN SUPPORTED;TEXTURALLY IMMATURE;COMPOSITIONALLY IMMATURE;TRANSLUCENT QUARTS WITH GLAUCONITE AND LITHOLOGY BLACK CARBONACEOUS MATERIAL;VERY FAINT OIL ODOR;SLIGHT GRAIN STAINING;100%EVEN DULL GREEN SAMPLE FLUORESCENCE;BLOOMING DULL BLUISH WHITE CUT FLUORESCENCE;VERY FAINT BROWN SAMPLE CUT;NO RESIDUAL CUT; DULL WHITE SAMPLE RESIDUAL FLUORESCENCE;POROSITY AND PERMEABILITY VISUALLY GOOD. ROTARY DRILLING DRLG F/7,245'T/8611 TVD/3861 UP=145 DN=75 ROT=105 WOB=8-12 GPM=610 PSI=2440/2470 RPM=120 DAILY TQ=6900/9000 ECD=11.35 BIT HRS=8 JAR HRS=88.1 SPR 1&3 SPM=35/45 PSI=270/350,265/350 MD=8328 TVD=3853 MWT=9.2 NO ACTIVITY LOSSES OF MUD ON THIS TOUR.ROTARY DRILLING F/8611 -9765(3863TVD)WOB 5-20K/144 SPM/610 GPM/2580 PSI ON,2570 SUMMARY PSI OFF/8600 TQ ON 7800 TQ OFF/135K UP,70K DWN,104K ROT/120 RPM/ECD 11.4 MWT 9.4 SPR @ 9091(3860 TVD)MWT 9.4# 35/45 SPM#1 300/380#3 290/380 ADT 8.11 JARS 96.2. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3060; RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANRIG 0107-04 REPORT FOR Keener/Smith/Buchanan DATE Jan 12,2011 DEPTH 12254 PRESENT OPERATION Drilling Ahead to TD TIME 24:00:00 YESTERDAY 9766 24 HOUR FOOTAGE 2488 CASING INFORMATION 16"@ 160' 13 3/8"@ 2315'9 5/8"@ 5606' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 12190.66 88.78 356.91 3923.95 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" Hcalog RSR616M F8 E140123 6x14 5618 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 357.8 @ 9771 12.3 @ 10356 224.3 0.00000 FT/HR SURFACE TORQUE 14779 @ 10525 7693 @ 11021 9809.4 9460.27051 AMPS WEIGHT ON BIT 22 @ 10720 0 @ 11555 6.4 0.38605 KLBS ROTARY RPM 123 @ 9796 57 @ 10488 108.7 120.45907 RPM PUMP PRESSURE 3014 @ 12188 1973 @ 12114 2756.3 3009.63843 PSI DRILLING FLUIDS REPORT DEPTH 11869/3930 MW 9.4 VIS 55 PV 17 YP 21 FL 8.0 Gels 6/7/7 CL- 80500 FC NA/1 SOL 12 SD - OIL 66/34 MBT - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 815 @ 9891 8 @ 11016 264.6 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 276511 @ 10320 1027 @ 11264 53648.7 CONNECTION GAS HIGH 0 ETHANE(C-2) 50007 @ 11254 11 @ 10523 661.5 AVG 264.6 PROPANE(C-3) 1277 @ 11507 1 @ 11408 93.1 CURRENT 27 BUTANE(C-4) 788 @ 10322 4 @ 11408 112.9 CURRENT BACKGROUND/AVG 200 PENTANE(C-5) 643 @ 10323 2 @ 11408 76.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SUMMARY:SAND/SANDSTONE FROM 9766 TO 10939;SILTSTONE/SILTY SANDSTONE FROM 10939 TO 11134;SAND/ SANDSTONE FROM 11134 TO 11254. PRESENT SAND LITHOLOGY ROTARY DRILLING DRLG F/9,765'T/10,914'TVD/3901 UP=148 DN=60 ROT=100 WOB=8-12 GPM=610 PSI=2800/2820 RPM=120 DAILY TQ=8400/9000 ECD=11.71 SPR 1&3 SPM=35/45 PSI=335/440 MD=10,434'TVD=3,874'MWT=9.4 BIT HRS=8.36 JAR HRS=104.5 ROTARY ACTIVITY DRILLING F/10914(3901TVD)-12254(3922)WOB 4-20K/144 SPM/2950 PSI ON 2940 OFF/11K TQ ON,8900 TQ OFF/145K UP,48K SUMMARY DWN 103K ROT/80-120 RPM/11.76 ECD 9.4 MWT SPR @ 11101(3906TVD)35/45#1 350/450#2 360/450 SPR @ 11871(3908TVD)35/45 #1 360/480#2 370/480 ADT 7.62 JARS 112.1 JARS 13 CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3060; RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CAIG 0107-04 REPORT FOR Keener/Smith/Buchanan DATE Jan 13,2011 DEPTH 12325 PRESENT OPERATION Back Reaming Out to Shoe TIME 24:00:00 YESTERDAY 12255 24 HOUR FOOTAGE 70 CASING INFORMATION 16"@ 160' 13 3/8"@ 2315'9 5/8"@ 5606' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 12262.28 88.81 357.31 3923.34 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" Hycalog RSR616M F8 E140123 6x14 5618 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 246.3 @ 12313 31.1 @ 12273 207.5 FT/HR SURFACE TORQUE 14360 @ 12270 9460 @ 12255 10998.9 AMPS WEIGHT ON BIT 17 @ 12270 0 @ 12255 6.0 KLBS ROTARY RPM 120 @ 12257 56 @ 12272 111.4 RPM PUMP PRESSURE 3037 @ 12268 2964 @ 12257 3008.3 PSI DRILLING FLUIDS REPORT DEPTH 12325/3926 MW 9.4 VIS 49 PV 16 YP 15 FL NA Gels 4/5/5 CL- 78k FC NA/1 SOL 12 SD - OIL 66/34 MBT - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 302 @ 12315 34 @ 12272 233.7 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 55826 @ 12315 5942 @ 12272 39672.8 CONNECTION GAS HIGH 0 ETHANE(C-2) 459 @ 12301 56 @ 12272 341.9 AVG 233.7 PROPANE(C-3) 104 @ 12323 12 @ 12272 68.7 CURRENT 5 BUTANE(C-4) 219 @ 12323 23 @ 12255 143.5 CURRENT BACKGROUND/AVG 6 PENTANE(C-5) 181 @ 12318 14 @ 12255 100.8 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SUMMARY:SAND PRESENT LITHOLOGY SAND ROTARY DRILLING DRLG F/12,254'T/12,325'TVD/3,925'UP=150 DN=COULD NOT SLIDE DOWN.ROT=103 WOB=8-20 ECD=11.71 GPM=610 PSI=3000/3020 RPM=120 TQ=9000/11,200'BIT HRS=.66 JAR HRS=112.8 SPR 1&2 SPM=35/45 PSI=360/450 350/450 MD=12,325' DAILY TVD=3,925'MWT=9.4 SV TWO FEET OFF BTM.STRAP LAST STAND OUT CIRCULATE AND CONDITION CBU 1-1/2X STAND ONE STD ACTIVITY BACK.CBU 6 X'S STANDING ONE STD BACK EVERY BU.ROT&RECIP UP=145 DN=55 ROT=104 RPM=140/120 TQ=11,300/8900 GPM=610 SUMMARY PSI=2800 ECD=11.40 F/12,325'T/11,680'MONITOR WELL F/10 MINS STATIC BACK REAMING BACK REAM F/11,680'T/9191 UP=130 DN=70 ROT=100 GPM=610 PSI=2400 RPM=120 TQ=7100 ECD=10.99 SLM OUT TOTAL LOSSES FOR TOUR 21 BBLS BACK REAMING F/ 9191-7630(3783TVD)610 GPM/144 SPM 2220PSI 6200 TQ BACK REAM SLOW THRU SHALE 8367-7788 125K UP 80K DWN 100K ROT MWT 9.4 ECD 10.89 FLUID LOSSES 50 BBLS 14. CANRIG PERSONNEL ON BOARD 5 DAILY COST DML$3060; RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANRIG 01 07-04 REPORT FOR Keener/Beauchamp/Buchanan DATE Jan 14,2011 DEPTH 12325 PRESENT OPERATION Cut/Slip Drill Line TIME 24:00:00 YESTERDAY 12325 24 HOUR FOOTAGE 0 CASING INFORMATION 16"@ 160' 13 3/18"@ 2315'9 5/8"©5606' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5 Hycalog RSR16M F8 E140123 6x14 5618 12325 6707 40.1 1-1-WT-A-O-BT-TD TD 6.25 x 8.5 Weatherford Hole Pnener 244765 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 12325/3924 MW 9.4 VIS 50 PV 17 YP 15 FL 7.8 Gels 5/5/6 CL- 74k FC NA/1 SOL 11.9 SD - OIL 67/33 MBT - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) @ @ CONNECTION GAS HIGH NA ETHANE(C-2) @ @ AVG NA PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY BACK REAMING BACK REAM F/7,630'T/5,554'UP=118 DN=92 ROT=104GPM=610 PSI=1920 RPM=120 TQ=4800 ECD=10.90 PACKING OFF @ F/6960'T/6952'F/6485'T/6475'CIRCULATE AND CONDITION CBU 4X UP INSIDE 9-5/8 SHOE MD=5554'ROT&RESIP,UP=118 DN=92 ROT=104 RPM=80 TQ=4500 GPM=610 PSI=1880,BACK REAMING BACK REAM,F/5,554'T/3927'UP=115 DN=105 ROT=110 RPM=80 DAILY TQ=3000 GPM=610 PSI=1680 BACK REAMING F 3927'-3640 144 SPM 610 GPM 1650 PSI 2700 TQ 115K UP 110K DWN 110 ROT ACTIVITY CIRCULATE AND CONDITION MONT WELL FOR FLOW/PUMP DRY JOB TRIP OUT OF HOLE POOH FROM 3640'-480 115K UP 110K SUMMARY DWN SLM DP LAY DOWN BHA STD BACK HWDP,JARS,NON MAG FLEX COLLARS/BO LD SONIC,NM STAB,TELESCOPE,ARC XCEED,8.5 BIT PICK UP BHA CLEAN UP RIG FLOOR/SWAP OUT BHA/CHANGE OUT SAVER SUB PICK UP BHA MU BIT SUB/HOLE OPENER TO STD OF FLEX COLLARS/RIH W/HWDP,JARS TRIP IN HOLE RIH TO 5453'FILL PIPE EVERY 25 STDS 110K UP 90K DWN 22:30 00:00 1.50 9.A CUT DRILLING LINE CUT/SLIP 45'SERVICE DRAWWORKS SERVICE TD BLOCKS/CROWN CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3060; RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANRIG 01 07-04 REPORT FOR Keener/Beauchamp/Buchanan DATE Jan 15,2011 DEPTH 12325 PRESENT OPERATION Trip out of hole TIME 24:00:00 YESTERDAY 12325 24 HOUR FOOTAGE 0 CASING INFORMATION 16"@ 160' 13 3//8"@ 2315'9 5/8"@ 5606' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 6.25 x 8.5 Weatherford Hole Opener 244765 40. DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 12325/3924 MW 9.5 VIS 57 PV 17 YP 15 FL 8.1 Gels 4/5/5 CL- 76k FC NA/1 SOL 12.0 SD - OIL 67/33 MBT - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 61 CUTTING GAS @ @ WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) @ @ CONNECTION GAS HIGH NA ETHANE(C-2) @ @ AVG NA PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY TRIP IN HOLE TIH ON ELEV.F/5452'12,325'BTM.ENCOUNTERED NO TIGHTSPOTS,PROPER DIS.FILL PIPE EVERY 20STDS.90-80K- DWN-WT CIRCULATE AND CONDITION CIRC AND RECIPROCATE PIPE.600GPM 2400PSI 120RPM 8.6K-TQ TILL SHAKERS CLEAN,PER MI&K&M REP.CIRC 300GPM 60RPM 800PSI 9.4PPG IN/OUT.WAIT ON 9.5PPG FAZE AWAY MUD/TRUCKS.PREP 5.5 LINER W/SWELL DAILY PACKERS IN SHED.PREP ACTIVE PITS FOR DISPLACMENT.CIRCULATE AND CONDITION ROT RECIP PIPE/60 RPM8400K TO/120K ACTIVITY ROT76 SPM 322 GPM WAIT ON FAZE AWAY BREAKER FLUID DISPLACE TO COMPLETION FLUID SPOT FAZE AWAY BREAKER FLUIDV SUMMARY 9.5#PUMP 510 BBLS/262 GPM 60 SPM 480 PSI/REC ROT 60 RPM 118K ROT 9.4K TO WHEN FLUID OUT BIT/PUMP 60 BBLS FAZE PRO 9.4#SAME PERAMITERS/PUMP 11.4#DRY JOB/MONT WELL TRIP OUT OF HOLE 12325-5600 POOH TO INTERMIDIATE SHOE 1 MIN PER STD PULLING SPEED 165K UP 80K DWN/MONT WELL @ SHOE TRIP OUT OF HOLE CONT TO POOH FROM 5600-2294 98K UP CANRIG PERSONNEL ON BOARD 4 DAILY COST DML$3060; RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANRIG 0107-04 REPORT FOR Keener/Beauchamp/Buchanan DATE Jan 16,2011 DEPTH 12325 PRESENT OPERATION Runnning Liner TIME 24:00:00 YESTERDAY 12325 24 HOUR FOOTAGE 0 CASING INFORMATION 16"@ 160' 13 3//8"@ 2315'9 5/8"@ 5606' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 12325/3924 MW 9.4 VIS 57 PV 17 YP 15 FL 8.1 Gels 4/5/5 CL- 75k FC NA/1 SOL 12.0 SD - OIL 67/33 MBT - pH - Ca+ - CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) @ @ CONNECTION GAS HIGH NA ETHANE(C-2) @ @ AVG NA PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY TRIP OUT OF HOLE POOH F/2294'T/382'LOSING 6BPH LAY DOWN BHA RACK BACK HWDP/JAR.L/D 3 FLEX D/C BIT SUB,HOLE OPENER.RIG UP/DOWN TO RUN CASING PJSM.P/U R/U GBR LINER RUNNING EQUIP.TONGS,SLIPS,ELEVATORS,TQ TURN EQUIP. DAILY PER GBR.PRE JOB SAFETY PJSM RUNNING TQ TURN 5.5 SLOTTED LINER.RUN LINER RIH W/5.5 17#L-80 SLOTTED LINER AND ACTIVITY SWELL PACKERS PER PROGRAM.T/2448'LOSING 3-5BPH.RUN LINER RIH W/5.5 17#HYDRIL 521 LINER F/2488-6912'M/U LINER SUMMARY SETTING SLEEVE MU LINER HANGER FILL W/PAL MIX/WAIT 30 MIN FOR MIX TO SET UP 112K UP 90K DWN/RIG DWN GBR CSG EQUIPMENT TRIP IN HOLE RIH W/5.5 17#HYDRIL 521 LINER,LINER HANGER ON 5"DP PUMP 50 STKS ON STD#1 43 SPM DWN 102K ROT 2,600 TQ GET ROT WEIGHTS,TQ VALUES EVERY 5 STDS FILL PIPE EVERY 10 STDS. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML$2220; RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CANRIG OI 07-04 REPORT FOR Keener/Beauchamp/Buchanan DATE Jan 17,2011 DEPTH 12325 PRESENT OPERATION Laydown Drill Pipe TIME 24:00:00 YESTERDAY 12325 24 HOUR FOOTAGE 0 CASING INFORMATION 16"@ 160' 13 31/8"@ 2315'9 5/8"@ 5606' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 12325/3924 MW 9.0 VIS BRINE PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS NA CUTTING GAS @ @ WIPER GAS NA CHROMATOGRAPHY(ppm) SURVEY NA METHANE(C-1) @ @ CONNECTION GAS HIGH NA ETHANE(C-2) @ @ AVG NA PROPANE(C-3) @ @ CURRENT 0 BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY TRIP IN HOLE WITH 5.5"F/10,300'LINER TO 12200TAKINGWEIGHT.REAMING/WASHING KELLY UP AND REAM IN HOLE FROM 12200'TO BOTTOM AT 12325'TAG SAME,PICK UP TO 12313'SETTING DEPTH.ROTATE WEIGHT=122K,SO WEIGHT=112K,RPM=25, TORQUE=9500 FT/LBS CIRCULATE AND CONDITION CIRC.DRILL PIPE VOLUME+(100 BBLS)AT 5 BPM WITH 400 PSI TO ENSURE FLOW PATH FREE.CIRCULATE AND CONDITION DROP BALL&PUMP DOWN AT 6 BPM(FOR 63 BBLS-500 PSI)SLOW PUMP TO 2 BPM (225 PSI)AND LAND BALL IN SEAT.PSI UP TO 3000 AND SLACK OFF TO 70K,PSI UP TO 4000,BLEED OFFTO ZERO.CLOSE ANNULAR DAILY AND PRESSURE UP ANNULUS TO 1500&HOLD FOR 10 MINUTES(CHART RECORD SAME)-OK.BLEED OFF.PRESSURE UP TO 400 PSI ACTIVITY &PULL STINGER OUT,PSI DROPPED TO ZERO-OK.LAY DOWN 2 SINGLES DP.SET T.O.L @ 5372'&12,313-SHOE DEPTH.DISPLACE TO SUMMARY WATER BASE PREPARE TO DISPLACE CASED HOLE OVER TO 9.0 PPG INHIBITED BRINE.CIRC 7BPM 400PSI 30RPM RECIPROCATING PIPE TILL 9.0 BRINE SURF/SURF 360BBLS PER MUD MAN.MONITOR HOLE 10MIN-STATIC..F LAY DOWN DRILL PIPE L/D DRILL PIPE, PROPER HOLE FILL.123JTS L/D LAY DOWN DRILL PIPE F/1500-SURFACE LD 46 JTS 5"DP/LD LINER SETTING TOOL SERVICE TOP DRIVE TRIP IN HOLE TO 4400'W/5"HWDP,JARS/43 STDS FROM DERRICK 125K UP/110K DWN F LAY DOWN DRILL PIPE F/4400-278' LD 129 JTS DP TRIP IN HOLE RIH W/30 STDS DP FROM DERRICK ON TOP OF HWDP RIH TO 3128'110K UP 100K DWN LAY DOWN DRILL PIPE LD F 3128-2650 LD 15 JTS. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML$2220; RIGWATCH$1450 REPORT BY Tollef Winslow ENI Petroleum DAILY WELLSITE REPORT CAMRIG 01 07-04 .... REPORT FOR Keener/Beauchamp/Buchanan DATE 18 Jan 2011 DEPTH 12325 PRESENT OPERATION RIH w/completion tubing TIME 24:00:00 YESTERDAY 12325 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2315'9 5/8"@ 5606' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MW 9.0 VIS BRINE PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca-i- CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY UD 5"DP.R/U completion string.RIH w/3.5"tubing and cables CANRIG PERSONNEL ON BOARD 2 DAILY COST DML-$2220; Rigwatch-$1450 REPORT BY E.Opitz ENI Petroleum DAILY WELLSITE REPORT CANS 01 07-04 REPORT FOR Keener/Beauchamp/Buchanan DATE 19 Jan 2011 DEPTH 12325 PRESENT OPERATION RIH w/tubing TIME 24:00:00 YESTERDAY 12325 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2315 9 5/8"@ 5606' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MW 9.0 VIS BRINE PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Cont.RIH 3.5"Tubing F/3361'to 6771'.M/U 3.5"Guage Carrier,Pup JT and 4.5"XO.RIH W/4.5"12.64 and Fiber Optic to 7760'.P/U M/U AHR Packer Assy.Finish Fiber Optic splice SUMMARY and RIH 4.5"tubing CANRIG PERSONNEL ON BOARD 2 DAILY COST DML-$2220; Rigwatch-$1450 REPORT BY E.Opitz ENI Petroleum DAILY WELLSITE REPORT CANZIG OI 07-04 .. REPORT FOR Keener/Beauchamp/Buchanan DATE 20 Jan 2011 DEPTH 12325 PRESENT OPERATION Nipple Down TIME 24:00:00 YESTERDAY 12325 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 2315'9 5/8"@ 5606' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MW 9.0 VIS BRINE PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY RIH w/4.5"Tubing f/7992'to 11,934'.P/U M/U V.I.T.TD @ 12,042'.Set Hanger and terminate control lines.Flush stack,drop ball and pressure up to 2100 psi seen Packer set.Then SUMMARY pressure up to 4000 psi and chart for 30 min.,test Ann.30 min.@ 500 psi.Set BPV and nipple down. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML-$2220; Rigwatch-$1450 REPORT BY E.Opitz ENI Petroleum DAILY WELLSITE REPORT CALK 01 07-04 ,... .., REPORT FOR Keener/Beauchamp/Buchanan DATE 21 Jan 2011 DEPTH 12325 PRESENT OPERATION Rig move TIME 24:00:00 YESTERDAY 12325 24 HOUR FOOTAGE 0 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY pull upper 4.5x7 and btm 3.5x6 varalble rams to replace elements and clean rams.nipple down bops and remove riser per vetco prepare cellar and wellhead prepare hanger.terminate/cap fiberoptic/gauge lines to hanger per slb.n/u tree,wing valve,actuator valve,r/u to test tree.test tree to 5000psi 10min charted.circulate and condition r/u lines/manifold f/testing ia and freeze DAILY protect pt Irs lines V 3000psi.pressure up tbg V 2000psi-shut in.pressure up ia t/2500psi,shut in,record on chart f/30 min.inner annular integrity test.bleed of tbg side,shear glm valve f/is side. ACTIVITY bleed off both sides V zero.freeze protect.pump 155bbls diesel dn is take returns f/tbg.icp/bpm-350psi fcp 1.5bpm 650psi.100%returns bk V surface.initial shut in pressure 11 Opsi is&tbg,u- SUMMARY tube 1/15 min final pressure 1750 is&tbg.blow dn lines,r/d Irs,r/d hoses and manifold.demobilization blow dn charge pump manifolds and lines,drain charge pumps.blow dn sub side water lines.raise cellar box.roll up tarps around lampsons.remove berming around rig.run methanol through air system and dw air lines.disconnect mud manifold innerconnect.disconnect flowlines and holefill line. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML-$2220;Rigwatch-$1450 REPORT BY E.Opitz 0 3 0 3 r 0 ca CA
