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206-113
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 From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CD4-318 SSSV Report of Non Compliance Date:Monday, December 15, 2025 9:41:38 AM Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (OGC) Sent: Monday, December 15, 2025 9:41 AM To: 'Hobbs, Greg S' <Greg.S.Hobbs@conocophillips.com> Cc: McMullen, Doug <Doug.McMullen@conocophillips.com>; Chmielowski, Jessie L C (OGC) <jessie.chmielowski@alaska.gov> Subject: RE: CD4-318 SSSV Report of Non Compliance CRU CD4-318A; PTD 2061130 I am most troubled by the fact the well showed up on CPAI’s SVS Missed State Safety Valve Tests Report but was overlooked in the next 6 days. Thank you for the self-report of noncompliance and implementing corrective actions to prevent recurrence. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Monday, December 15, 2025 9:07 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: McMullen, Doug <Doug.McMullen@conocophillips.com> Subject: CD4-318 SSSV Report of Non Compliance is safe. Jim, ConocoPhillips Alaska Inc. (CPAI would like to report a safety valve system violation that occurred Thursday, December 11th on CD4-318. On Dec 11th it was discovered that CPAI was out of compliance on well CD4-318 that had been operating without a state witnessed closure test on a sub-surface safety valve. This e-mail serves as our report to the AOGCC. The well was shut-in and a state test notification has been made to the state. The bullet points listed below describes the sequence of events that led to the non-compliance. Dec 1st - CD4-318 was TP'd(Theoretical production flag) down for Downhole Maint. Opt.- Other. Dec 4th -A MIT-T and MIT-TXIA combo was done on the well. The SSSV had been removed so that a plug could be installed in the tubing of the well. Dec 5th- Plug was removed and SSSV was reinstalled. Slickline performed a closure test on the SSSV by bleeding the tubing down from 1200 PSI to 550 PSI and got a good closure test. The well was brought online. Due to the incorrect TP code being used this did not flag on Well Trak which would have indicated the well would need to be state tested when it was brought online. Thus, the SVS techs and Operations were unaware that a State Test Notification needed to be made and the well needed to be state tested. CD4-318- did show up on the SVS Missed State Safety Valve Tests Report when it was TP'd up. However, the report was overlooked in the next 6 days. Dec 11th- It was discovered that the well had been online for 6 days total(longer than the allowable 5 days) with no State Test Notification made or performing a State Test. The well was shut in and the TP code was corrected to SSSV: SSSV: Maintain / Repair / Remove. State Test notification was made to the State. To prevent this from happening in the future all wells at Alpine with a wireline retrievable SSSV’s with the potential for this same event to occur will be displayed on the SVS Missed State Safety Valve Tests as Managed Alerts on the Board Alarm Summary. This will alert the Board Operators that once the well has been brought online, it needs a State Test. They can then make the appropriate notifications to their supervision. Thank-you for your time in this matter, if you have any further questions, please reach out to myself at 907-263-4749 or Doug McMullen at (907) 315-3601. Thank-you, Greg Greg Hobbs, P.E. Regulatory Engineer | Wells Team ConocoPhillips Alaska Inc. Office: 907-263-4749 Cell: 907-231-0515 Image Projeot 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. - 0~,0 ~ - ~ L~ Well History File Identifier Organizing (done) ^ Two-sided ~I I II II II I~ ~I I II III ^ Rescan Needed 1111111111111 111 111 RE CAN DIGITAL DATA Color Items: ~iskettes, No. ' ~Greyscale Items: ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: ^ Other: NOTES: BY: ~ Maria Date: Project Proofing OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: Q 8 /s/ BY: `Maria Date: ~ ~ /~ I ©`~ /s/ Y ~l' Scanning Preparation _~ x 30 = ~ + 1 ~ =TOTAL PAGES (Count does not include cover sheet) BY: Maria Date: © /s/ Production Scanning II I II'I I~ I' III I I III Stage 1 Page Count from Scanned File:_~ (Count does include cover sh et) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ , JI ~h~ lsl ~~ 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. (I I II ~I'I I I) II I I ilk ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked ifi II~II~~IIII~I~++ P P 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA • > ALA OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon f Repair w ell F Plug Perforations ("" Perforate E • Other ly Scale Inhibition Treatment Alter Casing i Pull Tubing I Stimulate - Frac r' Waiver E Time Extension I Change Approved Program EOperat. Shutdow n fa Stimulate - Other E Re -enter Suspended Well I°' 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. * Development g ' Exploratory r _ 206 -113 3. Address: 6. API Number: Stratigraphic J'""" Service r P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20519 -01 ' 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380077 CD4 - 318A ' 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Colville River Field / Nanuq Kuparuk Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 20612 • feet Plugs (measured) None true vertical 7212 feet Junk (measured) 2500 Effective Depth measured 20162 feet Packer (measured) 14025 true vertical 7212 feet (true vertical) 6863 Casing Length Size MD TVD Burst Collapse CONDUCTOR IN 77 16 114 114 SURFACE 3448 9.625 3485 2377 INTERMEDIATE '1 15661 7 15696 7240 + LINER 'A' 5084 4.5 20607 7213 Perforation depth: Measured depth: slotted liner from 15719 - 20566 �'�`j True Vertical Depth: 7239 - 7214 0 3\1\ i ScM t% Tubing (size, grade, MD, and TVD) 4.5, L - 80, 15541 MD, 7247 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 14025 MD and 6863 TVD NIPPLE - BAL -O nipple @ 2293 MD and 1865 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 15696 -20612 Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 944 2299 5339 -- 348 Subsequent to operation 1017 1911 7516 -- 378 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory 1 .-- Development l • Service E Stratigraphic I 16. Well Status after work: Oil 5.7 . Gas fl WDSPL I- Daily Report of Well Operations XXX GSTOR E VVINJ I WAG fl GINJ E SUSP I- SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Garrett McKee aa. 265 -6549 Email Garrett.L.McKee(a).cop.com Printed Name Garrett McKee Title WNS Engineer Signature r� i - qZ,..4 Phone: 265 -6549 Date 6 , /5/20/ 3 itz-r- RBDMS JUN —'� c ...,_ ( �l4d �� � Form 10 -404 Revised 10/2012 Submit Original Only • • CD4 -318A Scale Inhibition Treatment: 5/16/2013 Initial pressure TBG /IA /OA- 834/1116/VAC; Facility pumped 50 bbls PW preflush; LRS pumped 5.1 bbls WAW5206 (214 gal) at 0.4 bpm while facility pumped 47 bbls PW at 4 bpm, 870/1166/VAC; LRS pumped 51 bbls SCW4004 (2142 gal) at 0.65 bpm while facility pumped 289 bbls of PW at 4 bpm, 666/1111/VAC; facility pumped 1850 bbls of PW and 400 MSCF of gas while LRS pumped 580 bbls dead crude for over - displacement. Final pressures: 1224/343/VAC. Intervals treated: 15696' — 20612' • • WNS 0 CD4 -318A Co�noc ; Well Attributes Max AnStle & MD TD Alaska. Inc. Wel!bore AP W WI Field Name Well Status Inca (°) MD (ftKB) Act Btm (ftKB) l ,� R „_„1,,, 501032051901 NANUQ KUPARUK PROD 94.21 15553.18 20,612.0 Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date "' - SSSV: WRDP Last WO: 43.50 1/20/2006 fi9: Well Con - CD4 -, 5/1312013 9'44'16 AM sche -Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: Show Fish, Attempted CMT OA CSG osborl 5/13/2013 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.250 37.0 114.0 114.0 65.00 H -40 WELDED HANGER, 33 Insulated 36" Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String WL.. String ... String Top Thrd SURFACE 95/8 8.835 36.6 3,485.0 2,376.7 40.00 L - 80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (NO) ... String Wt... String ... String Top Thrd INTERMEDIATE'A; 7 6.276 34.4 15,695.8 7,239.9 26.00 L - 80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd LINER'A' 41/2 3.958 15,522.9 20,607.0 7,212.6 12.60 L -80 SLHT F. Liner Details ,L Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) - - -- 15,522.9 7,247.3 92.84 SLEEVE BAKER 'HR' LINER SETTING SLEEVE 4.420 CONDUCTOR Insulated 36 ". - 15,535.9 7,246.5 93.43 NIPPLE BAKER 'RS' PACKOFF SEAL NIPPLE 4.250 37 - 114 15,539.6 7,246.3 93.59 HANGER BAKER -DG' FLEX LOCK HANGER 4.400 Tubing Strings Tubing Description String 0... lath ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... Str ng ... String Top Thrd TUBING 4 1/2 3.958 32.6 I 15,541.1 7,246,2 I 12.60 L-80 NIPPLE, 2,292 Completion Details WRDP, 2,293 Top Depth 1 31 (TVD) Top Inc! Nomi... Top (ttKB) (ftKB) (°) Item Description Comment ID (in) 32.6 32.6 -0.02 HANGER FMC TUBING HANGER 3.958 2,292.5 1,865.2 64.79 NIPPLE BAL-0 NIPPLE (ID 3.812') 3.812 FISH, 2,500 1 . 14,024.7 6,862.6 63.65 PACKER BAKER PREMIER PACKER 3.875 14,085.9 6,889.7 63.79 NIPPLE HOWCO 'XN' NIPPLE 3.725 15,531.0 7,246.7 93.20 SOS SHEAR OUT SUB 3.850 15,533. 7,246.6 93.30 WLEG WIRELINE ENTRY GUIDE 3.850 ,,,Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth SURFACE, ," ■ (TVD) Top Inc) 37 -3,485 To (ftKB) 3 (ftKB) ( ° ) Description Comment Run Date ID (in) INV: ' 2,292.5 1,865.2 64.79 WRDP ' 3.81" WRDP -2 ON DB LOCK(S/N: HSS- 197) 5/1/2013 0.000 ft 2,500.0 1,955.7 63.28 FISH POSSIBLE WOBBLE RING IN TUBING - DEPTH NOT 5/1/2013 0.000 GAS LIFT, _ KNOWN 5,885 at Perforations & Slots III Shot Top (ND) Btm (TVD) Dens Top (ftKB) Btm VMS) (ftKB) (ftKB) Zone Date (Rh... Type Comment -_ 15,719.0 20,566.0 7,238.9 7,214.2 Miluveach, 9/5/2006 32.0 SLOTS Alternating solid/slotted pipe - GAS LIFT, CD4 -318A 0.125'k2.5" @ 4 circumferential 11,282 adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends Notes: General & Safety End Date Annotation 9/10/2006 NOTE: SIDETRACKED WELL w/SLOTTED LINER; Original 7" cut/pull @ 3645' forS/T 12/4/2009 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT. 5/7/2013 NOTE: CEMENT PUMPED INTO OA ON 5/2/2013 8 5/7/2013 DID NOT HOLD, SHOE STILL OPEN 13,912 ,FL, PACKER, 14,025 NIPPLE, 14,086 -- 1 « 3 31 505, 15,531 : WLEG, 15,533 Mandrel Details Top Depth Top Port (TVD) Inc! 00 Valve Latch Size TRO Run N... Top(ftKB) (ftK (°) Make Model (in) Sery Type Type ON (psi) Run Date Com... 1 5,885.2 3,385.8 64.58 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 2,081.0 8/27/2007 2 11,282.5 5,669.7 65.19 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 4/29/2013 3 13,911.5 6,812.0 63.39 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 4/30/2013 INTERMEDIATE a • 'A 34- 15,696 1 1 SLOTS, ' 1 15,719- 20,588 LINER 'A', 15,523- 20,607 -\ i 1 TD (054- 3188). 20,612 EE , \ \ I %i� s 9 THE STATE Alaska Oil and Gas �_ '� °fALAS� Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS LAS E+ 2Dttl Main: 907.279.1433 LZ �� 6 Fax: 907.276.7542 SG G NE® Jerry Dethlefs Well Integrity Director / 3 ConocoPhillips Alaska, Inc. 1 ©(0 ' P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD4 -318A Sundry Number: 313 -180 Dear Mr. Dethlefs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair / DATED this 1/ da y of April, 2013. Encl. STATE OF ALASKA 1 /1// ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 . . 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Plug Perforations r Perforate r Pull Tubing fl Time Extension r Operational Shutdown r Re -enter Susp. Well f Stimulate fl Alter casing r Other:SC Cement Shoe • SW 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p" • Exploratory r 206 -113 • 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20519 - 01 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r CD4 -318A • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0380077IADL0384209IADL0387209 Colville River Field / Alpine Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): ' 20612 •7212 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 3448 11 3485' 2375' INTERMEDIATE 'A; 15661 10 15696' 7239' LINER'A' 5084 5.92 20607' 7212' Perforation Depth MD (ft): , Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner from 15719' 20566' 7239' - 7214' 4.5 L - 15531 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) HANGER - FMC TUBING HANGER MD= 33 TVD= 33 PACKER - BAKER PREMIER PACKER " MD= 14025 TVD= 6863 NIPPLE - HOWCO 'XN' NIPPLE • MD= 14086 TVD= 6890 SOS - SHEAR OUT SUB • MD= 15531 TVD= 7247 WLEG - WIRELINE ENTRY GUIDE • MD= 15533 TVD= 7247 12. Attachments: Description Summary of Roposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development p°' Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/13/2013 Oil r'• Gas f WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR F SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jerry Dethlefs Email: jerrv.c.dethlefs@conocoohillips.com Printed Name Dethlefs Title: Well Integrity Director Signature , ! G Phone: 265 -1464 Date: T/./5 Commission Use Only n Sundry Number: 315..1 gt Conditions of approval: Notify Commission so that a representative may witness f Plug Integrity r BOP Test r Mechanical Integrity Test [ Location Clearance r Other: Ofr(iW§ ' br ,' ; Spacing Exception Required? Yes ❑ No a Subsequent Form Required: /0 — 40 9 APPROVED BY 4 - // /3 Approved by: COMMISSIONER THE COMMISSION Date: /� t l) I 1, Approved application is valid for 12 months from the date of approval. Q n Rt vi 1 e N 2 % (, F +1)11 l Submit Form and Attachment • Du licate ` � \ � \N Jerry Dethlefs Well Integrity Director ConocoPhillips Alaska, Inc. ConocoPl'ull1 5 8 An G Street Anchorage, AK 99510 Phone 907 - 265 -1464 April 10, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well CD4 -318A, PTD 206 -113 for pumping a surface casing cement shoe. Please contact me at 907 265 -1464 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Well Integrity Director Enclosures: Description Summary of Proposal 10 -403 Application for Sundry Approvals CD4 -318A Wellbore Schematic ConocoPhillips Alaska, Inc. Kuparuk Well CD4 -318A (PTD 206 -113) SUNDRY NOTICE 10 -403 REQUEST 4/10/13 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to pump a cement shoe in the surface casing of Alpine CRU development well CD4 -318A. A surface casing cement shoe was not pumped at the time of original completion in 2006. The cement shoe is required in order to pressure test the surface casing and to locate and verify the size of a suspected surface casing corrosion penetration. With approval, the OA cement shoe will require the following general steps: 1. Pump cement designed for a 1000' linear shoe in the OA. 2. Displace cement with freeze protection fluids 3. Wait 48 hrs on cement 4. MITOA to 1800 psi and / or establish LLR. 5. If MITOA fails establish circulation to conductor and locate leak 6. Submit 10 -404 to AOGCC. NSK Problem Well Supervisor 4/10/2013 WNS CD4 -318A Iv moot_ ,, Cd'70 Thp6 ', Well Attributes Max Angle & MD TD Alaska, Inc. Wellbore API/UWI Field Name Well Status loci ( °) MD (MB) Act Btm (MB) 501032051901 NANUO KUPARUK PROD 94.21 15,553.18 20,612.0 Comment H2S (ppm) Date Annotation End Date KB-Ord (R) Rig Release Date ••• WellConfia - CD4-318A,129/20131001.03AM SSSV:WRDP Last WO: 43.50 1/20/2006 Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: WELL REVIEW, RESET WRDP osborl Casing Strings __ -- Casing Description String 0... String ID ... Top (MO) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.250 37.0 114.0 114.0 65.00 H-40 WELDED Insulated 36" HANDER, 33 �" Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd r SURFACE 95/8 8.835 36.6 3,485.0 2,376.7 40.00 L - 80 BTC Casing Description String 0... String ID ... Top (RKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd INTERMEDIATE'A; 7 6.276 34.4 15,695.8 7,239.9 26.00 L - 80 BTCM 1'. P Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER'A' 41/2 3.958 15,522.9 20,607.0 7,212.6 12.60 L -80 SLHT [Liner Details Top Depth Cr- r. (TVD) Top Inc! Noml... Top (MB) (RKB) ( °) Item Description Comment ID (in) 15,522.9 7,247.3 92.84 SLEEVE BAKER 'HR' LINER SETTING SLEEVE 4.420 CONDUCTOR 15,535.9 7,246.5 93.43 NIPPLE BAKER 'RS' PACKOFF SEAL NIPPLE 4.250 Insulated 15,539.6 7,246.3 93.59 HANGER BAKER -DG' FLEX LOCK HANGER 4.400 37-114 ", Tubing Strings Tubing Description String 0... String ID ... Top (ttKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 41/2 3.958 32.6 15,541.1 7,246,2 12.60 L -80 NIPPLE, x292 , o Completion Details WRDP, 2,293 Top Depth (ND) Top lne! Noml... Top (MB) (RKB) ( °) item Description Comment ID (in) 32.6 32.6 -0.02 HANGER FMC TUBING HANGER 3.958 2,292.5 1,865.2 64.79 NIPPLE BAL-0 NIPPLE (ID 3.812 ") 3.812 14,024.7 6,862.6 63.65 PACKER BAKER PREMIER PACKER 3.875 14,085.9 6,889.7 63.79 NIPPLE HOWCO 'XN' NIPPLE 3.725 15,531.0 7,246.7 93.20 SOS SHEAR OUT SUB 3.850 SURFACE, 15,533.1 7,246,6 93.30 WLEG WIRELINE ENTRY GUIDE 3.850 373,485 Other In Hole (Nireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! GAS LIFT, _ _ r ._ , � ; Y-y Top (ftKB) (RKB) ( °) Description Comment Run Date ID (!n) 5.885 _ 2,292.5 1,865.2 64.79 WRDP 3.81 " WRDP -2 (S/N: HRS -282) 1/9/2013 0.000 Perforations & Slots Shot Top (TVD) Min (TVD) Dens Top (RKB) Btm (RKB) (RKB) (RKB) Zone Date (ah••• Type Comment ucT, - -- 15,719.0 20,566.0 7,238.9 7,214.2 Miluveach, 9/5/2006 32.0 SLOTS Altemating solid/slotted pipe - GAS 11 282 c CD4 -318A 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered I 18 deg, 3' non - slotted ends Notes: General & Safety End Date Annotation ■ 9/10/2006 NOTE: SIDETRACKED WELL w/SLOTTED LINER; Original 7" cut/pull © 3645' for S/T 12/4/2009 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT, ,. 13,912 ° PACKER, 14025 Et at NIPPLE. 14,086 II SOS, 16531 WLEG, 15,533 Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run N... Top MKS) (RKB) ( °) Make Mode! (In) Sery Type Type (In) (p ail Run Date Com... 1 5,885.2 3,385.8 64.58 CAMCO KBG -2 1 GAS LIFT GLV BK 0.188 2,081.0 8272007 2 11,282.5 5,669.7 65.19 CAMCO KBG -2 1 GAS LIFT GLV BK 0.188 2,125.0 8/26/2007 INTERMEDIATE • ' 3 13,911.5 6,812.0 63.39 CAMCO KBG -2 1 GAS LIFT OV BK 0.438 0.0 8/26/2007 'A 34- 15,666 E1 1 SLOTS, I I 15,719. 20,566 LINER 20,607 i 15.523 -2Q60', TD (0043184 20,612 • • (At. 064 -3s P 7.1 2 06(130 Regg, James B (DOA) From: NSK Problem Well Supv (n1617 @conocophillips.com] �� /A-161t Sent: Sunday, April 07, 2013 12:40 PM To: Wallace, Chris D (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: CRU CD4 -318A (PTD 206 -113) Report of SC leak Attachments: CD4 -318A schematic.pdf Chris, Jim, Guy Alpine gas lifted producer CD4 -318A (PTD 206 -113) has been diagnosed with a surface casing leak. The leak is suspected to be at approximately 45' down from surface. Using fluid level shots to identify the leak depth, nitrogen leaked to surface via the conductor by surface casing annulus. However the fluid appeared to be pushed out the bottom of the open OA shoe. The TIFL passed to confirm tubing (down to the packer) and production casing integrity following the discovery of the leak. The well was SI after the TIFL was completed. A plan forward for repair or continued production will be discussed and the appropriate paperwork will be submitted. Attached is a 90 day TIO plot and wellbore schematic. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor j - LJ12a kt45 (x'e. ,,ccej 4 , ndt ,,,,6,_ ConocoPhillips Alaska, Inc. — { Desk Phone (907) 659 -7224 l`s Pager (907) 659 -7000 pgr. 909 SCANNED AIL 1 0 2013 1 m.. CRU CD4-318A PTD 2061130 4/7/2013 TIO Pressures Plot WELLS WLHD CURRENT VALUE CURRENT VALUE CURRENT VALUE CURRENT VALUE OPERATOR NOTES SET CHOKE 0. CHOKE 0. LIFT RATE O. STATIC PR FTP 1052. ROR OIL ?Mr?? LG CHOKE 0.0 FTT 59. ROR LG 7777 LG SETPT IGV/OGV LG ORIF LG ORI DP CASING PRE 1993. LG CPRIME - _ g_____ I. 4111 - s77,.7us inn 2100 i OFF 2100. t GENERAL PURPOSE 150. inr -IA 111 Pm EVENT . 118600 1111111 OPEN/SI 2100 1111111 . 1000. 0.00 i11111111 W EVEN CREATE 11 , T AT PICK TIME 2100. 1470 I 11 2100. I i WELL 1260 _ PI NOTE AT I PICK TIME WW 1050 .' FREEZE 0 1111 840 I 1. "* . PROTECTION MP 111, 1 --- - i l l i - 1 , 4 1 ... 11 W PREV WELL gni 630 PINEXT WELL 4 1pir 411.1411 " 1611114611111 0 1111111 41 4 - inis sti ,_______ 00 ,... 11 . 100 . 0 au a 0. pi II it 0 64 jIS 100. VIEW SDL 210 III O. A ■ El ilr CREATE SDL 0 A 3.00 I III VIEW EDL O. 0 00 ER SCALE DESC PICK VALUE LATEST 7 ATION U CREATE EDL . Will CHOKE 100. q. 2160 OURS 07 06:20 I NM FTP 330. 1052. pir ANNCOM PROBLEMS I PM FIT 137. 59. I I 1 MIE 4W OW rff 111F Flags: Ili pm CASING P 1964. 1993. 700M TUG: WIll LIFT RATE 127. 0. MINOR TIME IA: Orr" ORIF-DP ??????? e HOURLY an r 1 .1 MAJOR TINFWEEK r OA: I Por IA PRES 1964. 84 -T1 r PICK TTY 02-APR 20:10:47 00A/Tree: R. OA PRES -0. 0. 1 WNS CD4 -318A - COtx coF :In �ipS a u Well attributes Max Angie & MD TD y Wellbore API /UWI Field Name Well Status Incl (1 MD (ftKB) Act Btm (ftKB) r Alaska Jrtr, 1n 501032051901 NANUQ KUPARUK PROD 94.21 15,553.18 20,612.0 CorxxoPh ., ' Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date Well conrg - C134 - imams AM SSSV: WRDP Last WO: 43.50 1/20/2006 Sohon lrc -Agyad Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: WELL REVIEW, RESET WRDP osborl Casing Strings Casing Description String 0.., String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd y CONDUCTOR 16 15.250 37.0 114.0 114.0 65.00 H-40 WELDED v Insulated 36" MANGER, 33 Casing Description String 0... String ID ... Top (ftKB) Set Depth ( f... Set De h ( TVD) ... Strin Wt... Strin String T Thrd T 9 P g 9 P( ) Pt 9 9 ��� 9 P ' - r " SURFACE 95/8 8.835 36.6 3,4 85 . 0 2 40 L -80 BTC Cooing Description String 0... String ID ... Top (ftK8) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd '= INTERMEDIATE'A; 7 6.276 34.4 15,695.8 7,239.9 26.00 L - 80 BTCM t , ; r Casing Description String 0... String ID ... Top (91(5) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd • LINER 'A' 41/2 3.958 15,522.9 20,607.0 7,212.6 12.60 L -80 SLHT „ Liner Details Top Depth ars (TVD) Top Inc! . Top (ttKB) (ttK ( °) Rem Description Comment ID (in) 15,522.9 7,247.3 92.84 SLEEVE BAKER 'HR' LINER SETTING SLEEVE 4.420 CONDUCTOR 15,535.9 7,246.5 93.43 NIPPLE BAKER 'RS' PACKOFF SEAL NIPPLE 4.250 Insulated 36"' 37 15,539.6 7,246.3 93.59 HANGER BAKER -DG' FLEX LOCK HANGER 4.400 • 37 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 41/2 3.958 32.6 15,541.1 7,246.2 12.60 L -80 NIPPLE, 2,29 I Completion Details WRDP, 2,293 Top Depth lit (TVD) Top Incl Top (ftKB) (MB) C) Rem Description Comment ID (in) 32.6 32.6 -0.02 HANGER FMC TUBING HANGER 3.958 2,292.5 1,865.2 64.79 NIPPLE BAL-O NIPPLE (ID 3.812 ") 3.812 14,024.7 6,862.6 63.65 PACKER BAKER PREMIER PACKER 3.875 14,085.9 6,889.7 63.79 NIPPLE HOWCO 'XN' NIPPLE 3.725 15,531.0 7,246.7 93.20 SOS SHEAR OUT SUB 3.850 SURFACE, 15,533.1 7,246.6 93.30 WLEG WIRELINE ENTRY GUIDE 3.850 37 -3,485 Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) iik'. Top Depth (TVD) Top Incl GAS LIFT, Top (ftKB) )RKB) (°) Description Comment Run Date ID (in) sass ' �� 2,292.5 1,865.2 64.79 WRDP 3.81" WRDP -2 (S /N: HRS -282) 1/9/2013 0.000 at Perforations & Slots Shot Top (TVD) BM, (TVD) Dens -`, Top (RKB) Btm (RKB) (ftKB) (ftKB) Zone Date (sh'° Type Comment GAS LIFT, 15,719.0 20,566.0 7,238.9 7,214.2 Miluveach, 9/5/2006 32.0 SLOTS Alternating solid/slotted pipe - 11 zT, CD4 -318A 0.125 "x2.5" @ 4 circumferential � 18 deg, 3' staggered non-slotted ends Notes: General & Safety End Date Annotation 9/10/2006 NOTE: SIDETRACKED WELLw /SLOTTED LINER; Original 7" cut/pull @ 3645' for S/T ' 12/4/2009 NOTE: View Schematic w/ Alaska Schematic9.0 GAS 3.912 .912 II PACKER, 14,025 ill ti NIPPLE, 14,086 'ill SOS, 15,531 WLEG. 15.533 .� Mandrel Details Top Depth Top Port S,,, (TVD) Inc! OD Valve Latch Size TRO Run N... Top (ftKB) (ftKB) )°) Make Model (in) Sery Type Type (!n) (psi) Run Date Com... 1 5,885.2 3,385.8 64.58 CAMCO KBG -2 1 GAS LIFT GLV BK 0.188 2,081.0 8/27/2007 2 11,282.5 5,669.7 65.19 CAMCO KBG -2 1 GAS LIFT GLV BK 0.188 2,125.0 8/26/2007 INTERMEDIATE • 3 13,911.5 6,812.0 63.39 CAMCO KBG -2 1 GAS LIFT OV BK 0.438 0.0 8/26/2007 'A„ 34 15,696 ...1 1 SLOTS, 1 1 15,719- 20,566 LINER 15523-20,607 IN2 'A TD (CD4- 318A), 20612 STATE OF ALASKA RECEIVED AL,A OIL AND GAS CONSERVATION COM SION , ,UN 14 2012 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repairwell r Plug Ferforations r Perforate r Other AQ ° Alter Casing 1 Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory r _ • 206 -113 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 A 50 - 103 - 20519 - 00 7. Property Designation (Lease Number): A i 8. Well Name and Number: ADL 380077 c3 8 lazy 1 381"+ ao 1 Co' . CD4 - 318A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): .. none Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 20612 feet Plugs (measured) none true vertical 7212 feet Junk (measured) none Effective Depth measured 20612 feet Packer (measured) 14025 true vertical 7212 feet (true vertucal) 6863 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 3448 9.625 3485 2375 INTERMEDIATE 15661 7 15696 7239 LINER 5084 4.5 20607 7212 ... Perforation depth: Measured depth: 15718' 20565' True Vertical Depth: 7239' - 7214' 54ANNEDJUL 24 ZU3Z Tubing (size, grade, MD, and TVD) 4.5, L -80, 15541 MD, 7247 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 14025 MD and 6863 TVD SSSV - BAL-0 NIPPLE @ 2293 MD and 1865 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 15718'- 20565' Treatment descriptions including volumes used and final pressure: see attachment 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 1107 3012 5017 -- 371 Subsequent to operation 1194 4103 5857 -- 371 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17 .. Service r Stratigraphic r 16. Well Status after work: ,, Oil p Gas "" WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact David Neville as 265 -6402 Printed Name D id Neville Title Alpine Production Engineer Signature Phone: 265-6402 Date C A 3,,'! '2. akie o DMS JUN 15-101ldr fL 6.p-cit., Form 10 -404 Revised 11/2011 7Yi V'1 7/L3/,/, Submit Original Only I ' • • Scale Inhibition Treatment: CD4 -318A 5/19/2012: Initial pressure TBG/IA/OA — 782/1928/219; Facility pumped 50 bbls SW preflush at 4 bpm; LRS pumped 3 bbls WAW5206 (132 gal) at 0.4 bpm while facility pumped 29 bbls of SW at 4 bpm, 302/1831/116; LRS pumped 31 bbls SCW4004 (1320 gal) at 0.65 bpm while facility pumped 178 bbls of SW at 4.3 bpm, 0/1758/100; facility pumped 1491 bbls of SW over - displacement at 4.3 bpm. .,,,-,. WNS • CD4 -318A ConocoPhillips i Well Attributes Max Angle & MD TD Ala inc Wel!bore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) 501032051901 NANUQ KUPARUK PROD 94.21 15,553.18 20,612.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: WRDP Last WO: 43.50 1/20/2006 Well Conk, - CD4-318A 7112120112: 47 58 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: RESET WRDP ninam 7/22/2011 Casing Strings -- - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.250 37.0 114.0 114.0 65.00 H -40 r Insulated 36" HANGER. 33 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd a.. r SURFACE 95/8 8.835 36.6 3,485.0 2,376.7 40.00 L - 80 .tY Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd • ^ INTERMEDIATE 7 6276 34.4 15,695.8 7,239.9 26.00 L - 80 P Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 41/2 3.958 15,522.9 20,607.0 7,212.6 12.60 L -80 ,Liner Details Top Depth (TVD) Top Inc! Noml... I Top (ftKB) (ftKB) Item Description 15,522.9 7247.3 Comment ID (in) ,247.3 92.54 SLEEVE BAKER'HR' LINER SETTING SLEEVE 4.420 CONDUCTOR 15,535.9 7246.5 93.43 NIPPLE BAKER 'RS' PACKOFF SEAL NIPPLE 4.250 Insulated 36 37 - 114 15,539.6 7,246.3 93.59 HANGER BAKER -DG' FLEX LOCK HANGER 4.400 15,549.3 7,245.7 94.04 XO- Reducing CROSSOVER 5x4.5" 4.000 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD)... String Wt... String ... String Top Thrd NIPPLE. 2,292 _ - TUBING I 41/2 I 3.958 I 32.6 I 15,541.1 I 7,246.2 I 12.60 L-80 WRDP, 2,293 Completion Details 1 MI Top Depth (TVD) Top Inc! None.. Top (ftKB) (MB) ('3 Item Description Comment ID (in) i 32.6 32.6 -0.02 HANGER FMC TUBING HANGER 1958 2,292.5 1,865.2 64.79 NIPPLE BAL-0 NIPPLE (ID 3.8121 3.812 14,024.7 6,862.6 63.65 PACKER BAKER PREMIER PACKER 3.875 14,085.9 6,889.7 63.79 NIPPLE HOWCO 'XN' NIPPLE 3.725 SURFACE. 15,531.0 7,246.7 93.20 SOS SHEAR OUT SUB 3.850 37 - 3,485 - - -- 15,5331 7,246.6 93.30 WLEG WIRELINE ENTRY GUIDE 3.850 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT, Top Depth 5,885 c--. (TVD) Top Intl Top (ftKB) (ftKB) (°) Descri ption Comment Run Date ID (in) a l 2,293 1,865.2 64.79 WRDP WRDP (HVS -268) 7/21/2011 2.125 aill Perforations & Slots I IM Shot Top (ND) Blm (ND) Dens GAS LIFT, Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date ( Type Comment 11.282 15,719 20,566 7,238.9 7,214.2 Miluveach, 9/5/2006 32.0 SLOTS Alternating solid/slotted pipe - CD4 -318A 0.125 "x2.5" @ 4 circumferential _ _ adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends I Notes: General & Safety End Date Annotation 9/10/2006 NOTE: SIDETRACKED WELLw /SLOTTED GAS LIFT ,.. 12/4/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 13.912 PACKER, 14,025 NIPPLE, 14,086 1 SOS, 15,531 WLEG, 15,533 Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (°) Make Model (in) Sery Type Type (!n) (psi) Run Date Com... 1 5,885.2 3,385.8 64.58 CAMCO KBG 1 GAS LIFT GLV BK 0.188 2,081.0 8/27/2007 2 11,282.5 5,669.7 65.19 CAMCO KBG 1 GAS LIFT GLV BK 0.188 2,125.0 8/26/2007 NTERMEDIATE, • 3 13,911.5 6,812.0 63.39 CAMCO KBG 1 GAS LIFT OV BK 0.438 0.0 8/26/2007 34. 15,696 SLOTS, I 1 1 1 1 15,719-20,566 LINER, 15,523- 20,607 - \ , i I , TD (CD4-318A), 20,612 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI• REPORT OF SUNDRY WELL OPERATIONS 16--/-6.t( 1. Operations Performed: Abandon f ` Repair well f °"` Plug Fbrforations f Stimulate Other S c I" 134 ' Alter Casing r Pull Tubing r Ferforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p' Exploratory r ... 206 - 113 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 • 50 - 103 - 20519 - 00 7. Property Designation (Lease Number): , V 7/4-> ) 8. Well Name and Number: ADL 380077 ,...if � :./ 02' . 3' l 0 7 -, CD4 - 318A 9. Field /Pool(s): / Colville River Field / Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 20612 feet Plugs (measured) None true vertical 7212 feet Junk (measured) None Effective Depth measured 20612 feet Packer (measured) 14025 true vertical 7212 feet (true vertucal) 6863 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 3448 9.625" 3485 2375 INTERMEDIATE 15661 7" 15696 7239 LINER 5084 4.5" 20607 7212 Perforation depth: Measured depth: slotted liner 15718' 20565' ; , 1 '01 True Vertical Depth: 7239' -7214' Yi !x �' n r� a �1eY MtrA�. 7� t! . ?, �,9 ii:2 13 j�t 1yt r)WflftSSIiOil N r r.4ctwe Tubing (size, grade, MD, and TVD) 4.5, L - 80, 15541 MD, 7247 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 14025 MD and 6863 TVD NIPPLE - BAL-0 NIPPLE @ 2292 MD and 1865 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 15718'- 20565' Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 1933 2352 5823 -- 344 Subsequent to operation 1722 2199 6435 -- 344 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development R►0 Service r Stratigraphic r 15. Well Status after work: , Oil Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG f GINJ r SUSP r SPLUG I 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tim Schneider (a, 265 -6859 Printed Name Tim Schneider Title Staff Production Engineer Signature ,-- / ,, Phone: 265 -6859 Date 7 -- S - / /; z z i RBDMS 111L 0 6 2011 `` 47 2 Z ? /" Form 10 -404 Revised 10/2010 Submit Original Only i • • 4 -318A • '{JI- t�� l ;\ WellA N.S. weu s�ai�s Max Angl B M O D ��a D t.n(eKe) Field Name i 501032051901 jNANUO KUPARUK Comment PRO 94 1595 3.18 20,6120 An otat on End Date KB - Grd (ft) Rig Release Date Weu pone . c 318!1, 6/1af2410 1 : s apn , SSSV WRDP l H25 (ppm) Date Last WO 1 I 43 50 - , 1/20/2006 Alaska, Inc,. - ' "" 9 A 4 $, Annotation (Depth (ftK6) (End Date Annotation Last Mod ... End Date Last Tag Rev Reason' RESET WRDP Imosbor 6/14/2010 Casin r Strin s Casing Description String 0 String ID ... Top (ftK6) Set Depth (1... Set Depth (ND) ... String Wt.. l String ... String Top Thrd .-5E.,;: CONDUCTOR 16 15.250 37.0 114.0 114.0 65.00 H -40 Insulated 36" HANGER, 33 Casing escdpton String 0... String ID ... Top (MB) Set Depth (f.., Set Depth (ND) ... String Wt... String String Top Thrd n9 9 P 9 9 •- nB op - r SURFACE 9 5/8 8.835 36.6 3,485.0 2,376.7 40.00 L ,� .�. Casing Description String 0... String ID ... Top Off) Set Depth (E.. Set Depth (TVD) ... String WI... String ... String Top Thnt P INTERMEDIATE 7 6.276 34.4 15,695 8 7,239.9 26.00 L ig I- Casing Deserpton String 0... String ID ... Top O1K8) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd I - 'LINER 41/2 3958 15,5229 206070 7,2126 1260 L-80 Liner Details Top Depth I (TVD) Top Inc! Nomi... To• • B ( (1 Item Description Comment ID On) 15,522.9 7,247.3 92.84 SLEEVE BAKER 'HR' LINER SETTING SLEEVE 4.420 CONDUCTOR 15,535.9 7,246.5 93.43 NIPPLE BAKER 'RS' PACKOFF SEAL NIPPLE 4.250 615W81 37 - 114 . 15,539.6 7,246.3 93 - 59 HANGER BAKER - DG' FLEX LOCK HANGER 4.400 37 15549.3 7,245 7 94 041 cin XO- Redug CROSSOVER 5x4 5 4.000 Tubing Strings « Tubing Description String 0... String ID ... Top (ftK6) Set Depth (i... Set Depth (ND) D( .. String Wt... String ... String Top Thrd NWRDIPPLE, P,2,000 2,2x2 --- TUBING 41/2 3.958 32.6 15,5411 7,246.2 12.60 L80 _.. _. _ -- Completion Details Top Depth (ND) Top (eel Top (ft(B) ( B) C) Item DescLiI tion Comment ID (in) I "' 'r 32.6 32.6 -0.02 HANGER FMC TUBING HANGER Ell 'I 2,292.5 1,865.2 64.79 NIPPLE BAL-O NIPPLE (ID 3.812") w/PACKOFF DUMMY (ID 2.75") 2.750 14,024.7 6,862.6 63.65 PACKER BAKER PREMIER PACKER 3.875 14,085.9 6,889.7 63.79 NIPPLE HOWCO'XN' NIPPLE 3.725 SURFACE, ; 15,531.0 7,246.7 93.20 SOS SHEAR OUT SUB 3.850 37 - 3,485 - 15,533.1 7,246.6 93.30 WLEG WIRELINE ENTRY GUIDE 3.850 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT, Top Depth I 5,885 (TVD) Top Inc! Top (ftKB) MKS) (°) Description Comment Run Date ID ( 1 _: 2,293 1,865.2 64.79 WRDP 3.812" WRDP (S /N: HRS -277) 5/30/2010 2.125 Ift Perforations & Slots snot Top (TVD) Btm (TVD) Dens GAS LIFT, _ _.___ - ; Comment Top (flKB) Btrn NIKB) (flKB) (ftK6) Zone Date (sh.,. Type Comment t 7.282 , ,, .. 15,719 20,566 7,238.9 7,214.2 Miluveach, 9/5/2006 32.0 SLOTS Alternating solid/slotted pipe - CD4-318A 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered '- -- " 18 deg, 3' non - slotted ends Notes: General & Safety - End Date Annotation 9/10/2006 NOTE: SIDETRACKED WELL w /SLOTTED GAS Urr, 12/4/2009 Schematic9.0 NOTE: VIEW SCHEMATIC w /Alaska Scheauc9.0 3,912 PACKER, __. 4,025 NIPPLE, 14,086- --'' 1 1 SOS, 15,531 i E , i ', l WLEG, 15,533 _ -- Mandrel Details Top Depth Top Port (TVD) Inc' OD Valve Latch Size TRO Run ' Stn Top (flKB) (ftK6) ( °) Make Model (in) Sere Type Type (in) (Psi) Run Date Com... J 1 5,885.2 3,385 -8 64.58 CAMCO KEG 1 GAS LIFT GLV BK 0.188 2,081.0 8272007 2 11,282.5 5,669.7 65.19 CAMCO KBG 1 GAS LIFT GLV BK 0.188 2,125.0 8/26/2007 - NTERMEDIATE, 3 13,911.5 6,812.0 63.39 CAMCO KBG 1 GAS LIFT OV BK 0.438 0.0 8/26/2007 34- 15,696 ::I 1° SLOTS, ;1 i'. 15,719- 20,566 .. - LINER, 15 CD4'3t A(. TD (CD4 -2 20,612 ,612 • • CD4 -318A Scale Inhibitor Summary 5/26/2011: Initial pressure TBG /IA /OA- 453/1990/650; facility pumped 50 bbl SW preflush; facility pumped 29 bbls SW at 4.6 bpm, LRS pumped 132 gal WAW5206 at 0.5 bpm, 453/1954/413; facility pumped 178 bbls SW at 2.8 bpm, LRS pumped 1320 gal SCW4004 at 0.5 bpm, 57/1909/115; facility pumped 1865 bbl SW overflush at 6.9 bpm. ~~, '- ~ ~; -~ ~~ ~ s. rt w ~ f ~°% ~'.~ c yfi .;~ i " i. s• j s .~ ~":. t gyk l ti , ~ MfCROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ^ C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc i Memorandum ~ zoG - i~3 State of Alaska Oil and Gas Conservation Commission To: Colville River Unit Well History File #205-196 July 27, 2006 Colville River Unit Well History File #206-113 Re: Administrative Abandonment Action Caused by Deepening of Existing Wellbore Administratively Abandoned Wellbore: Colville River Unit CD4-318 Permit #205-196 Extension Wellbore: Colville River Unit CD4-318A Permit #206-113 This memo will remain at the front of the subject well files. Colville River Unit ("CRU") well CD4-318A (permit #206-113, API # 50-103-20519-01) will replace CD4-318 (permit #205-196, API # 50-103-20519-00) effective the date that permit 206-113 is approved by the Commission. CRU CD4-318A incorporates an extension to a new bottom hole location from the existing CRU CD4- 318 well bore. This extension, along with the original well bore, will be used for production of hydrocarbons. A review of the well history file for CD4-318 and the proposed operations in CD4-318A indicates administrative abandonment of the originating well bore is appropriate according to current Commission procedures for wells when an additional permitted extension is drilled from an existing well bore. 20 AAC 25.005(a) requires a Permit to Drill for each hole drilled below the conductor unless drilled to straighten the original hole, sidetrack junk, or correct mechanical difficulties. In addition, Commission databases require each conductor has only one permit number and API number. Administrative abandonment of the original well bore only eliminates duplication in databases. Information for the original well and its replacement will be maintained in their respective files. The operator has been notified of this action. All future correspondence with the Commission should reflect the new well name, permit number, API number and well data. ~~~ti ~~' Petroleum Geolo ist ~' Z'7' b ~ retroleum Engtneer ,,~ ~ ,,., ~`.~'` ~ z gm ,~ --~ Reservoir En ~ eer ~. / ~6 STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMIS•N REPORT OF SUNDRY WELL OPERATIONS RECEIVED FEB 2 2 2010 ~. operations Performed: Abandon ~ Repair w ell Plug Perforations ~"" Stimulate r Alaska OII~~f~"~+ISIGi. ommtsston Alter Casing Pull Tubing ~""°` Perforate New Fbol ~ Waiver Time Extensior~tj~fj~CBg~ Change Approved Program '"` Operat. Shutdown ("` Perforate '°" Re-enter Suspended Well '"" 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ~ 206-113 3. Address: Stratigraphic Service .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20519-01 7. Prop@rty Designation: 8. Well Name and Number: ADL 380077 ~. CD4-318A Field/Pool(s): ~ a1 ~ ' t olville River Field / Adrt~.~utaarl~,Pool L ~ 10. Present Well Condition Summary: Total Depth measured 20612 feet Plugs (measured) None true vertical 7212 feet Junk (measured) None Effective Depth measured 20612 feet Packer (measured) 14025 true vertical 7212 feet (true vertucal) 6863 Casing Length Size MD TVD Burst Collapse CONDUCTOR IN 77 16 114 114' SURFACE 3448 9.625 3485 2375' - - INTERMEDIATE 15661 7 15696 7239' LINER 5084 4.5 20607 7212' Perforation depth: Measured depth: slotted liner from 1 571 9-20566' True Vertical Depth: 7239'-7214' Tubing (size, grade, MD, and TVD) 4.5, L-80, 15541 MD, 7247 TVD Packers 8~ SSSV (type, MD, and TVD) PACKER -BAKER PREMIER PACKER @ 14025 MD and 6863 TVD NIPPLE - BAL-O NIPPLE (ID 3.812") w/PACKOFF DUMMY (ID 2.75") @ 2292 MD and 1865 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): See attachment Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 4873 7836 3140 -- 423 Subsequent to operation 4152 6997 3938 -- 440 13. Attachments Well Class after proposed work: Copies of Logs and Surveys run Exploratory Development ~' Service 5. Well Status after work: Oil Gas "' WDSPL Daily Report of Well Operations XXX GSTOR "` WAG ~"°` GASINJ "° WINJ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. sundry Number or N/A if C.O. Exempt: none contact Brian Barreda ~ 265-6036 Printed Name Brian Barreda Title WNS Production Engineer ~ Signature F? Phone: 265-6036 Date ~"y ~' . Y v~.t,',., ~ G~'~SCC.--.. Form 10-404 Revised 7/2009 f'iBDMS fE6 2 ~ Z0~1 ~~ :~ ~'-'moo Submit Original Only • L~ CD4-318 Job pumped 20:00 on 1/31/2010 by T.Lundstrom. Pumped an aqueous scale squeeze into well. Consisted of 258 bbl preload PW pumped from the facility. 35 bbls pre- flush w/PW+5206 (111 gallons) chemical pumped at 4 BPM while the well went on VAC. LRS unit pumped 252 bbls PW+4004 (1375 gal) at 4 BPM, well on VAC. Facility pumped 1480 bbls of PW overdisplacement at 6.5 bpm. Job pumped as planned. Well freeze protected with 45 bbls of diesel. Well SI for 12 hours before returning back to production. ConocdPh~ilips shi. IrY;. ... ,,, ~T ~y'gll CO f 3 CJd-3 8q. 12/d _ SG -~..1,ic-AC HANG.R. 33 colvoucroR Insulaietl 36', 3]116 NIPPLE, 2,292 WRDP, 2.253 -~' SURFACE. 3]-3,485 GAS LIFT, _ 5.886 GAS LIFT, 11,282 GAS LIFT, _- - -__-_ 13,512 PACKER. 14,626 NIPPLE. 14 066 - SOS, 15,531 WLEG, 16.533 - --- ~ WNS all Attributes _, (bore APVUWI Field Name 501032051901 NANUO KUPARUK CD4-318A Well Slatus Intl (°) MD (kKB) PROD 94.21 15,553.18 ~Canment H2S (pplell Annotation Entl Date Date KB-Grd (it) ~.i Rig Release Date SSSV: WRDP ( ( Last WO: 43.50 1120/2006 Annotation (Depth (ftK6) Ena D t Annotation iLasi MOtl ... /End Date ( IILast Tag Rev Reason: OC TALLIES i Imosbor 12/4/2009 I Casin Strin s - ---- ------ - - Casing Description String 0... String ID Top (ftKe) Set Depth (t... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15250 37.0 114.0 114 0 65.00 H-40 Insulatetl 36" Casing Description String 0... String ID ... Top (ftK6) Set Depth (i... Set Depth (ND) ... Siring Wi... String ... String Top Thrd SURFACE 95/8 9.A35 366 3,485.0 2,376.7 40.00 L-80 _ String ID ... Top (ftK6) Sat Depth (f... Set Depth (ND) ... Casing Description String 0... String Wt... String ... String Top Thrd ( 6 'I6 34.4 15,695.8 7,239.9 INTERMEDIATE 7 26.00 L 80 _ - ~ Casing Description Siring 0... '~Str g ID _ Top (NKBJ Set Depth (f... Set Depth (ND) .. String WL.. Str g ... String Top Thrd LINER 41/2 ~ i. NSF', 15,522.9 20,607.0 7,212.6 I 12.60 L 80 ~., - _ -. _-_ Liner Details _. _ __ _ - _ ToP Depth (ND) Top Intl Nomi... Top (NKBJ (ftK6) (°) Item Description Comment ID (1n) SLEEVE BAKER'HR'LINER SETTING SLEEVE 15.522.9 7.2473 92.84 4420 I 7,246.51, 93.43'NIPPLE BAKER'RS' PACKOFF SEAL NIPPLE 1, _ 4.250 7.24C.3, 93.59HANGEI? BAKER -DG' FLEX LOCK HANGER i . S,b 9 4 400 ; ~ ~~ 3 /,245. T', 94.04 XO-Reducing CROSSOVER 5x4.5" 4 _000 TUt)In9 Strln95 ., _ g g p( p ( ( ).. .. Str ID To NK81 Set De th f... Set Depth ND Tobin Des g pion Str g Str g...'Siring Top Thrd St in Wt-' -- ~- ~ 1 2 ,i .SF, 132.6 15,541.1 7.246.2 I USING 12.60 L 80 __.._-- Completion Details Top Depth _____ (NDJ Top Intl Nomi... Top (NKB) (NKB) (°) Item Description Comment _ ID (in) 32.6 32.6 -0.02 FIANIGEFI FMC TUBING HANGER 3.958 2,29251 1,865.2 64.79jNIPPLE-- - BAL-O NIPPLE (ID 3.812") wlPACKOFF DUMMY (ID 2.75") 2.750 14,024.71 6,862.61. 63.65 PACKEF: BAKER PREMIER PACKER 3.875 14,085.9 6,889.7 63.79 NIPPLE HOWCO'XN' NIPPLE ~ 3.725 1 15,531.0 7,246.7 9320 SOS SHEAR OUT SUB _ 3.550 1 15,533.1 /246.6 93.30 WLEG I, WIRELINE ENTRY GUIDE 3.850 Other I etc valves pumps fish n Hole (Wireline retrievable plugs .) , , , , To _ (TVDJ Top I cl P L Top (NKBJ (HKB () Des~ Phi Comment J 2 Run Date ID (inJ 2 293 - _ ''4-1/2 WRDP (5/M HSS 124) -RESET WR 64.79 WRDG-' i 865 DP & SLIPSTOP 8/27/2007 2.125 ,Perfora 15/27/2007 tions 8r Slots +' ............__-_ snrn Top(ND) Btm (TVDj Dens Top (kKB) Bhn (ftK6) (ftK6) IHKBj Zone ~ Date (sn-~ Type Comment 15,719- 20,566 7,238.9 2214.2 Miluveach, 9!5/2006 32.0 SLOTS Alternating solid/slotted pipe - CD4-318A 0.125"x2.5" @ 4 circumferential ~, atljacent rows. 3" centers staggered '~, 18 deg, 3' non-slotted entls Notes: General Sr Safety _ ... End Date Annotation __ 9/10/2006 '(NOTE: SIDETRACKED :HELL w/SLOTTED 1214/2009 NOTE: VIEW SCh{EfWA LIC w/Alasxa Schematic9.0 Mandrel Details - - _ _ TOp Depin Top (TVD) Intl OD Valve Latc Stn Top (ftKBJ'~ (NKB) (") MaFe Model lint Serv TYpe TYPe PoR n Size TRO Run (InJ (Psi) Run Date Com..._ ~ 1 5,885.2 3,385.8 64.58 CAPoICij'IKBG 1 GAS LIFT GLV BK 0.188. 2,081.0 8/27/2007 ' 2 11.2825I~ 5,669.7 65.19 CAPoICO KBG 1iGAS LIFT GLV BK 0.1881 2,125.0 8/26/2007 3 13.91 t5~ 6,812.0 63.39~CAhdCO KBG 1,GAS LIFT. ;OV ~~BK 1-0.438 0.0 8/26/2007 «a ~- x+!r SLOTS _ _ .._ ~Y 1~ 15.719-20,666 - ~ LINER, ~ ~ 15523-2(1,6(1] \ TD (CD4-318A), _ _ 20,612 • ! ,, ~q ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 19, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~o (~ I ~ ~3~~b ~ C~ ~' Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped March 18th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sinc Perry ~c~~~ ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Date 3/19/2009 Well Name PTD # Initial top of .cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al CD4-301 B 207-180 SF NA 7" NA 2.55 3/18/2009 CD4-302 207-056 28" NA 28" NA 22.95 3/18/2009 CD4-304 207-132 8" NA 8" NA 1.70 3/18/2009 CD4-05 207-155 SF NA 7" NA 1.70 3/18/2009 CD4-306 207-094 SF NA 5" NA 1.70 3/18/2009 CD4-07 207-:118 SF NA 6" NA 0.42 3/18/2009 CD4-208 205-162 SF NA 7" NA 1.27 3/18/2009 CD4-209 206-065 SF NA 6" NA 0.85 3/18/2009 CD4-210 206-077 SF NA 7" NA 1.27 3/18/2009 ~ GD4-211 206-153 9" NA 9" NA 3.SZ 3/1S/2Wy CD4-214' 206-145 7" NA 7" NA 2.12 3/18/2009 CD4-215 ~ 206-157 5" NA 5" NA 2.55 3/18/2009 CD4-16 206-131 SF NA 5" NA 2.55 3/18/2009 4-17 206-118 SF NA 11" NA 1.27 3/18/2009 CD4-318A 206-113 7" NA 7" NA 1.70 3/18/2009 CD4-319 205-148 SF NA 7" NA 1.27 3/18/2009 CD4-320 206-055 6" NA 6" NA 0.85 3/18/2009 CD4-321• 206-.142 SF NA 8" NA 1.70 3/18/2009 CD4-322 207-101 SF NA 5" NA 1.27 3/18!2009 ~~ ~ ~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 9/12/2008 Permit to Drill 2061130 Well Name/No. COLVILLE RIV NAN-K CD4-318A Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20519-01-00 MD 20612 TVD 7212 Completion Date 9/10/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neutron (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stou CH Received Comments pt 14181 LIS Verification 3454 15711 Open 10/19/2006 GR, ROP, C Lis 14181 Induction/Resistivity 2484 15711 Open 10/19/2006 GR, ROP, D Asc Directional Survey 3447 15711 Open 10/19/2006 n LIS Veri, GR, ROP, FET epv. w/Graphics PDS and TIF og Induction/Resistivity 25 Blu 1 15500 20612 6es~ 7/30/2007 MD Vision Resisistivity 5- Sep-2006 r Log Induction/Resistivity 25 Blu 1 15500 20612 sy~ c.atst 7/30/2007 TVD Vision Resisistivity 5- / Sep-2006 _ ~D C 15899 Induction/Resistivity 3525 15711 .s-~w~ E~s2 2/6/2008 MD and TVD for EWR, DGR and ROP in PDF, EMF and CGM graphics Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y .~~ Daily History Received? ~V Chips Received? -~'.-.:.-.~ Formation Tops ~N Analysis `'f"°h#- Received? • Comments: DATA SUBMITTAL COMPLIANCE REPORT 9/12/2008 Permit to Drill 2061130 Well Name/No. COLVILLE RIV NAN-K CD4-318A Operator CONOCOPHILLIPS ALASKA INC MD 20612 ND 7212 Completion Date 9/10/2006 Completion Status 1-OIL Current Status 1-OIL Compliance Reviewed By: Date: API No. 50-103-20519-01-00 UIC N WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-318A ~, ~ .:~~ ~~, ~_.~. `? ; < `~,, January 31;,2008 AK-MW-4123605 CD4-318A: Digital Log Images: 50-103-20519-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNIl~TG THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~- ~ ~Z yro ~~ 1 S Date: L. ~1 i~ r. Signed: ~ ~OO~ - i ~ 3 ~ l 5 X59, ~' 0~12~/0~ $Cli~tlh~l'~~~" Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth ~~ -Il ~ ~ ~~~~' N0.4365 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aipine Color Well Job # Log Description Date BL Prints CD DATE: ~J~~- d 2~a~ ~)~ska Coil ~ G~ Cnns. ~mmi~icx~ ~. Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you.~SnCrK~Y CD4-318 40012945 OH EDIT MWD/LWD 01/16/06 1 1 CD4-318A 40012945 OH EDIT MWD/LWD 09/05/08 2 1 SIGNED: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL ~ ~l~a/Q7 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: "Z'~~- ® - ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 7. Well Name: CD4-318A 2. Address: 4b. Well Status: Oil ~ Gas WAG 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20519-01 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ^ or Final ^Q 306-181/206-113 5/26/2006 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 419* 419 totals (bbls): 2006 / 2nd 0 0 0 0 0 2006 / 3rd 28 100 395 523 1 7/2/2006 7/2/2006 CD4-320 2006 / 4th 0 0 0 0 0 2007 / 1st 0 0 0 0 0 Total Ending Report is due on the 20th volume 28 100 814 942 1 (bbls): of the month following the final month of the quarter. Ex: Apri120 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze protect volumes and in'ectivit test I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: `'~' Date: .~ rs~8 7 Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL ~~~1, ~-l ~ b 1 ~ 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number. ~ ?~ ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 7. Well Name: CD4-318 2. Address: 4b. Well Status: Oil Q Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20519-0 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ^~ or Final 306-181 5/26/2006 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated drilling mud, completion domestic waste water descriptions in block 12) disposal occurred fluids, formation fluids and any necessary water added Previous 419* 419 totals (bbls): 2006 / 2nd 0 0 0 0 0 2006 / 3rd 28 100 395 523 1 7/2/2006 7/2/2006 CD4-320 2006 / 4th 0 0 0 0 0 2007 / 1st 0 0 0 0 0 Total Ending Report is due on the 20th volume 28 100 814 942 1 of the month following the final month of the quarter Ex: (bbis>: . July 20 for the second quarter, Apri120 for the first quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze rotect volumes and in'ectivit test I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ ~ ~ Date: ~~ ~~3~G ~ Printed Name: Randy Thoma Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL -- 1. Operator: 4a. Well Class: Stratigraphic ^ Service - 6. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 7. Welf Name: CD4-318 2. Address: 4b. Well Status: Oil ^~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20519-0 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^~ or Final ^ 306-181 5/26/2006 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous totals (bbls) 419* 419 2006 / 2nd 0 0 0 0 0 2006 / 3rd 28 100 395 523 1 7/2/2006 7/2/2006 CD4-320 2006 / 4th 0 0 0 0 0 2007 / 1st Total Ending volume 28 Report is due on the 20th 100 814 942 1 tbb~s> of the month following the final month of the quarter. Ex: A ri120 for the first uarter Jul 20 for th d rt p q , y e secon qua er, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze protect volumes and in~ectivit test I hereby certify that the foregoing~i&,true and correct to the best of my knowledge. Signature: ~ ~~-..E;~~~a. ~ ~, ~.~~_L.: ~-~--~. / ~t 2 /~ 7 Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2!2004 INSTRUCTIONS ON REVERSE SIDE Suhmit in Iliinlir•atP STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL ~~ 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Dritl Number. ~'~ > -~~ ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 7. Well Name: CD 8 2. Address: 4b. Well Status: Oil ~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20519-0~ 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^Q or Continuation ^ or Final ^ 306-181 5/26/2006 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated drilling mud, completion domestic waste water descriptions in block 12) disposal occurred fluids, formation fluids and any necessary water added Previous 419" 419 totals (bbls): 2006 / 2nd 0 0 0 0 0 2006 / 3rd 2006 / 4th 2007 l 1st Total Ending Report is due on the 20th volume 419 419 0 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first uarter Jul 20 for the second uarter q y , q , 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze rotect volumes and injectivit test I hereby certify that the foregoing is true and correct to the best of my knowledge. Si nat ~ ~ -°- ~ f ~ g ure: ~- Date: > ~ ~' tr Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate . _. ~ ~ ,~ .~._ ,1. ,~ /,6,~~ r • STATE OF ALASKA • ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 ~ ~h1 ~- ~ ~ ~ ~ 1. Operator ~,~~~~~ ~; ;,~~~ ®r!S\.~r~~ ~k\~ 3. Permit to Drill ff,, ~ ~ '' Name: Number: l( ConocoPhillips Alaska Esc®~`~.~~ '~c .:>c~v+ -~C '^ ~~•~o~ 4. API Number: ~ r, € 50-103-20519-0 2. Address: P.O. Box 100360, Anchorage, Ala a ~~~ ~t- ~shc~b:~~ t ~pc~~~. 1 5. Well CD4-318 ~ ~ C ~~ ~~ ~ 6. Field: ~ ~ Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: Nanuk 3, CD4-319" Torok and Seabee formation, shale, siltstone and sandstone b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1780' MD ! 1600' TVD ~ None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2248 PSI 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, domestic waste water, any added water 3-Jun-06 needed to facilitate pumping of drilling mud or drilling cuttings, new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations and any other fluids associated with drilling a well. " 17. Attachments: ~ Well Schematic (Include MD and TVD) ^ FIT Records w/LOT Graph Q Cement Bond Log (if required) ^ Surf. Casing Cementing Data ~ Other '^ previous authorization for new product cleanup fluids for CD1 and CD2 oregoi true and correct to the best of my knowledge. 18. I hereby certify that th e f n g is / ~ / ~ ' 1 / ' , y , /~ Signature: r'~:'3• ~~ (~!" ` ~ Title: !~~ ~L.uf~..fl/~C:. L~w~~- / 1 (f Printed Phone Name: Chip Alvord Number: 265-6120 Date: '~ ~ (`~ ~ ~.~~ 6 Commission Use Only Conditions of approval: LOT review and approval: ' ' 7"`~ Subsequent form required: ~~+'R~ Approval number: U/_ " CC~- APPROVED BY ~,~~' THE COMMISSION - ~ Approved by: Date: V COMMISSIONER Form 10-403RD Rev. 6/2004 T~j,JCTIONS ON REVERSE Su mit in Dup icate Annulus i~osal Transmittal Form - We11~4-318 ~ 4(1(:('C' Ragnlatinnc 7(1 AAC' 75 (1R(1 (hl 1 Designation of the well or wells to receive drillin wastes: CD4-318 2 The depth to the base of freshwater aquifers and permafrost, if There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = 1600' TVD RKB 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other inforrnation sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/l. (Ref. AOGCC Conservation Order No. 443, 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing - waste under (h)(3) of this section. tanks and equipement after producing drilling/completion fluid (see included note from CD1&2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure a~the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2248 psi. See attached calculation calculations showin how this value was determined. a e. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT /FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N/A de th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD4-318, CD4-209, CD4-320, CD4-210, CD4-211;CD4-17 will be enerated. CD4-16 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com Hance would be im rodent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. • Well CD4-318 Date Si 17/2006 (for submital with Annular Disposal Application) Assumptions iviaximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing casing annulus 0.07 psi/ft Header Pressure (for wells on gas lift) 1,000 psi ~~_~o° . -.a~ o Pburst85% -PHydrostatic +PApplied - PFormation 4,888 = ( 2,375 * 0.052 * MWmax ) + 1500 - ( 0.4337 * 2,375 ) ~Wmax = 35.8 PPg Surface Casing Strin i~ Pressure Calculations for Annular Disposal Size 9.625 in Weight 40 ppf Grade L 80 rburstloo°% 5,750 psi Pburst85°/ 4,888 psi Depth of Shoe 2,375 ft FIT/LOT ~ Shoe 18.2 ppg or 2,248 psi FITiLOT for Annulus 17.1 ppg Max Surf. Pressure 1,500 psi TOC Est. @ 11,800' MD \ 5,966' TVD a.5 "Tubing 7,254 TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85°/ -PHydrostatic +PApplied - PGasGradient - PHeader 4,599 = ( 5,966 * 0.052 * MWa,~ )+ 1,500 - (0.0700 * 5,966) - 1,000 ~Wmax = 14.6 PPg 2nd Casing String Size 7 in Weight 26 ppf Grade L 80 rcollapse100% 5,410 pst Pcollapse85% 4,599 p5t Top of Cement 5,966 ft Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable =Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable - ( 2,375 * .052 * 18.2 ) Pmax allowable - 2,248 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". • • ronoco hi~l~ s p Casing Detail 9 5/8" Surface Casing Well: CD4-318 {~ Date: 12/27/2005 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.84 FMC Gen V Hanger 2.20 36.84 Jts 3 to 90 88 Jts 9-5/8" 40# L-80 BTC Csg 3367.60 39.04 Weatherford Float Collar 1.54 3406.64 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 74.71 3408.18 Ray Oil Tools "Silver Bullet" Float Shoe 2.31 3482.89 3485.20 TD 12 1/4" Surface Hole 3495.20 TOTAL BOWSPRING CENTRALIZERS -50 1 per jt on Jt #1 - #12 (stop ring on Jt #1 8~ 3 ) and over collars on jts# 14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62 64, 66, 68,70,72,74,76,78,80,82,84,86,88, 94 joints in the pipe shed. Run joints - 4 joints stay out Use Best-o-Life 2000 pipe dope All joints drifted - 8.781" MU torgue - 8600 ft/Ibs Remarks: Up Wt - 170 k Dn Wt- 130k Block Wt - 75k Supervisor: Lutrick/Hill • • 19-Sep-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD4-318A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 3,447.27' MD Window /Kickoff Survey ` MD (if applicable) Projected Survey: 15,711.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICHC~?HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ Si ned Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~p lO -!I ~ • • WELL LOG TRANSMITTAL To: State of Alaska October 2, 2006 Alaska Oil and Gas Conservation. Comm. Attn.: Librarian 333 West 7`'' Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-318A, AK-MW-4123605 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention o£ Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20519-0 l . ._ ~~~ _~ :,rte ~, ~~+-- ~~~'~~~ ~ l~~ ! °~ ~ • ConocoPhillips October 6, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD4-318A (APD 206-113) Dear Commissioner: ~~~~~~ OCT 0 9 ICS Alaska Oil & Gas Cans. C~issi~~ Ancit~raga ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD4-318A. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, .~ 1....co-- G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 GCA/skad STATE OF ALASKA ALASi<A OIL AND GAS CONSERVATION COMMISSION ~~~`~E® ~ ~ T 0 9 2006 WELL COMPLETION OR RECOMPLETION REPO~~~~3~- 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class:AOC~Ol.8~8 Development Q Exploratory ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: September 10, 2006 12. Permit to Drill Number: 206-113 / 306-267 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: / r~~ ~7 ~ DeftCpm~ Se 13. API Number: 50-103-20519-01 ' 4a. Location of Well (Governmental Section): Surface: 2312' FSL, 400' FEL, Sec. 24, T11 N, R4E, UM 7. Date TD Reached: /p .9 September 5, 2006 14. Well Name and Number: CD4-318A ' At Top Productive Horizon: 1867' FSL, 180' FEL, Sec. 27, T11 N, R4E, UM 8. KB Elevation (ft): 36.5' RKB 15. Field/Pool(s): Colville River Field Total Depth: 1775' FSL, 1235' FEL, Sec. 22, T11 N, R4E, UM 9. Plug Back Depth (MD + ND): 20612' MD / 7212' ND Nanuq Kuparuk Oil Poof 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377844 ' y- 5957447 Zone- 4 10. Total Depth (MD + ND): 20612' MD / 7212' ND 16. Property Designation: 3$ ?-OQ~ ADL 380077 3$'7~q TPI: x- 367414 y- 5951897 Zone- 4 Total Depth: x- 366443 - - 5957103 Zone- 4 11. Depth where SSSV set: SCSSSV nipple @ 2292' 17. Land Use Permit: ALK 38077 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1900' MD 21. Logs Run: ~+ L.' s•i~ •3s'2S~/1'la~ ~,3y1'3 ~~'Y.2S ~~ GR/Res/Dens/Neutron /o • p•cG 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 68# H-40 36.5' 114' 36.5' 114' 42" Portland Type III 9.625" 40# L-80 36.5' 3485' 36.5' 2375' 12.25" 520 sx AS Lite, 231 sx Class G 7" 26# L-80 36.5' 15696' 36.5' 7239' 8.75" 200 sx LiteCRETE, 110 sx Class G 4.5" 12.6# L-80 15532' 20607' 7246' 7212' 6.125" slotted liner 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 15541' 14025' slotted liner from 15718'-20565' MD' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) not on-line Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~it~illP'~£TtUic { QAiE E NONE '~..~~_~----~ Form 10-407 Revised 12/2003 CONTINUED ON RE E U~~ ~ ZD~~ ~t0(cC~ ~ '~•4~~ ,i~,~~ ~~ 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD4-318A Nanuq sand 12588' ' 6217' Kuparuk C 15271' 7235' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name /C ~Alvo-rd Title: Alpine Drilling Team Leader P'1 ~ (a ~ ~ Signature~~. tom--- Phone Z~~ ~ ~~ Date t INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared by Sharon Allsup-Drake Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. 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: True vertical thickness. 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 interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 1212003 Halliburton Company Survey Report Company: ConocoPfiillips Alaska Inc. Date: 9/1 212 00 6 Time: 13:39:22 I'a~c: 1 Field: Colville River Unit Co -ordinatclT'E) Itcfercncc: Welh CD4-318, True North Site: Alpine CD4 Ve ttiril ("I~~D) Re fercucc: GD4-318A: 55.9 Wetl: CD4-318 Secliun 1~~~1 Refer ence: Well (DAON,O.OOE,200.OOAzi) Wellpath: CD4-318A Survey Calculation Method: Minimum Curvat __- ure Db: Oracle ___ Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 ' Geo Datum: NAD27 (Clarke 1866). Sys Datum: Mean Sea Level Coordinate System: Well Centre Geomagnetic Model: bggm2006 Well: CD4-318 Slot Name: Alpine CD4 Well Position: +N/-S -84.84 ft Northing: 5957446.62 ft Latitude: 70 17 32.131 N +E/-W -329.52 ft Easti ng : 377843.88 ft Longitude: 150 59 20.366 W Position Uncertainty: 0.00 ft ~ Wellpath: CD4-318A Drilled From: CD4-318PB1 501032051901 Tie-on Depth: 3447.27 ft Current Datum: CD4-318A: Height 55.90 ft Above System Datum: Mean Sea Level Magnetic Data: 8/3/2006 Declination: 23.10 deg i Field Strength: 57545 nT Mag Dip Angle: 80.66 deg ~ Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.90 0.00 0.00 200.00 Survey Program for Definitive Wellpath Date: 9/12/2006 Validated: No Version: 5 Actual From To Survey Toolcode Tool Name ft ft i 81.04 441.04 CD4-318PB1 gyro (81.04-441.04) CB-GYRO-SS Camera based gyro single shot ~~ i 567.60 3447.27 CD4-318P B1 (567.60-14813.30) ( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3525.00 15654.87 CD4-318A sperry (3 525.00-15654 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC ', 15755.78 20549.47 CD4-318A Schlumberger (15755.7 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey __- _ DID lucl azim TVD Sys'TVD N/S E/W l~l;~p~ MapE Tool ft deg deg ft ft ft ft ft ft --- - I 36.90 0.00 0.00 36.90 -19.00 0.00 0.00 5957446.62 377843.88 . TIE LINE 81.04 0.20 324.00 81.04 25.14 0.06 -0.05 5957446.68 377843.84 CB-GYRO-SS 170.04 0.30 318.00 170.04 114.14 0.36 -0.29 5957446.99 377843.59 CB-GYRO-SS 260.04 1.00 326.00 260.03 204.13 1.19 -0.89 5957447.82 377843.01 CB-GYRO-SS 351.04 2.75 320.00 l 350.98 295.08 3.52 -2.74 5957450.18 377841.20 CB-GYRO-SS 441.04 4.65 316.00 ~ 440.79 384.89 7.80 -6.66 5957454.52 377837.35 CB-GYRO-SS !, i 567.60 6.11 297.66 566.80 510.90 14.61 -16.19 5957461.49 377827.93 MWD+IFR-AK-CAZ-SC 657.47 6.92 282.45 656.09 600.19 18.00 -25.71 5957465.04 377818.46 MWD+IFR-AK-CAZ-SC 747.41 8.99 269.16 745.17 689.27 19.07 -38.03 5957466.30 377806.17 MWD+IFR-AK-CAZ-SC 840.07 11.47 258.08 836.36 780.46 17.06 -54.29 5957464.56 377789.88 MWD+IFR-AK-CAZ-SC 934.53 16.52 248.56 928.00 872.10 10.20 -76.00 5957458.06 377768.07 MWD+IFR-AK-CAZ-SC 1029.47 21.41 244.77 1017.76 961.86 -2.12 -104.25 5957446.19 377739.61 MWD+IFR-AK-CAZ-SC ~, 1120.73 24.84 242.34 1101.68 1045.78 -18.13 -136.31 5957430.71 377707.30 MWD+IFR-AK-CAZ-SC 1216.78 31.64 240.81 1186.25 1130.35 -39.81 -176.22 5957409.69 377667.05 MWD+IFR-AK-CAZ-SC 1311.70 33.04 240.93 1266.44 1210.54 -64.52 -220.57 5957385.70 377622.31 MWD+IFR-AK-CAZ-SC 1406.77 37.34 238.91 1344.12 1288.22 -92.02 -267.94 5957358.98 377574.50 MWD+IFR-AK-CAZ-SC 1502.29 40.37 237.29 1418.50 1362.60 -123.70 -318.79 5957328.13 377523.15 MWD+IFR-AK-CAZ-SC I 1597.40 43.32 235.36 1489.35 1433.45 -158.90 -371.57 5957293.79 377469.81 MWD+IFR-AK-CAZ-SC 1692.72 47.39 233.35 1556.32 1500.42 -198.44 -426.64 5957255.15 377414.11 MWD+IFR-AK-CAZ-SC 1787.94 51.82 232.63 1618.01 1562.11 -242.10 -484.52 5957212.45 377355.53 MWD+IFR-AK-CAZ-SC 1882.72 56.24 231.87 1673.67 1617.77 -289.06 -545.15 5957166.48 377294.15 MWD+IFR-AK-CAZ-SC 1978.00 59.51 232.38 1724.33 1668.43 -338.59 -608.84 5957118.00 377229.67 MWD+IFR-AK-CAZ-SC 2073.08 63.45 232.93 1769.72 1713.82 -389.25 -675.24 5957068.43 377162.46 MWD+IFR-AK-CAZ-SC 2168.28 64.12 233.34 1811.77 1755.87 -440.49 -743.57 5957018.31 377093.31 MWD+IFR-AK-CAZ-SC 2263.55 64.79 233.96 1852.85 1796.95 -491.43 -812.80 5956968.50 377023.27 MWD+IFR-AK-CAZ-SC 2358.47 64.79 232.02 1893.29 1837.39 -543.12 -881.38 5956917.93 376953.87 MWD+IFR-AK-CAZ-SC ~I 2453.63 63.42 229.70 1934.85 1878.95 -597.15 -947.77 5956865.00 376886.61 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report ( omp;uiy: ConoCOPhillipsAlaska Inc. Uatc: 9!1212006 Time: 13:39:22 I'a!~e:_ Field: Colville Rive r Unit Co-ordinate (NE) Reference: Well: CD4-318, Trrfe North tii tr. Alpine CD4 Verti cal (Tti'D) Reference: CD4-318A: 55.9 «cll: CD4-312 Secti on (VS) Reference: Well (O.OON,O-OOE,200.OOAzi) 1~cllpath: CD4-'318A Survey Calc ulation"~lcthud: Minimum C urvat ure Dlr: Oracle Sur~c~ ~II) Inc! ___ Azim llll Sys 1l7) 1rS r:~~~ ~IapN -- - ~1a~E Tool ', ft deg deg ft ft ft ft ft ft 2548.74 63.13 229.21 1977. 62 -- 1921.72 -652 .37 -1012. 32 _ 5956810 .84 376821. 17 - MWD+IFR-AK-CAZ-SC 2644.07 65.07 229.84 2019. 26 1963.36 -708 .03 -1077. 56 5956756 .26 376755. 05 MWD+IFR-AK-CAZ-SC 2739.23 65.01 232.14 2059. 42 2003.52 -762 .33 -1144. 59 5956703. 06 376687. 15 MWD+IFR-AK-CAZ-SC 2834.49 65.32 234.27 2099. 43 2043.53 -814 .10 -1213. 81 5956652. 42 376617. 10 MWD+IFR-AK-CAZ-SC 2929.59 66.82 235.46 2138. 01 2082.11 -864 .12 -1284. 90 5956603. 56 376545. 22 MWD+IFR-AK-CAZ-SC 3025.06 65.41 234.20 2176. 66 2120.76 -914 .39 -1356. 25 5956554. 46 376473. 06 MWD+IFR-AK-CAZ-SC 3119.02 63.68 233.01 2217. 05 2161.15 -964 .72 -1424. 54 5956505. 25 376403. 97 MWD+IFR-AK-CAZ-SC 3215.44 64.52 233.04 2259. 16 2203.26 -1016 .89 -1493. 84 5956454. 22 376333. 84 MWD+IFR-AK-CAZ-SC 3310.63 64.17 233.44 2300. 38 2244.48 -1068 .24 -1562. 58 5956404. 00 376264. 28 MWD+IFR-AK-CAZ-SC ~ 3405.86 64.31 231.11 2341. 77 2285.87 -1120 .72 -1630. 41 5956352. 64 376195. 61 MWD+IFR-AK-CAZ-SC 3447.27 64.52 231.32 2359. 65 2303.75 -1144 .11 -1659. 52 5956329 .72 376166. 12 MWD+IFR-AK-CAZ-SC 3525.00 65.00 230.52 2392. 80 2336.90 -1188 .44 -1714. 10 5956286 .29 376110. 84 MWD+IFR-AK-CAZ-SC 3627.95 61.71 226.10 2438. 98 2383.08 -1249 .57 -1782. 82 5956226 .29 376041. 14 MWD+IFR-AK-CAZ-SC 3722.44 60.87 218.78 2484. 41 2428.51 -1310 .65 -1838. 70 5956166 .13 375984. 28 MWD+IFR-AK-CAZ-SC i 3822.05 63.14 222.91 2531. 18 2475.28 -1377 .14 -1896. 23 5956100. 59 375925. 68 MWD+IFR-AK-CAZ-SC 3913.68 65.98 225.02 2570. 54 2514.64 -1436 .68 -1953. 67 5956042. 00 375867. 28 MWD+IFR-AK-CAZ-SC 4009.66 65.86 225.88 2609. 71 2553.81 -1498 .15 -2016. 12 5955981. 55 375803. 85 MWD+IFR-AK-CAZ-SC i 4103.25 67.40 226.25 2646. 83 2590.93 -1557 .75 -2077. 99 5955922 .96 375741. 03 MWD+IFR-AK-CAZ-SC 4198.68 67.20 229.40 2683. 66 2627.76 -1616 .85 -2143. 22 5955864 .94 375674. 85 MWD+IFR-AK-CAZ-SC 4293.83 67.29 234.92 2720. 49 2664.59 -1670 .65 -2212. 48 5955812 .27 375604. 73 MWD+IFR-AK-CAZ-SC 4387.51 66.76 234.16 2757. 06 2701.16 -1720 .69 -2282. 73 5955763 .39 375533. 68 MWD+IFR-AK-CAZ-SC i 4482.33 66.83 231.79 2794. 42 2738.52 -1773 .16 -2352. 30 5955712 .06 375463. 27 MWD+IFR-AK-CAZ-SC 4577.52 66.50 234.61 2832. 14 2776.24 -1825 .51 -2422. 28 5955660 .86 375392. 46 MWD+IFR-AK-CAZ-SC i 4672.41 65.95 235.49 2870. 39 2814.49 -1875 .26 -2493. 45 5955612 .28 375320. 50 MWD+IFR-AK-CAZ-SC 4767.64 65.33 235.46 2909. 67 2853.77 -1924 .43 -2564. 92 5955564 .28 375248. 24 MWD+IFR-AK-CAZ-SC 4863.14 64.99 234.38 2949. 79 2893.89 -1974 .23 -2635. 84 5955515 .64 375176. 52 MWD+IFR-AK-CAZ-SC 4957.54 64.93 233.94 2989. 74 2933.84 -2024 .31 -2705. 18 5955466 .70 375106. 39 MWD+IFR-AK-CAZ-SC 5052.79 64.91 232.49 3030. 12 2974.22 -2075 .97 -2774. 27 5955416 .17 375036. 48 MWD+IFR-AK-CAZ-SC 5147.99 64.75 230.34 3070. 61 3014.71 -2129 .70 -2841. 61 5955363. 55 374968. 27 MWD+IFR-AK-CAZ-SC 5243.42 64.60 230.69 3111. 43 3055:53 -2184 .55 -2908. 19 5955309 .79 374900. 82 MWD+IFR-AK-CAZ-SC 5338.80 64.70 231.47 3152. 27 3096.37 -2238 .70 -2975. 25 5955256 .74 374832. 90 MWD+IFR-AK-CAZ-SC 5434.08 64.68 231.78 3193. 00 3137.10 -2292 .17 -3042. 77 5955204 .38 374764. 52 MWD+IFR-AK-CAZ-SC 5528.59 63.95 231.41 3233. 97 3178.07 -2345 .08 -3109. 52 5955152 .57 374696. 93 MWD+IFR-AK-CAZ-SC ~ 5624.34 64.36 233.96 3275. 71 3219.81 -2397 .31 -3178. 05 5955101 .46 374627. 56 MWD+IFR-AK-CAZ-SC 'I 5719.45 65.43 232.62 3316. 07 3260.17 -2448 .79 -3247. 08 5955051 .11 374557. 70 MWD+IFR-AK-CAZ-SC ~ 5814.82 64.98 232.57 3356. 06 3300.16 -2501 .39 -3315. 86 5954999 .65 374488. 09 MWD+IFR-AK-CAZ-SC 5909.91 64.78 232.68 3396. 43 3340.53 -2553 .65 -3384. 28 5954948 .51 374418. 84 MWD+IFR-AK-CAZ-SC 6005.34 65.54 231.72 3436. 52 3380.62 -2606 .73 -3452. 70 5954896 .55 374349. 56 MWD+IFR-AK-CAZ-SC 6101.01 65.25 230.48 3476. 35 3420.45 -2661 .35 -3520. 40 5954843 .05 374281. 00 MWD+IFR-AK-CAZ-SC 6196.46 .65.99 232.83 3515. 76 3459.86 -2715 .27 -3588. 58 5954790 .24 374211. 95 MWD+IFR-AK-CAZ-SC 6291.35 65.47 230.58 3554. 77 3498.87 -2768 .87 -3656. 46 5954737 .75 374143. 21 MWD+IFR-AK-CAZ-SC 6386.55 65.59 231.51 3594. 20 3538.30 -2823 .35 -3723. 85 5954684 .38 374074. 96 MWD+IFR-AK-CAZ-SC 6481.47 65.48 231.78 3633. 51 3577.61 -2876 .96 -3791. 60 5954631 .88 374006. 35 MWD+IFR-AK-CAZ-SC i 6576.56 64.94 232.79 3673. 38 3617.48 -2929 .77 -3859. 88 5954580 .19 373937. 22 MWD+IFR-AK-CAZ-SC 6671.16 64.72 230.63 3713. 62 3657.72 -2982 .82 -3927. 08 5954528 .25 373869. 18 MWD+IFR-AK-CAZ-SC j 6765.75 64.99 229.82 3753. 81 3697.91 -3037 .60 -3992. 89 5954474 .55 373802. 49 MWD+IFR-AK-CAZ-SC ~ 6860.61 65.64 232.61 3793. 44 3737.54 -3091 .58 -4060. 07 5954421 .68 373734. 45 MWD+IFR-AK-CAZ-SC 6971.38 65.61 233.94 3839. 15 3783.25 -3151 .91 -4140. 94 5954362 .67 373652. 62 MWD+IFR-AK-CAZ-SC 7066.50 65.04 233.69 3878. 86 3822.96 -3202 .94 -4210. 70 5954312 .79 373582. 04 MWD+IFR-AK-CAZ-SC 7161.33 63.61 234.54 3919 .95 3864.05 -3253 .04 -4279. 94 5954263 .82 373512. 00 MWD+IFR-AK-CAZ-SC 7256.49 63.06 233.60 3962 .65 3906.75 -3302 .94 -4348. 80 5954215 .05 373442. 35 MWD+IFR-AK-CAZ-SC 7351.63 63.11 233.60 4005 .72 3949.82 -3353 .28 -4417. 08 5954165 .83 373373. 26 MWD+IFR-AK-CAZ-SC 7447.19 63.01 232.12 4049 .02 3993.12 -3404 .71 -4484. 99 5954115 .51 373304 .54 MWD+IFR-AK-CAZ-SC ~ Halliburton Company* Survey Report Compam : ConocoPhillipsAlaskalnc. Uate: 9/12/2006 "Lime: 13:39:22 Yagc: 3 Fief: Colville Rive r Unit Co-ordinate(NE) Reference: Well: CD4-318, True North tiire: ,4lpine CD4 Verti cal (1'VD) Reference: CD4-318A: 55.9 ~1'cll: CD4-318 tiecti on (VS}Beferencc: Well (O.OON,O.OOE,200.OOAzi) lielipath: CD4-318A sur~ry Calculnti uu ~9cthnd: Minimum C urvat ure Db: Oracle Surve~• ~ ', '1~ID Incl Azim I"~l) ~_~sll`I1 1;S F.!~~ flapA' 11ap1? foul ', ft deg de g ft ft ft ft ft ft 7542 .26 62.70 231 .17 4092. 39 4036.49 -3457 .21 -4551. 33 5954064. 11 373237. 36 I MWD+IFR-AK-CAZ-SC I 7637 .25 63.41 230 .59 4135. 44 4079.54 -3510 .63 -4617. 02 5954011. 76 373170. 81 MWD+IFR-AK-CAZ-SC 7732 .70 64.31 228 .45 4177. 49 4121.59 -3566 .26 -4682. 19 5953957. 20 373104. 75 MWD+IFR-AK-CAZ-SC 7827 .59 64.99 228 .09 4218. 12 4162.22 -3623 .34 -4746. 18 5953901. 18 373039. 84 MWD+IFR-AK-CAZ-SC 7922 .78 64.94 228 .75 4258. 40 4202.50 -3680 .58 -4810. 70 5953845. 00 372974. 41 MWD+IFR-AK-CAZ-SC 8017 .57 65.73 230 .03 4297. 96 4242.06 -3736 .64 -4876. 09 5953790. 01 372908. 12 MWD+IFR-AK-CAZ-SC 8111 .55 64.93 229 .38 4337. 18 4281.28 -3791 .87 -4941. 23 5953735. 85 372842. 10 MWD+IFR-AK-CAZ-SC 8202 .52 65.05 230 .67 4375. 65 4319.75 -3844 .84 -5004. 41 5953683. 92 372778. 08 MWD+IFR-AK-CAZ-SC 8297 .03 64.99 230 .73 4415. 56 4359.66 -3899 .10 -5070. 70 5953630. 75 372710. 92 MWD+IFR-AK-CAZ-SC 8391 .36 65.12 231 .31 4455. 34 4399.44 -3952 .90 -5137. 19 5953578. 04 372643. 57 MWD+IFR-AK-CAZ-SC 8485 .95 65.12 230 .99 4495. 14 4439.24 -4006 .73 -5204. 02 5953525. 31 372575. 88 MWD+IFR-AK-CAZ-SC 8578 .80 65.41 233 .28 4533. 99 4478.09 -4058 .48 -5270. 59 5953474. 65 372508. 48 MWD+IFR-AK-CAZ-SC 8676 .21 65.13 234 .14 4574. 74 4518.84 -4110 .85 -5341. 90 5953423. 45 372436. 33 MWD+IFR-AK-CAZ-SC ~ 8770 .84 65.24 233 .96 4614. 46 4558.56 -4161 .28 -5411. 43 5953374. 17 372366. 00 MWD+IFR-AK-CAZ-SC j 8865 .40 65.05 234 .42 4654. 20 4598.30 -4211 .48 -5481. 02 5953325. 11 372295. 61 MWD+IFR-AK-CAZ-SC I 8960 .97 65.00 235 .45 4694. 56 4638.66 -4261 .25 -5551. 92 5953276. 50 372223. 91 MWD+IFR-AK-CAZ-SC 9056 .24 65.00 235 .08 4734. 82 4678.92 -4310 .45 -5622. 88 5953228. 46 372152. 17 MWD+IFR-AK-CAZ-SC 9151 .85 65.73 234 .36 4774. 67 4718.77 -4360 .64 -5693. 82 5953179. 43 372080. 43 MWD+IFR-AK-CAZ-SC 9247 .02 65.00 231 .99 4814. 35 4758.45 -4412 .48 -5763. 07 5953128. 73 372010. 36 MWD+IFR-AK-CAZ-SC 9343 .43 65.49 231 .12 4854. 72 4798.82 -4466 .92 -5831. 64 5953075. 42 371940. 92 MWD+IFR-AK-CAZ-SC 9437 .27 65.62 231 .30 4893. 55 4837.65 -4520 .44 -5898. 22 5953022. 99 371873. 48 MWD+IFR-AK-CAZ-SC !, 9531 .91 65.52 231 .32 4932. 69 4876.79 -4574 .30 -5965. 48 5952970. 23 371805. 36 MWD+IFR-AK-CAZ-SC ' 9627 .14 65.61 231 .52 4972. 09 4916.19 -4628 .37 -6033. 26 5952917. 28 371736. 72 MWD+IFR-AK-CAZ-SC I 9722 .43 65.54 230 .69 5011. 49 4955.59 -4682 .84 -6100. 78 5952863. 91 371668. 32 MWD+IFR-AK-CAZ-SC 9817 i .65 65.26 231 .90 5051. 13 4995.23 -4736 .98 -6168. 34 5952810. 88 371599. 90 MWD+IFR-AK-CAZ-SC 9912 .53 64.93 232 .11 5091. 09 5035.19 -4789 .96 -6236. 16 5952759. 02 371531. 23 MWD+IFR-AK-CAZ-SC 10007 .35 64.71 232 .19 5131. 43 5075.53 -4842 .61 -6303. 92 5952707. 48 371462. 63 MWD+IFR-AK-CAZ-SC 10102 .49 64.31 232 .53 5172. 37 5116.47 -4895 .06 -6371. 92 5952656. 15 371393. 79 MWD+IFR-AK-CAZ-SC ~ , 10197. 86 64.45 232 .50 5213. 61 5157.71 -4947 .39 -6440. 16 5952604. 94 371324. 72 MWD+IFR-AK-CAZ-SC 10293. 23 64.94 232 .87 5254. 37 5198.47 -4999 .65 -6508. 73 5952553. 80 371255. 31 MWD+IFR-AK-CAZ-SC ~ 10388 .31 65.21 232 .00 5294. 44 5238.54 -5052 .22 -6577. 07 5952502. 35 371186. 13 MWD+IFR-AK-CAZ-SC 10483 .47 65.68 231 .88 5333. 99 5278.09 -5105 .58 -6645. 22 5952450. 11 371117. 13 MWD+IFR-AK-CAZ-SC 10578 .82 65.14 231 .22 5373. 67 5317.77 -5159 .49 -6713. 13 5952397. 32 371048. 36 MWD+IFR-AK-CAZ-SC i 10673 .52 65.33 232 .02 5413. 34 5357.44 -5212 .88 -6780. 53 5952345. 03 370980. 10 MWD+IFR-AK-CAZ-SC 10768 .95 64.99 232 .45 5453. 43 5397.53 -5265 .92 -6848. 99 5952293. 12 370910. 80 MWD+IFR-AK-CAZ-SC 10863 .98 64.79 233 .15 5493. 75 5437.85 -5317 .94 -6917. 53 5952242. 22 370841. 43 MWD+IFR-AK-CAZ-SC 10959 .30 65.13 233 .46 5534. 10 5478.20 -5369 .55 -6986. 78 5952191. 75 370771. 36 MWD+IFR-AK-CAZ-SC 11054 .43 65.27 232 .58 5574. 00 5518.10 -5421 .49 -7055. 77 5952140. 94 370701. 54 MWD+IFR-AK-CAZ-SC 11149 .47 65.19 231 .39 5613. 82 5557.92 -5474 .64 -7123. 75 5952088. 91 370632. 71 MWD+IFR-AK-CAZ-SC 11244 .78 65.25 229 .19 5653. 77 5597.87 -5529 .92 -7190. 32 5952034. 72 370565. 26 MWD+IFR-AK-CAZ-SC 11340 .44 65.01 227 .90 5694. 01 5638.11 -5587 .38 -7255. 36 5951978. 33 370499. 29 MWD+IFR-AK-CAZ-SC 11435 .53 64.72 227 .48 5734. 40 5678.50 -5645 .32 -7319. 02 5951921. 43 370434. 70 MWD+IFR-AK-CAZ-SC 11530 .82 64.99 227 .38 5774. 89 5718.99 -5703 .68 -7382. 55 5951864. 12 370370. 24 MWD+IFR-AK-CAZ-SC ~ 11625 .91 65.06 229 .16 5815. 04 5759.14 -5761 .05 -7446. 87 5951807. 81 370305. 00 MWD+IFR-AK-CAZ-SC ~ , 11721 .01 64.31 230 .65 5855. 70 5799.80 -5816 .42 -7512. 63 5951753. 52 370238. 36 MWD+IFR-AK-CAZ-SC 11815. 81 63.27 232 .35 5897. 57 5841.67 -5869 .37 -7579. 19 5951701. 67 370170. 95 MWD+IFR-AK-CAZ-SC 11910. 95 63.97 234. 75 5939. 85 5883.95 -5919 .99 -7647. 74 5951652. 16 370101. 59 MWD+IFR-AK-CAZ-SC 12005 .69 64.91 236 .23 5980. 73 5924.83 -5968 .41 -7718. 17 5951604. 90 370030. 39 MWD+IFR-AK-CAZ-SC 12101. 10 66.42 236 .58 6020. 04 5964.14 -6016 .51 -7790. 58 5951557. 99 369957. 22 MWD+IFR-AK-CAZ-SC 12196 .10 66.89 237 .72 6057. 69 6001.79 -6063 .82 -7863. 86 5951511. 88 369883. 19 MWD+IFR-AK-CAZ-SC 12290 .95 66.67 239 .39 6095. 09 6039.19 -6109 .29 -7938. 22 5951467. 63 369808. 10 MWD+IFR-AK-CAZ-SC 12385 .80 65.75 242 .52 6133. 36 6077.46 -6151 .43 -8014. 08 5951426. 73 369731. 58 MWD+IFR-AK-CAZ-SC ;~ Halliburton Company Survey Report Company: ConocoPhillips Alaska inc. Ficld: Colville River Unit Site: Alpine CD4. ~~ cll: CD4-348 ~~'cllpath: CD4-31$A Sw~c~ Date: 9/12/2006 'time: 13:39:22 Page: a Co-ordinate(NE) Reference: Well: CD4-318. True North Vertical ('PVD) Reference: CD4-318A: 55.9 Section (VS) Reference: Well (O.OON,O.OOE;200 OOAzi) Survey Calculation Method: Minimum Curvature Db: Oracle X11) LiCI ,1tim 1"VD Sys f11) ft deg de g ft ft 12480 .82 65.33 245 .29 6172.71 6116 .81 12575 .92 65.61 246 .66 6212.19 6156 .29 12670 .96 65.26 246 .65 6251.70 6195 ,80 12766 .24 65.40 247 .46 6291.47 6235 .57 12861 .85 64.92 248 .06 6331.64 6275 .74 12955 .62 62.93 249 .92 6372.85 6316 .95 13052 .70 63.01 252 .58 6416.98 6361 .08 13147 .75 62.82 255 .83 6460.26 6404 .36 13243 .05 61.80 258 .95 6504.56 6448 .66 13338 .19 62.10 261 .23 6549.30 6493 .40 13433 .06 61.89 264 .84 6593.86 6537 .96 13528 .28 61.94 267 .72 6638.69 6582 .79 13623 .61 63.42 269 .96 6682.45 6626 .55 13718 .97 63.01 273 .07 6725.43 6669 .53 13814. 36 63.35 275. 98 6768.48 6712 .58 13907. 45 63.33 279 .50 6810.26 6754 .36 14004 .25 63.60 282 .05 6853.51 6797 .61 14095 .16 63.81 286 .99 6893.80 6837 .90 14143 .58 64.64 288 .35 6914.86 6858 .96 14190 .29 65.31 288 .80 6934.61 6878 .71 14234 .08 66.11 290 .78 6952.63 6896 .73 14290 .04 67.19 292 .39 6974.81 6918 .91 14326 .67 67.80 294 .52 6988.83 6932 .93 14358 .70 68.79 295 .07 7000.68 6944 .78 14385 .47 69.25 296 .69 7010.26 6954 .36 14480 .74 69.04 301 .55 7044.20 6988 .30 14575. 71 70.23 304 .18 7077.25 7021 .35 14670. 83 71.66 309 .16 7108.32 7052 .42 14766 .14 73.16 312 .40 7137.13 7081 .23 14861 .33 76.05 314 .86 7162.40 7106 .50 14956 .14 77.89 318 .25 7183.78 7127 .88 15051 .47 79.02 322 .44 7202.87 7146 .97 15146 .61 80.84 324 .83 7219.51 7163 .61 15241 .92 83.71 326 .64 7232.32 7176 .42 15263 .62 84.38 328 .04 7234.57 7178 .67 15295 .19 82.70 327 .57 7238.12 7182 .22 15322 .35 82.64 326 .88 7241.59 7185 .69 15375 .62 85.43 329 .91 7247.12 7191 .22 N/S - __ _ g/~~~ ft ft -6189.47 -8091.74 -6224.69 -8170.76 -6258.95 -8250.12 -6292.70 -8329.85 -6325.54 -8410.16 -6355.74 -8488.77 -6383.54 -8570.65 -6406.57 -8652.07 -6425.00 -8734.40 -6439.45 -8817.10 -6449.60 -8900.22 -6455.05 -8984.04 -6456.76 -9068.71 -6454.51 -9153.80 -6447.79 -9238.65 -6436.59 -9321.06 -6420.40 -9406.13 -6399.97 -9484.99 -6386.73 -9526.54 -6373.25 -9566.66 -6359.74 -9604.21 -6340.83 -9651.98 -6327.36 -9683.02 -6314.88 -9710.04 -6303.97 -9732.52 -6260.67 -9810.27 -6212.35 -9885.04 -6158.67 -9957.12 -6099.33 -10025.89 -6036.01 -10092.30 -5968.95 -10155.80 -5897.05 -10215.38 -5821.63 -10270.91 -5743.58 -10324.07 -5725.41 -10335.72 -5698.87 -10352.43 -5676.22 -10367.02 -5631.10 -10394.77 Vlap\ ft 5951389.96 5951356.03 5951323.07 5951290.62 5951259.09 5951230.17 5951203.72 5951182.01 5951164.92 5951151.82 5951143.02 5951138.93 5951138.61 5951142.23 5951150.33 5951162.87 5951180.44 5951202.14 5951216.05 5951230.18 5951244.31 5951263.98 5951277.95 5951290.87 5951302.14 5951346.70 5951396.22 5951451.07 5951511.51 5951575.90 5951643.97 5951716.82 5951793.13 5951872.02 5951890.38 5951917.19 5951940.07 5951985.63 15415.51 88.12 332.65 7249. 37 7193 .47 -5596.18 -10413. 91 5952020. 85 15462.59 91 .57 334.34 7249. 49 7193 .59 -5554 .06 -10434. 91 5952063. 31 15512.63 92 .37 335.16 7247. 77 7191 .87 -5508 .83 -10456. 25 5952108. 88 15553.17 94 .21 337.30 7245. 45 7189 .55 -5471 .79 -10472. 56 5952146. 17 15608.26 93 .15 336.43 7241. 91 7186 .01 -5421 .24 -10494. 16 5952197. 06 15654.87 91 .41 336.94 7240. 06 7184 .16 -5378 .47 -10512. 59 5952240. 12 15755.78 91 .27 339.64 7237. 70 7181 .80 -5284 .75 -10549. 90 5952334. 43 15852.03 89 .86 347.43 7236. 75 7180 .85 -5192 .53 -10577. 16 5952427. 07 15946.08 90 .65 346.62 7236. 33 7180 .43 -5100 .88 -10598. 28 5952519. 04 16039.59 90 .38 347.00 7235. 49 7179 .59 -5009 .84 -10619. 61 5952610. 41 16138.13 90 .03 346.16 7235. 13 7179 .23 -4913 .99 -10642. 48 5952706. 61 16232.45 90 .41 348.52 7234. 77 7178 .87 -4821 .97 -10663. 15 5952798. 94 16327.44 90 .20 348.64 7234. 27 7178 .37 -4728 .86 -10681. 96 5952892. 34 16423.14 89 .21 349.60 7234. 76 7178 .86 -4634 .89 -10700. 02 5952986. 59 16519.40 89 .52 354.26 7235. 83 7179 .93 -4539 .61 -10713. 53 5953082. 06 MapE ___ Toof ft - 369653.31 - --_ MWD+IFR-AK-CAZ-SC 369573.74 MWD+IFR-AK-CAZ-SC 369493.84 MWD+IFR-AK-CAZ-SC ~ I 369413.57 MWD+IFR-AK-CAZ-SC 369332.75 MWD+IFR-AK-CAZ-SC 369253.66 MWD+IFR-AK-CAZ-SC 369171.35 MWD+IFR-AK-CAZ-SC 369089.58 MWD+IFR-AK-CAZ-SC 369006.96 MWD+IFR-AK-CAZ-SC 368924.04 MWD+IFR-AK-CAZ-SC 368840.77 MWD+IFR-AK-CAZ-SC 368756.88 MWD+IFR-AK-CAZ-SC 368672.21 MWD+IFR-AK-CAZ-SC 368587.18 MWD+IFR-AK-CAZ-SC 368502.45 MWD+IFR-AK-CAZ-SC 368420.24 MWD+IFR-AK-CAZ-SC i 368335.45 MWD+IFR-AK-CAZ-SC 368256.94 MWD+IFR-AK-CAZ-SC 368215.62 MWD+IFR-AK-CAZ-SC 368175.72 MWD+IFR-AK-CAZ-SC 368138.40 MWD+IFR-AK-CAZ-SC 368090.95 MWD+IFR-AK-CAZ-SC 368060.13 MWD+IFR-AK-CAZ-SC li 368033.32 MWD+IFR-AK-CAZ-SC 368011.02 MWD+IFR-AK-CAZ-SC 367933.99 MWD+IFR-AK-CAZ-SC 367860.02 MWD+IFR-AK-CAZ-SC 367788.84 MWD+IFR-AK-CAZ-SC 367721.04 MWD+IFR-AK-CAZ-SC 367655.68 MWD+IFR-AK-CAZ-SC 367593.28 MWD+IFR-AK-CAZ-SC 367534.88 MWD+IFR-AK-CAZ-SC 367480.58 MWD+IFR-AK-CAZ-SC 367428.70 MWD+IFR-AK-CAZ-SC 367417.35 MWD+IFR-AK-CAZ-SC ~ 367401.07 MWD+IFR-AK-CAZ-SC ~I 367386.86 MWD+IFR-AK-CAZ-SC 367359.85 MWD+IFR-AK-CAZ-SC 367341.28 MWD+IFR-AK-CAZ-SC ' 367320.97 MWD+IFR-AK-CAZ-SC 367300.37 MWD+IFR-AK-CAZ-SC I 367284.67 MWD+IFR-AK-CAZ-SC 367263.89 MWD+IFR-AK-CAZ-SC 367246.16 MWD+IFR-AK-CAZ-SC 367210.38 MWD+IFR-AK-CAZ-SC 367184.62 MWD+IFR-AK-CAZ-SC 367165.00 MWD+IFR-AK-CAZ-SC 367145.15 MWD+IFR-AK-CAZ-SC 367123.84 MWD+IFR-AK-CAZ-SC 367104.67 MWD+IFR-AK-CAZ-SC 367087.38 MWD+IFR-AK-CAZ-SC 367070.85 MWD+IFR-AK-CAZ-SC 367058.89 MWD+IFR-AK-CAZ-SC '~ i~ Halliburton Company Survey Report Company: ConocoPhilEipsAlaska lnc. Date: 9/12/2006 Time: 13:39:22 pa;;e: 5 Field: Colville River Unit Co-ordinatc lti~t:) Reference: Well: CD4-318, True North Site:. Alpine CD4 Ve rtical ("f~ U) Kcfcrcncc: CD4-318A: 55.9 Nell;" CD4-318 Sectiw- (VS( Reference: Well (O.OON,O.OOE,200.OOAzi) ~'i'ellpath: CD4-318A Su re c~ (alc ulatia~ Method: Minimum Curvat ure llb: Oracle Survey ____ _ _ _ _ bID Incl ~1zim 'hell Scs 71~ U v/5 N:;ly y]apA viapE Tool ft deg deg ft ft ft ft ft ft I 16613.06 90.48 358 .72 7235. 83 7179 .93 -4446 .15 -10719. 26 5953175 .59 367054.68 MWD+IFR-AK-CAZ-SC i 16710.98 90.41 0 .87 7235. 07 7179 .17 -4348 .24 -10719. 61 5953273 .49 367055.92 MWD+IFR-AK-CAZ-SC ~ i 16802.75 90.10 0 .75 7234. 66 7178 .76 -4256 .48 -10718. 32 5953365 .21 367058.71 MWD+IFR-AK-CAZ-SC 16898.87 89.83 1 .08 7234. 72 7178 .82 -4160 .38 -10716. 78 5953461 .27 367061.80 MWD+IFR-AK-CAZ-SC 16994.68 91.78 359 .08 7233. 37 7177 .47 -4064 .59 -10716. 65 5953557 .04 367063.49 MWD+IFR-AK-CAZ-SC 17090.79 90.48 357 .64 7231. 48 7175 .58 -3968 .54 -10719. 40 5953653 .11 367062.31 MWD+IFR-AK-CAZ-SC 17187.26 90.72 354 .32 7230. 46 7174 .56 -3872 .32 -10726. 16 5953749 .41 367057.11 MWD+IFR-AK-CAZ-SC 17281.63 90.89 352 .73 7229. 14 7173 .24 -3778 .57 -10736. 80 5953843. 32 367047.99 MWD+IFR-AK-CAZ-SC i 17377.50 89.69 348 .00 7228. 65 7172 .75 -3684 .08 -10752. 84 5953938. 05 367033.49 MWD+IFR-AK-CAZ-SC j 17472.76 89.38 344 .04 7229. 43 7173 .53 -3591 .66 -10775. 85 5954030. 82 367011.99 MWD+IFR-AK-CAZ-SC 17567.83 90.34 343 .08 7229. 66 7173 .76 -3500 .48 -10802. 75 5954122 .42 366986.57 MWD+IFR-AK-CAZ-SC 17662.94 90.82 343 .59 7228. 70 7172 .80 -3409 .37 -10830. 03 5954213 .95 366960.78 MWD+IFR-AK-CAZ-SC 17758.39 90.79 345 .46 7227. 36 7171 .46 -3317 .40 -10855. 49 5954306 .32 366936.82 MWD+IFR-AK-CAZ-SC 17853.54 90.96 348 .23 7225. 90 7170 .00 -3224 .76 -10877. 14 5954399 .29 366916.68 MWD+IFR-AK-CAZ-SC 17948.86 91.16 351 .53 7224. 14 7168 .24 -3130 .96 -10893. 89 5954493 .35 366901.46 MWD+IFR-AK-CAZ-SC 18044.52 90.55 353 .52 7222. 71 7166 .81 -3036 .12 -10906. 33 5954588 .36 366890.57 I MWD+IFR-AK-CAZ-SC 18140.18 90.07 355 .76 7222. 19 7166 .29 -2940 .89 -10915. 26 5954683. 72 366883.18 MWD+IFR-AK-CAZ-SC i, 18234.82 90.27 357 .28 7221. 91 7166 .01 -2846 .43 -10921. 01 5954778. 25 366878.97 MWD+IFR-AK-CAZ-SC 18329.47 90.31 358 .19 7221. 43 7165 .53 -2751 .85 -10924. 75 5954872 .87 366876.77 MWD+IFR-AK-CAZ-SC 18423.42 90.89 359 .58 7220. 45 7164 .55 -2657 .93 -10926. 58 5954966. 80 366876.47 MWD+IFR-AK-CAZ-SC 18520.23 89.96 357 .47 7219. 73 7163 .83 -2561 .16 -10929. 07 5955063 .59 366875.55 MWD+IFR-AK-CAZ-SC 18613.86 89.83 355 .07 7219. 90 7164 .00 -2467 .74 -10935. 16 5955157 .09 366870.98 MWD+IFR-AK-CAZ-SC ~ 18708.96 90.10 352 .61 7219. 96 7164 .06 -2373 .19 -10945. 36 5955251 .78 366862.31 MWD+IFR-AK-CAZ-SC 18807.49 90.31 351 .82 7219. 61 7163 .71 -2275 .57 -10958. 71 5955349 .60 366850.55 MWD+IFR-AK-CAZ-SC ~ 18900.08 89.93 349 .21 7219. 41 7163 .51 -2184 .26 -10973. 97 5955441 .14 366836.78 MWD+IFR-AK-CAZ-SC 18996.48 90.10 349 .42 7219. 39 7163 .49 -2089 .53 -10991. 84 5955536. 14 366820.45 MWD+IFR-AK-CAZ-SC 19091.39 90.24 350 .85 7219. 11 7163 .21 -1996 .02 -11008. 10 5955629. 89 366805.72 MWD+IFR-AK-CAZ-SC '~ ~ 19186.28 90.75 350 .34 7218. 29 7162 .39 -1902 .41 -11023. 60 5955723. 73 366791.73 MWD+IFR-AK-CAZ-SC 19280.37 90.65 348 .46 7217. 14 7161 .24 -1809 .94 -11040. 91 5955816. 47 366775.94 MWD+IFR-AK-CAZ-SC 19376.20 88.83 345 .89 7217. 57 7161 .67 -1716 .51 -11062. 18 5955910. 22 366756.19 MWD+IFR-AK-CAZ-SC 19471.65 89.04 343 .94 7219. 35 7163 .45 -1624 .37 -11087. 02 5956002 .74 366732.86 MWD+IFR-AK-CAZ-SC 19567.30 89.11 342 .98 7220. 89 7164 .99 -1532 .69 -11114. 24 5956094 .84 366707.13 MWD+IFR-AK-CAZ-SC 19661.74 89.59 340 .50 7221. 96 7166 .06 -1443 .02 -11143. 83 5956184 .98 366679.00 MWD+IFR-AK-CAZ-SC 19757.08 90.96 338 .96 7221. 51 7165 .61 -1353 .59 -11176. 86 5956274 .92 366647.43 MWD+IFR-AK-CAZ-SC 19850.41 92.43 341 .33 7218. 74 7162 .84 -1265 .86 -11208. 54 5956363. 16 366617.18 ~ MWD+IFR-AK-CAZ-SC i i 19947.42 90.07 343 .15 7216. 63 7160 .73 -1173 .50 -11238. 12 5956455. 97 366589.11 MWD+IFR-AK-CAZ-SC 20041.97 89.55 343 .63 7216. 94 7161 .04 -1082 .90 -11265. 15 5956546. 99 366563.56 MWD+IFR-AK-CAZ-SC '. 20137.55 89.55 343 .58 7217. 69 7161 .79 -991 .21 -11292. 12 5956639. 10 366538.08 MWD+IFR-AK-CAZ-SC ~ 20229.74 91.23 344 .23 7217. 06 7161 .16 -902 .64 -11317. 68 5956728. 07 366513.97 MWD+IFR-AK-CAZ-SC 20327.28 89.69 345 .60 7216. 28 7160 .38 -808 .47 -11343. 06 5956822. 63 366490.12 MWD+IFR-AK-CAZ-SC 20421.87 89.59 347 .16 7216. 88 7160 .98 -716 .54 -11365. 33 5956914 .90 366469.35 MWD+IFR-AK-CAZ-SC 20515.63 91.61 351 .22 7215. 89 7159 .99 -624 .48 -11382. 91 5957007 .23 366453.27 MWD+IFR-AK-CAZ-SC 20549.47 92.13 353 .14 7214. 79 7158 .89 -590 .97 -11387. 52 5957040 .81 366449.21 MWD+IFR-AK-CAZ-SC • 20612.00 92.13 353 .14 7212. 47 , 7156 .57 -528 .93 -11394. 98 5957102. 95 366442.76 ~ PROJECTED to TD `~ ~ ~ono+ccPhili s Time Lo Summa Time Lo s Date From' To Dur - S. De th E. De th Phase Ccde Subcode T COM - 07/30/2006 19:00 00:00 5.00 MIRU MOVE - MOB P -- Prep rig for move -Move ball mill, pit & motor complexes -Jack floor to moving position -Move to CD4-318A - Center up over well -Jack floor to drillin osition 07/31/2006 00:00 00:30 0.50 MIRU MOVE RURD P RU service lines -Hook up ball mill - Acce t ri 0030 hrs. 7/31/2006 00:30 01:30 1.00 PROD1 DRILL OTHR P RU FMC lubricator & pull BPV RD Lubicator 01:30 03:00 1.50 PROD1 DRILL OTHR P Spot open top tank for well kill - RU squeeze manifold and lines to wellhead - 03:00 04:45 1.75 PROD1 DRILL OTHR P Bring XO's & other equipment to rig floor for well kill & BOPE testin 04:45 05:00 0.25 PROD1 DRILL SFTY P Held pre job with crew on well kill ops 05:00 09:00 4.00 PROD1 DRILL CIRC P Test lines to 2500 psi -displace well with 550 bbls 9.3 ppg brine - @ 3 BBP/min 660 is - FCP 480 si 09:00 09:45 0.75 PROD1 DRILL OTHR P Shut down & monitor well -observed flow f/ annulus -monitor well - 0 PSI on tb side 175 is on annulus 09:45 10:15 0.50 PROD1 DRILL CIRC T Circ an additional 50 bbls 9.3 ppg brine 2 bbls/min -Shut down 10:15 11:00 0.75 PROD1 DRILL OTHR T Monitor well Tbg 0 psi -Annulus 175 si 11:00 14:15 3.25 PROD1 DRILL OTHR T Monitor well while bring on 9.6 ppg brine - Tb - 0 si Annulus 195 is 14:15 16:30 2.25 PROD1 DRILL OTHR T Circ well to 9.6 ppg brine @ 4.5 bbls/min 950 si 16:30 21:45 5.25 PROD1 DRILL P Shut down - no flow f/annulus - monitorwell 30 mins. Tbg 0 psi annulus 0 psi - RD Circ eugipment - RU FMC lubricator & Set TWC - ND tree - NU BOPE 21:45 00:00 2.25 PROD1 WELCT BOPE P RU to test BOPE against TWC -Test Hyrill to 250 & 3500 psi -Top rams to 250 & 5000 si 08/01/2006 00:00 04:30 4.50 PROD1 WELCT P Finish testing BOPE -pipe rams - Ckoke & kill line valves -floor valves - 250 & 5000 psi -Accumulator closure test -Blind rams 250 & 5000 psi - RD testing eugipment -set mouse hole - Blown down lines 04:30 05:00 0.50 PROD1 WELCT P RU & pull TWC 05:00 05:30 0.50 PROD1 DRILL OTHR P RU Landing jt. A - MU XO' -screw into tbg hanger -screw into TD -Pull up & unseat tbg hanger -pulled 10' - PU 210 k -slack -off 5' m. ~; mot.°a 9 Time Logs _ _ Date From To Dur ! th E. De th Phase Code Subcode T M 08/01/2006 05:30 08:00 2.50 PROD1 DRILL CIRC P Close Hydril -Circulate btms up through choke as a precaution for any trapped gas around packer - 3 bbls/min @ 400 psi - no gas or oil on btms up -open Hydril monitor well fluid level dro in slow) 08:00 09:00 1.00 PROD1 RPCOh PULD P Pull tbg hanger to rig floor -observed over pull to 250 k then string dropped back to original PU wt. 170 k - LD landing jt. - tbg hanger - 2 jts. 4 1/2" tb & XO 3 1/2" x 4 1/2" 09:00 00:00 15.00 PROD1 RPCOti PULD P POOH & LD 3 1/2" tbg & otherjewelry in strin 08/02/2006 00:00 03:15 3.25 PROD1 RPCOCV PULD P Cont. POOH w/ 3 1/2" completion assembly - LD tbg - GLM -Packer - DS, XN, & X ni les, WLEG 03:15 03:45 0.50 PROD1 RPCOh OTHR P PU LD jt. A -break off XO subs & pup 03:45 04:30 0.75 PROD1 RPCOh OTHR P RD tbg equipment 7 -clean up rig floor of excess a ui ment 04:30 05:00 0.50 PROD1 RPCOh OTHR P RU rig tongs in derrick 7 Set wear bushin 05:00 07:45 2.75 454 PROD1 FISH PULD P MU milling assembly -mill, 2 boot baskets, string mag. -bumper sub - PU 8 - 4 3/4" DC's f/ pipe shed -RIH wears & 5 'ts. HWDP - to 454' 07:45 12:00 4.25 454 4,743 PROD1 FISH PULD P RIH w/ milling assembly f/ 454' to 4743' - ickin u 4" DP f/ i e shed 12:00 16:00 4.00 4,743 6,196 PROD1 FISH PULD P Cont. RIH w/ milling assembly & finish ickin u 4" DP f/ shed to 6,196'. 16:00 19:45 3.75 6,196 15,037 PROD1 FISH TRIP P RIH with stands from derrick to 15,037'. 19:45 21:00 1.25 15,037 15,242 PROD1 FISH WASH P Washed from 15,037' to 15,242' with 80 RPM and 222 GPM. PP 1200 si. 21:00 22:30 1.50 15,242 15,246 PROD1 FISH MILL P Milled 4' from 15,242' to 15,246'. No indication of junk. Pumped 20 Bbl Hi Vis while milling. Worked junk baskets. RPM 80 WOB 8 K. GPM 222 PP 1200 si. 22:30 00:00 1.50 15,246 15,246 PROD1 FISH CIRC P Pumped 30 Bbl Hi Vis pill and circulated out. 222 GPM 80 RPM 1200 si. 08/03/2006 00:00 00:30 0.50 15,246 15,246 PROD1 FISH CIRC P Pump Hi-vis sweep @ 15246' - 210 gpm @ 1150 psi w/ 80 RPM -torque 16k 00:30 01:00 0.50 15,246 15,033 PROD1 FISH TRIP P POOH - backreaming f/ 15,246' to 15,033' - 210 gpm @ 1000 psi w/ 50 r m W/ 15 k for ue 01:00 09:15 8.25 15,033 454 PROD1 FISH TRIP P POOH on TT f/ 15,033' to 454' - * flow checked @ 7" shoe fluid level dropping 09:15 11:00 1.75 454 0 PROD1 FISH PULD P Flow ck @ BHA (static) Std back HWDP & Jars - LD 4 3/4" DC's -break down & Baker tools -Recovered 1 piece of cone 1" x 1 1/2" & a lot of shale - LD mill & tools ~~ ~ a.m. ~ ~-_-~~~~~n ~s._.~_ _~ ~ ~ a..e . am..._~~_.. ~. ~ ... _~~ . ~_...~..~_ _ ....~ . ... , ~~ ~r ~_..®... ~.____ __ ~ _ _.m.~ _~..,w.._~ ~~ Time Los Date From To Dur tp h E. De th Phase Code Subcode T M _ 08/03/2006 11:00 14:00 3.00 0 377 PROD1 DRILL PULD P MU bit , PD bias unit w/ float -test tool 210 m - 14:00 15:00 1.00 377 2,279 PROD1 DRILL TRIP P RIH to 2279'. 15:00 16:45 1.75 2,279 2,279 PROD1 RIGMN SVRG P Cut drilling line and serviced Top Drive. 16:45 22:45 6.00 2,279 15,047 PROD1 DRILL TRIP P RIH to 15,047' filling pipe every 20 stands. 22:45 00:00 1.25 15,047 15,047 PROD1 DRILL CIRC P Estabilished circulation and pumped soap pill followed by 9.2 PPG Flow Pro mud. 08/04/2006 00:00 00:45 0.75 15,047 15,047 PROD1 DRILL CIRC P Continued displacing with 9.2 PPG Flow Pro. 00:45 12:00 1125 15,047 15,137 PROD1 DRILL REAM T Washed and reamed from 15,047' to 15,137' Hole packing off. Raised MW to 9.8 PPG while reamin . 12:00 14:45 2.75 15,137 15,150 PROD1 DRILL REAM T Reamed from 15,137' to 15,150' hole ackin off no ro ress. 14:45 15:45 1.00 15,150 14,861 PROD1 DRILL TRIP T POOH backreaming from 15,150' to 14,861'. 15:45 20:00 4.25 14,861 14,861 PROD1 DRILL CIRC T Circulated and transported 9.6 PPG Brine. Displaced well to brine and flow checked. 20:00 00:00 4.00 14,861 9,617 PROD1 DRILL TRIP T POOH from 14,861' to 9,617'. 08/05/2006 00:00 06:00 6.00 9,617 377 PROD1 DRILL TRIP T Cont. POOH f/ 9617' to 377' (BHA) Flow ck. Static 06:00 07:30 1.50 377 0 PROD1 DRILL PULD T Std. back HWP,Jars & NM flex DC's - LD MWD -Periscope -Powder Drive & bit 07:30 12:00 4.50 0 6,672 PROD1 DRILL TRIP X PJSM - MU Baker Hydro-Set bridge plug-RIH on4'DPto6672' PU wt 150 SO wt 120 12:00 15:30 3.50 6,672 14,824 PROD1 DRILL TRIP X Continue RIH w/ Baker Bridge plug f/ 6672' to 14,824'. 15:30 16:30 1.00 14,824 14,824 PROD1 PLUG MPSP X Broke circulation. Dropped ball and pumped down. Set Bridge Plug 14,824'. 16:30 17:00 0.50 14,824 14,824 PROD1 PLUG MPSP X Tested Bridge Plug with 2000 psi. 17:00 23:00 6.00 14,824 0 PROD1 PLUG TRIP X POOH from 14,824' to 0'. 23:00 00:00 1.00 0 0 PROD1 PLUG PULD X Layed down running tools and changed elevators. 08/06/2006 00:00 02:00 2.00 0 630 PROD1 DRILL PULD X MU Whipstock assembly -orient MWD - PU 8 DC's - 6 HWDP 02:00 12:30 10.50 630 14,729 PROD1 DRILL TRIP X RIH w/ Whipstock assembly f/ 630' to 14,729' _ 12:30 14:30 2.00 14,729 14,729 PROD1 RIGMN SLPC P Cut & slip drill line -Change well over f/ 9.6 brine to 9.8 FloPro 14:30 16:15 1.75 14,729 14,809 PROD1 STK WPST X Broke circulation . Oreint and set Whi stock 60 De .left. 16:15 19:30 3.25 14,809 14,822 PROD1 STK WPST X Sheared off Mill and cut window in casin . Pum ed 3 Hi Vis swee s. ~~ -. _.~... ®.. ~__-_ a~....e.w __. . e®®~_T__.. _ ..~..~......m_, _~...... ~~ __,.. ~ . _ ~ ;~ of ?~ 1 Time Logs _ Date From To Dur ,, th E. De th Phase Code Subcode T M 08/06/2006 19:30 22:00 2.50 14,822 14,834 PROD1 STK KOST X Milled 12' of hole from 14,822' to 14,834'. WOM 10 K 100 RPM. 5.5 BPM 2070 si. 22:00 23:15 1.25 14,834 14,834 PROD1 STK CIRC X Pumped Hi Vis sweep and circulated out 7 BPM. 2450 si. 23:15 00:00 0.75 14,834 14,822 PROD1 CEMEf~ FIT X Pulled up into casing and RU for FIT. Did FIT to 11.8 PPG EMW. 08/07/2006 00:00 01:30 1.50 14,822 14,711 PROD1 DRILL CIRC X Pull up to 14,711' -Change well over to 9.6 ppg brine @ 7 BPM - ICP 2720 psi FCP 2380 si 01:30 12:00 10.50 14,711 4,521 PROD1 DRILL TRIP X POOH on TT f/ 14,711' to 4521' -Flow ck. well 13,300' static 12:00 13:45 1.75 4,521 363 PROD1 DRILL TRIP X Cont. POOH w/ milling assembly 13:45 15:45 2.00 363 0 PROD1 STK PULD X Laid down BHA and cleared floor. 15:45 17:15 1.50 0 356 PROD1 DRILL PULD X Picked up Mud Motor drilling BHA. 17:15 00:00 6.75 356 13,218 PROD1 DRILL TRIP X RIH from 356' to 13,218' Filling pipe eve 20 stands. 08/08/2006 00:00 00:30 0.50 13,218 14,748 PROD1 DRILL TRIP X RIH to 14,748'. 00:30 02:00 1.50 14,748 14,748 PROD1 DRILL CIRC X Displaced to 9.8 PPG Flow Pro. 02:00 03:30 1.50 14,748 14,809 PROD1 DRILL KOST X Worked through window, turned on pumps and pressured up. Pulled up and had overpull 80 - 90 K. in the casing above the window and whipstock. Worked down again and took weight at the top of the window. Worked by and into hole again. Turned on pumps with the same results. Same over pull above whipstock. Tried to go down several times, with pump and without pump(Pump @ 2 BPM), and could not pass top of whipstock. Fishing tool Hand was present while attem tin to enter window. 03:30 05:30 2.00 14,809 14,748 PROD1 DRILL CIRC XT Pumped Hi Vis and displaced to 9.6 PPG Brine. Stood back 1 stand after hi Vis was in the annulus. 05:30 12:00 6.50 14,748 11,031 PROD1 DRILL TRIP XT POOH to pick up Mill. From 14,748' to 11,031'. 12:00 18:30 6.50 11,031 358 PROD1 DRILL TRIP XT Continue POOH from 11,031' to 358'. 18:30 20:00 1.50 358 0 PROD1 DRILL PULD XT Laid down Motor BHA and bit. Bit was dams ed from workin on 'unk. 20:00 22:00 2.00 0 459 PROD1 DRILL PULD XT Picked up Mill BHA and 8 DC's. 22:00 00:00 2.00 459 3,314 PROD1 DRILL TRIP XT RIH from 459' to 3,314' Filling pipe eve 30 stands Float in strin . 08/09/2006 00:00 05:30 5.50 3,314 14,748 PROD1 DRILL TRIP XT RIH w/ 4" DP from 3314' to 14,748'. Fill i e eve 20 stds. 05:30 07:00 1.50 14,748 14,748 PROD1 DRILL CIRC XT PJSM. Pump sweep. Displace well to 9.8 ppg flo-pro while cut slip and cut drillin line. Service to drive. cY « ~# C'' Time Logs _ _~ Date From To Dur th E. De'th Phase Code Subcode T M 08/09/2006 07:00 12:00 5.00 14,748 14,836 PROD1 DRILL REAM XT RIH. Tag up on top of window at ' ' 14,809 . Wash and ream from 14,809 to 14,834'. Hole tight and packing off. Continue reaming and back reaming until hole cleaned up. Fine shale and metal over shakers. Drill 2' new hole to 14,836'. No problems working through window. 12:00 15:00 3.00 14,836 14,836 PROD1 DRILL CIRC XT Pumped Hi Vis sweep and worked throu h window 5.6 BPM 1670 si. 15:00 16:00 1.00 14,836 14,366 PROD1 DRILL TRIP XT POOH with pump from 14,836' to 14,366'. 16:00 17:45 1.75 14,366 14,366 PROD1 DRILL CIRC XT Displaced well to 9.6 PPG Brine. 17:45 21:00 3.25 14,366 11,508 PROD1 DRILL TRIP XT Observed well dead. POOH on Trip Tand from 14,366' to 11,508'. 21:00 21:45 0.75 11,508 11,508 PROD1 DRILL CIRC XT Observed well dead. Pipe was over flowin Circulated to balance fluid. 21:45 00:00 2.25 11,508 9,412 PROD1 DRILL TRIP XT Continued POOH on trip tank from 11,508' to 9,412'. Pie ullin d 08/10/2006 00:00 05:00 5.00 9,412 230 PROD1 DRILL TRIP XT POH from 9412' to HEDP. Flow check well. Static. Stand back HWDP and 'ars. 05:00 07:00 2.00 230 0 PROD1 DRILL TRIP XT Stand back 2 stands DC's. LD 2 watermelon mills and flex joint. Pin on bottom watermelon mill had broken. Left window mill and 3' bit sub in hole. 07:00 12:00 5.00 0 0 PROD1 DRILL WOEQ X Stand by for tools to arrive from Deadhorse. Monitor well. Perform work orders on ri . 12:00 13:00 1.00 0 0 PROD1 DRILL PULD X Laid down 6 Drill Collars from derrick. 13:00 13:45 0.75 0 9 PROD1 DRILL PULD X Made up Baker Cement Retainer and runnin tools for DP Set. 13:45 22:30 8.75 9 14,765 PROD1 DRILL TRIP X RIH with Cement Retainer From 9' to 14,765'. 22:30 00:00 1.50 14,765 14,765 PROD1 DRILL CIRC X CBU @ 3.5 BPM 520 psi. 08/11/2006 00:00 02:15 2.25 14,765 14,759 PROD1 DRILL OTHR X Attempt to set Baker cement retainer at 14,770' and 14,759' with no success. 02:15 12:00 9.75 14,759 7,537 PROD1 DRILL TRIP XT POH slow from 14,759' to 7,537'. 12:00 18:00 6.00 7,537 0 PROD1 DRILL TRIP XT Continue POOH from 7,537' to surface. Laid down running tool and cement retainer. 18:00 19:00 1.00 0 0 PROD1 CEME~ RURD XT Rig up to run 3 1/2" tubing. PJSM. 19:00 21:00 2.00 0 1,033 PROD1 CEMEI~ PULD XT Picked up and RIH 33 Jts 3 1/2" tubing with muleshoe to 1033'. 21:00 00:00 3.00 1,033 8,466 PROD1 CEMEf~ TRIP XT RIH with 4" DP from 1033' to 8,466'. 08/12/2006 00:00 03:00 3.00 8,466 14,806 PROD1 CEMEf~ TRIP XT Finish RIH w/ 4" DP from 8466' to 14, 806'. 03:00 04:15 1.25 14,806 14,806 PROD1 CEMEf~ CIRC XT CBU at 7 bpm. ._~, Time Logs _ Date From To D ur S th E. De th Phase Code Subcode T M 08/12/2006 04:15 05:15 _ _ r 1.00 14,806 14,806 PROD1 CEME~ DISP X ___ PJSM. Dowell pumped 10 bbls H2O, 15 bbls 15.8 cement and 4 blls H2O. Rig displaced cement with 9.6 brine. Balance lu from 14,806 to 14,406'. --• 05:15 06:00 0.75 14,806 13,856 PROD1 CEMEt~ TRIP X POH w/ 10 stds DP to 13,856'. 06:00 06:45 0.75 13,856 13,856 PROD1 CEMEf~ CIRC X CBU at 7 bpm. C~~ ~~ r\ t~ 06:45 09:00 2.25 13,856 11,380 PROD1 CEME~ TRIP X POH w/ 26 stds 4" DP from 13,856' to 11,380'. tip 09:00 10:00 1.00 11,380 11,380 PROD1 RIGMN SVRG X Slip and cut drilling line. Service top drive. 10:00 18:30 8.50 11,380 1,033 PROD1 CEMEI~ TRIP X POH LD 4" DP from 11,380' to 1033'. 18:30 20:00 1.50 1,033 0 PROD1 CEME~ TRIP X POOH and stood back 11 stands of 3 1/2" tubin . 20:00 22:30 2.50 0 3,775 PROD1 CEMEC\ TRIP X Made up Bridge plug and RIH to 3,775'. Set BP with 800 psi. Tagged with 5 K. 22:30 23:30 1.00 3,775 3,775 PROD1 CEMEt` CIRC X Displaced well to 9.6 PPG LSND mud 7 BPM. Cleaned Possumbell . 23:30 00:00 0.50 3,775 3,247 PROD1 CEME~ TRIP X POOH from 3,775' to 3,247'. 08/13/2006 00:00 01:00 1.00 3,247 0 PROD1 CEME~ TRIP X POH w/ 4" DP and setting tool from 3247' to surface. LD settin tool. 01:00 03:00 2.00 0 3,645 PROD1 CASIN( TRIP X RIH w/ Baker 7" csg mechanical csg cutter on 4" DP to 3645'. 03:00 03:30 0.50 3,645 3,645 PROD1 CASIN( OTHR X Cut 7" csg at 3645' with 80 rpms and 3.1 bpm. Had good pressure drop as indication of full extension (8 1/4") of cutter arms. No communication with 9 5/8" X 7" annulus. 03:30 04:00 0.50 3,645 3,645 PROD1 CASIN( OTHR X Close annular preventer. Pressure DP and 7' csg to 500 psi. No communication with 9 5/8" x 7" annulus. 04:00 04:30 0.50 3,645 3,645 PROD1 CASIN( CIRC X CBU. Had small amount of diesel at bottoms u . 04:30 05:30 1.00 3,645 3,645 PROD1 CASIN( CIRC X Had very small flow out 4" x 7" annulus. Circ and increase mud wt to 9.8 05:30 06:00 0.50 3,645 3,645 PROD1 CASIN( OTHR X Monitor well. 4" x 7" annulus was static. Pressure on 9 5/8" x 7" annulus had increased from 0 to 500 si. 06:00 06:30 0.50 3,645 3,645 PROD1 CASIN( CIRC X Circ down 4" DP and out 4" x 7" annulus at 5 bpm. Opened 9 5/8" x 7" annulus to flow back tank. Flowed back 1/2 bbl diesel. No flow. 06:30 08:30 2.00 3,645 3,645 PROD1 CASIN( CIRC X Circ at 4 bpm down 4" DP and out 7" annulus. Monitor 9 5/8" x 7" annulus. SIP - 0. Open annulus to flow back tank. No flow. 08:30 09:00 0.50 3,645 3,346 PROD1 CASIN( TRIP X POH w/ 7" csg cutter to 3346'. N~.~ ~ _ ~,. ~~.. ~ ~_. ., ..m~. ~ ~ __~e ~ . e ...e , ' ~ ~ ref ~s€~ ~ ~ m,_ _ _ ___ ~~.. ~ .._ _...m_. Time Logs __ Date From To Dur th E. De th Fhase Code Subcode T M 08/13/2006 09:00 09:15 _ _ 0.25 3,346 3,346 PROD1 CASIN( OTHR X Cut 7" csg at 3346' w/ 80 rpms and 3.2 bpm. 9 5/8" x 7" annulus pressure increased from 0 to 500 psi. Check cut with cutter. 1' seperation of 7" csg at the cut. 09:15 12:00 2.75 3,346 3,346 PROD1 CASIN( CIRC X Circ down 4" DP and out 4" x 7" annulus at 7 bpm. Opened 9 5/8" x 7" annulus to flow back tank. Flowed back 85 bbls diesel and 10 bbls drilling mud. Monitor well. Static. 12:00 14:30 2.50 3,346 0 PROD1 CASIN( TRIP X POOH and laid down casing cutter. 14:30 17:00 2.50 0 0 PROD1 CASIN( CIRC X Pumped down 7" taking returns from 7" X 9 5/8" annulus. circulated 90 Bbls of diesel too en to tank. 17:00 19:00 2.00 0 0 PROD1 WELCT BOPE X Changed upper pipe rams to 7" and tested 250/5000 si. 19:00 20:00 1.00 0 0 PROD1 CASIN( OTHR X Made up tools and recovered Packoff. 20:00 22:00 2.00 0 3,269 PROD1 CASIN( RURD X Rigged up and pulled casing hanger. Laid down hanger and landing joint and 1 Jt casin .Well was swabbin . 22:00 00:00 2.00 3,269 3,269 PROD1 CASIN( CIRC X Circulated and conditioned mud. Mud had lite spots and was backflowing. Well was dead. Pumped slug and observed well. 08/14/2006 00:00 01:00 1.00 3,269 3,131 PROD1 CASIN( OTHR X POH and LD 7" csg from 3346' to 3131'. Hole not takin ro er fill. 01:00 02:00 1.00 3,131 3,131 PROD1 CASIN( CIRC X Circ and condition mud at 4 bpm at 120 si. 02:00 03:00 1.00 3,131 2,873 PROD1 CASIN( OTHR X POH and LD 7" csg from 3131' to 2873. Hole not taking proper fill. Add de-foamer to mud. 03:00 05:00 2.00 2,873 2,873 PROD1 CASIN( CIRC X Displaced 9.6 LSND with 9.8 brine water. 05:00 05:30 0.50 2,873 2,842 PROD1 CASIN( OTHR X POH w/ 1 jt 7" csg. Hole was swabbin . 05:30 07:15 1.75 2,842 2,842 PROD1 CASIN( CIRC X Circ at 4 bpms. Reciprocate csg. Stage pumps up to 8 bpm at 250 psi. Monitor well. Static. 07:15 14:00 6.75 2,842 0 PROD1 CASIN( OTHR X POH and LD 65 jts 7" csg + 20' cut jt. No hole roblems. 14:00 16:00 2.00 0 0 PROD1 WELCT OTHR X Installed thin wear bushing. Change top pipe rams from 7" to 3 1/2" x 6" variables. Test rams to 5000 si. 16:00 16:30 0.50 0 0 PROD1 FISH OTHR X Pulled thin wear bushing and installed Ion wear bushin . 16:30 20:30 4.00 0 514 PROD1 FISH PULD XT Brought Spear and componnets to rig floor. Found XO sub to DC's was bad, took DC's out of pipe shed and loaded 16 jts of 5" HWDP. Moved tubing tail pipe to Drillers side of the derrick. Made u Sear BHA and RIH to 514'. 20:30 00:00 3.50 514 3,340 PROD1 FISH TRIP XT RIH with Spear picking up 5" DP from 514' to 3,340'. Time Logs Date From To Dur th E De th Phase Code Subcode T _ M 08/15/2006 00:00 01:00 1.00 3,346 3,346 PROD1 FISH JAR XT Engage fish. Jar on 7" csg. Pulled to 375k. Fish came free. 01:00 02:30 1.50 3,346 2,515 PROD1 FISH TRIP XT POH to 2515'. Had diesel to surface. 02:30 03:30 1.00 2,515 2,515 PROD1 FISH CIRC XT Circ and condition brine at 8 bpm at 130 si. 03:30 06:30 3.00 2,515 300 PROD1 FISH TRIP XT POH to fish. 06:30 08:30 2.00 300 0 PROD1 FISH PULD XT POH LD fishing tools and 300' 7" csg. Full recove 08:30 09:30 1.00 0 0 PROD1 CEME~ RURD X Clear floor. RU 3 1/2" tbg equipment 09:30 13:00 3.50 0 3,775 PROD1 CEMEI~ TRIP X PJSM. RIH w/ 33 jts 3 1/2" tbg w/ mule shoe on 5" DP to top of 7" csg stub at 3645' -Work tbg tail to 3775' to of bride lu 13:00 14:00 1.00 3,775 3,775 PROD1 CEMEf~ CIRC X Circulate & condition for cmt. job 10 BPM 350 si 14:00 15:00 1.00 3,775 3,775 PROD1 CEMEf~ PLUG X With tbg stinger @ 3775' -Set KO plug w/ 37.4 bbls 17.0 ppg Class G - Dis lace toe ualize - CIP 1505 hrs. 15:00 16:00 1.00 3,775 3,127 PROD1 CEME~ TRIP X POOH on TT f/3775' to 3127' 16:00 16:30 0.50 3,127 3,127 PROD1 CEMEf~ CIRC X Circ 2 x btms up @ 3127' - 10 BPM @ 310 psi -Observed cement returns f/ btms u - Calc. to of cmt 3127' 16:30 21:00 4.50 3,127 0 PROD1 CEMEI~ TRIP X Flow ck.(static) -POOH on TT f/ 3127' to 1034' - RU & LD 3 1/2" tbg - RD tbg e ui ment 21:00 21:30 0.50 0 0 PROD1 DRILL OTHR X Pull wear bushing 21:30 00:00 2.50 0 0 PROD1 WELCT BOPE X RU to test BOPE -test Hydril to 250 & 3500 psi -Pipe rams, choke & kill lines, choke manifold valves, IBOP & HRC kill to 250 i~ 5000 si 08/16/2006 00:00 02:00 2.00 0 0 PROD1 WELCT BOPE X Finish test BOPE to 250- - 5000 psi. Witness of test was waived by AOGCC re John S laldin . 02:00 16:30 14.50 0 0 PROD1 DRILL PULD X PU and stand back 312 jts 5" DP. 16:30 19:30 3.00 0 263 PROD1 DRILL PULD X MU KO assembly -Motor w/ 1.5 bend MWD -Orient motor & Mwd - Up load MWD -RIH to 263' -Shallow test tools 19:30 21:00 1.50 263 2,233 PROD1 DRILL TRIP X PU HWDP & RIH to 2233' w/ 5" DP f/ derrick 21:00 00:00 3.00 2,233 2,233 PROD1 DRILL OTHR X MU XO - LD 19 stds 4" drill pipe f/ derrick - 08/17/2006 00:00 01:15 1.25 2,233 726 INTRM2 DRILL OTHR X Finish LD 4" DP from derrick. POH std back 5" DP to 726'. 01:15 05:30 4.25 726 2,994 INTRM2 DRILL OTHR X PU ans stand back 72 jts 5" DP. 05:30 07:00 1.50 2,994 2,994 INTRM2 DRILL SLPC X Slip and cut drlg line. Service top drive. 07:00 12:00 5.00 2,994 3,495 INTRM2 CEME~ DRLG X Break circ. Wash and ream from 2994' to firm cement at 3200'. Drill out firm/hard cement from 3200' to 3495'. . e~ ~ ___._ m.....m~~ . -, ~®~~._ _ --__ ...e.._H_~~m~..~ __._~. ~®®~_s ,__ ~w® ~F____~ Time Logs _ _ Date From To Dur__T th E. Depth Phase Code Subcode T ___ M: 08!17/2006 12:00 12:30 0.50 3,495 3,495 INTRM2 DRILL CIRC X Displace well to 9.6 ppg LSND mud. 12:30 20:00 7.50 3,495 3,567 INTRM2 DRILL KOST X Orient motor & time drill off cmt plug f/ 3495' to 3567' -Off cmt plug @ 3525' WOB 2/9 k GPM 550 1150 si 20:00 20:30 0.50 3,567 3,567 INTRM2 RIGMN RGRP XT Repair SCR blower 20:30 00:00 3.50 3,567 3,806 INTRM2 DRILL DDRL X Drill 8 3/4" hole w/ motor f/ 3567' to 3806' MD 2530' TVD ADT - 7.2 hrs = ART - .82 hrs. AST - 6.38 hrs ECD - 10.62 ppg WOB 6/11 k RPM 60 GPM 550 @ 1340 psi String wt. PU 153 SO 105 Rot 125 Torque on/off btm. - 10,500/9,000 ft/Ibs. 08/18/2006 00:00 12:00 12.00 3,806 4,895 INTRM2 DRILL DDRL X Drill 8 3/4" hole w/ motor f/ 3806' to 4895' MD 2963' TVD ADT - 7.11 hrs = ART - 6.03 hrs. AST - 1.08 hrs ECD - 10.9 ppg WOB 6/10 k RPM 70 GPM 600 @ 1950 psi String wt. PU 162 SO 110 Rot 132 Tor ue on/off btm. - 10,00/9,500 ft/Ibs. 12:00 00:00 12.00 4,895 6,038 INTRM2 DRILL DDRL X Drill 8 3/4" hole w/ motor f/ 4895' to 6038' MD 3451' TVD ADT - 7.89 hrs. =ART - 7.03 hrs. AST - .86 hrs ECD - 11.1 ppg WOB 7/12 k RPM 70 GPM 600 @ 2330 psi String wt. PU 183 SO 115 Rot 138 Torque on/off btm. - 11,500/11,000 ft/Ibs 08/19/2006 00:00 10:45 10.75 6,038 6,894 INTRM2 DRILL DDRL X Drill 8 3/4" hole w/ motor f/ 6038' to 6894' MD 3793' TVD ADT - 6.87 hrs. =ART - 6.07 hrs. AST - .8 hrs ECD - 11.3 ppg WOB 7/13 k RPM 70 GPM 600 @ 2350 psi String wt. PU 195 SO 120 Rot 145 Torque on/off btm. - 13,000/12,000 ft/Ibs 10:45 12:00 1.25 6,894 6,799 INTRM2 DRILL CIRC X Pump sweep. Circ hole clean at 600 gpm - 2230 psi - 70 rpms. Set back 1 std to 6799'. Flow check well. Static. 12:00 12:30 0.50 6,799 6,514 INTRM2 DRILL TRIP X POOH on TT f/ 6799' to 6514' - Im ro er hole fill -Flow ck.- static 12:30 14:00 1.50 6,514 5,561 INTRM2 DRILL TRIP X POOH w/ pump f/6514' to 5561' - 7 BPM @ 730 psi w/ 40 RPM -Attempt to ull on TT- Swabbin 14:00 14:30 0.50 5,561 5,561 INTRM2 DRILL CIRC X Circ btms. up - 600 GPM @ 2140 psi w/ 80 RPM -flow ck -static -Attempt to ull on TT - swabbin 14:30 17:00 2.50 5,561 3,375 INTRM2 DRILL TRIP X POOH w/ pump f/ 5561' to 3375' - 7 BPM 7 BPM 17:00 18:00 1.00 3,375 3,375 INTRM2 DRILL CIRC X Circ btms up 600 gpm @ 2030 psi w/50 r m -Flow ck. static a °: ~~~ ~ Time Logs Date From To Dur ~ th E. De th Phase Code Subcode T M'_ 08/19/2006 18:00 20:00 2.00 3,375 715 INTRM2 DRILL TRIP X POOH on TT f/ 3375' to 715' -Flow ck static 20:00 00:00 4.00 715 0 INTRM2 DRILL PULD X POOH & Std back HWDP, jars & NM flex DC's -Down load MWD -break off bit - LD motor - PU GeoPilot - MU bit - MU MWD - 08/20/2006 00:00 03:00 3.00 0 357 INTRM2 DRILL PULD X Continue MU BHA. Upload MWD. MU flex collars, 2 stds HWDP and jars to 357'. Shallow test Geospan, MWD and GeoPilot. 03:00 07:45 4.75 357 6,811 INTRM2 DRILL TRIP X RIH w/HWDP, ghost reamers and 5" DP from 357' to 6811'. Fill pipe every 2000'. 07:45 08:30 0.75 6,811 6,894 INTRM2 DRILL CIRC X Break circulation. Wash from 6811' to 6894'. Stage pumps up to 550 gpm. Dis lace well with new 9.6 LSND mud. 08:30 12:00 3.50 6,894 7,146 INTRM2 DRILL DDRL X Drill 8 3/4" hole w/ GeoPilot f/ 6894' to 7146' MD 3912' TVD ADT - 2.03 ECD - 10.6 ppg WOB 12/15 k RPM 130 GPM 600 @ 1750 psi String wt. PU 210 SO 120 Rot 150 Torque on/off btm. - 13,500/12,500 ft/Ibs 12:00 00:00 12.00 7,146 8,380 INTRM2 DRILL DDRL X Drill 8 3/4" hole w/ GP f/ 7146' to 8380' MD 4445' TVD ADT - 8.47 hrs. ECD - 10.7 ppg WOB 19/22 RPM 100 GPM 550 @ 1950 psi String wt. PU 230 SO 125 Rot 160 Torque on/off btm. - 16,000/15,000 ft/Ibs 08/21/2006 00:00 12:00 12.00 8,380 9,760 INTRM2 DRILL DDRL X Drill 8 3/4" hole w/ GP f/ 8380' to 9760' MD 5027' TVD ADT - 7.9 hrs. ECD - 10.95 ppg WOB 20/25 RPM 150 GPM 650 @ 2280 psi String wt. PU 200 SO 145 Rot 170 Torque on/off btm. - 14,000/13,000 ft/Ibs 12:00 00:00 12.00 9,760 11,274 INTRM2 DRILL DDRL X Dril18 3/4" w/ GP f/ 9760' to 11,274' MD 5665' TVD ADT - 8.55 hrs. ECD - 11.13 ppg WOB 22/25 k RPM 150 GPM 650 @ 2500 psi String wt. PU 220 SO 150 Rot 175 Torque on/off btm. - 16,500/16,000 ft/Ibs 08/22/2006 00:00 12:00 12.00 11,274 12,574 INTRM2 DRILL DDRL X Drill 8 3/4" w/ GP f/ 11,274' to 12,574' MD 6213' TVD ADT - 7.69 hrs. ECD - 10.8 - 11.1 ppg WOB 24/30 k RPM 100-150 GPM 600 @ 2224 psi String wt. PU 230 SO 155 Rot 185 Torque onloff btm. - 17,500/15,500 fUl bs ,_..~_ _ ~~ea ®.... ~.~.n _ _ __ m.®. ee~~ ®.~m ~ ~ ..~._... ~ ~. _a e... ®~« ~ ~. _ ~ ~~ Time Los _ Date From To Dur th E. De th Phase Code Subcode T M 08/22/2006 12:00 00:00 12.00 12,574 13,820 INTRM2 DRILL DDRL X Drill 8 3/4" hole w/ GP f/ 12,574' to 13,820' MD 6775' TVD ADT - 8.81 hrs. ECD - 10.85 ppg WOB 18/20 k RPM 100 GPM 525 @ 1950 psi String wt. PU 247 SO 160 Rot 198 Torque on/off btm. - 18,500/17,500 ft/Ibs. 13,820 INTRM2 DRILL 08/23/2006 00:00 01:30 1.50 13,820 13,939 INTRM2 DRILL DDRL X Drill 8 3/4" hole w/ GP f/ 13,820' to 13,939' MD 6824' TVD ADT - 1.36 hrs. ECD - 10.9 ppg WOB 18/20 k RPM 100 GPM 525 @ 1870 psi String wt. PU 248 SO 160 Rot 198 Torque on/off btm. - 18,500/17,500 ft/Ibs. 01:30 03:30 2.00 13,939 13,463 INTRM2 DRILL CIRC XT Unable to obtain required dogleg for well plan -Flow check well, static - Circ and cond mud - 650 gpm / 2500 psi / 130 rpm -set back one stand eve 20 min. to 13,463' 03:30 07:15 3.75 13,463 11,084 INTRM2 DRILL TRIP XT Pump out of hole from 13,463' to 11,084' - 550 gpm / 1960 psi / 100 rpm -flow check well, static -Blow down to drive 07:15 09:30 2.25 11,084 9,252 INTRM2 DRILL TRIP XT POOH on trip tank from 11,084' to 9,252', unable to work through tight s of 9252'. 09:30 12:00 2.50 9,181 6,180 INTRM2 DRILL TRIP XT POOH on trip tank from 9,181' to 6,180', wiped through tight spot from 7,809' to 7807' -attempt to work throu h ti ht s of 6180'. 12:00 12:30 0.50 6,180 6,178 INTRM2 DRILL REAM XT Backream from 6,240' to 6,145' - worked through tight spot from 6,180' to 6,178'. Blow down to drive 12:30 14:45 2.25 6,178 3,450 INTRM2 DRILL TRIP XT POOH on trip tank from 6,178' to 3,450' -reamed through tight spot from 4,433' to 4431'. 14:45 15:15 0.50 9,252 9,181 INTRM2 DRILL REAM XT Backream from 9,274' to 9,181' - worked through tight spot from 9252' to 9248'. Blow down to drive 15:15 15:45 0.50 3,450 3,450 INTRM2 DRILL OTHR XT Flow check well, static -Pump dry job - blow down to drive 15:45 18:00 2.25 3,450 170 INTRM2 DRILL TRIP XT POOH from 3,450' -Stand back HWDP, jars -Pre job on handling BHA ,.~ _ ~ w ~ _ _ ®e..... ~. ~ ____mma - Time Lomas _ --- -- - _ -~ Date Fro~~i To Dur th E. De th Phase Code Subcode T M _ _ 08/23/2006 18:00 22:00 4.00 170 260 INTRM2 DRILL PULD XT Std back NM flex DC's -Pull up & break bit -Down load MWD -Change out Geopilot, bit & probe in MWD - up load MWD -RIH w/ NM flex DC's & 1 std HWDP to 260' -Shallow test tools OK Observed 2 of the thre sets of pizza cutters on Geopilot compressed into the body of the tool & several of the cutteers were chipped -the bit looked ood 22:00 00:00 2.00 260 2,341 INTRM2 DRILL TRIP XT RIH f/ 260' to 2341' 08/24/2006 00:00 05:30 5.50 3,484 13,844 INTRM2 DRILL TRIP XT RIH from 3,884' to 13,844' -hole appears in good condition -fill pipe eve 20 stands 05:30 06:00 0.50 2,341 3,484 INTRM2 DRILL TRIP XT RIH from 2,341' to 3484' -fill pipe 06:00 07:30 1.50 3,484 3,484 INTRM2 RIGMN SVRG XT PJSM -Slip and cut drilling line - service to drive, crown and drawworks 07:30 09:00 1.50 13,844 13,718 INTRM2 DRILL REAM XT Establish circulation -slight packoff initiaAy -worked pipe free and staged pumps up to 315 gpm / 1300 psi - 50 rpm @ 21 K torque - circ and condition mud -reamed tight hole from 13,844' to 13,860'. Backream from 13,860' to 13,718', no roblems above 13,844' 09:00 10:00 1.00 13,718 13,749 INTRM2 RIGMN RGRP XT PJSM -Rig welder repaired leak on stand i e. 10:00 12:30 2.50 13,749 13,939 INTRM2 DRILL REAM XT Staged pumps up to 450 gpm / 1680 psi / 100 rpm -ream tight hole from 13860' to 13939' -conditioned mud with 600 bbls whole mud dilution - increased pump rate to 550 gpm / 2440 psi - backream from 13,939' to 13,844' - no ti ht s ots 12:30 00:00 11.50 13,939 14,830 INTRM2 DRILL DDRL X . Drill 8 3/4" hole w/ GP f/ 13,939' to 14,830' MD 7155' TVD ADT - 8.6 hrs. ECD - 11.35 ppg WOB 22/24 k RPM 110 GPM 550 @ 2680 psi String wt. PU 260 SO 160 Rot 202 Torque on/off btm. - 19,000/17,500 ft/I bs. 08/25/2006 00:00 12:00 12.00 14,830 15,274 INTRM2 DRILL DDRL X Drill 8 3/4" hole w/ GP f/ 14,830' to 15,274' MD 7235' TVD ADT - 10.15 hrs. ECD - 11.2 ppg WOB 20/25 k RPM 110 GPM 550 @ 2540 psi String wt. PU 280 SO 155 Rot 205 Torque on/off btm. - 20,000/19,000 ft/Ibs. Penetration rate dropped to near zero the last 3 hours drilling siderite cap above ku aruk sand ,~ ~ ~ ... .....~ _ ~ ~ _ -~_~~~m. A.®~~.~_~ ~~~~ E _ .~~~~ - - Time Logs -- _ Date From To Dur th E. Depth Phase Code Subcode T _ M 08/25/2006 12:00 15:30 3.50 15,274 13,368 INTRM2 DRILL TRIP XT Flow check well, static -Pump out from 15,274' to 13,368', no problems - 500 gpm / 2150 psi / 80 rpm @ 18k ft/I bs 15:30 23:45 8.25 13,368 3,485 INTRM2 DRILL TRIP XT Flow check well, static -POOH on trip tank from 13,368' to 3485' -work through tight spot @ 5418' -Hole took ro er fill 23:45 00:00 0.25 3,485 3,485 INTRM2 DRILL OTHR XT Observe well-(static) 08/26/2006 00:00 00:30 0.50 3,485 3,485 INTRM2 DRILL TRIP XT Function test BOPE -pump dry job @ 3,485' -blow down to drive 00:30 03:00 2.50 3,485 78 INTRM2 DRILL TRIP XT POOH from 3,485' to 78' - LD ghost reamer -stood back hwdp and flex collars 03:00 04:15 1.25 78 0 INTRM2 DRILL PULD XT Down load mwd - LDpony collar, bit and GeoPilot -clear tools from ri floor 04:15 05:30 1.25 0 79 INTRM2 DRILL PULD XT PU bit, motor and mwd tools -initialize mwd tools 05:30 06:00 0.50 79 715 INTRM2 DRILL TRIP XT RIH with flex collars and hwdp to 715' - shallow test tools 06:00 07:30 1.50 715 3,089 INTRM2 DRILL TRIP XT RIH with 5" drill pipe to 3,089' 07:30 08:45 1.25 3,089 3,089 INTRM2 RIGMN SVRG X Slip and cut drilling line -Service top drive, drawworks and crown 08:45 17:00 8.25 3,089 14,908 INTRM2 DRILL TRIP XT RIH from 3,089' to 14,908', tight spot - filled pipe every 20 stands -establish circ and pumped 100 bbls @ 8,789' and 13,070' 17:00 19:00 2.00 14,908 15,274 INTRM2 DRILL REAM XT Establish circulation -staged pumps up to 400 gpm / 1680 psi -wash and ream from 14, 879' to 15,274' 19:00 00:00 5.00 15,274 15,443 INTRM2 DRILL DDRL X Drill w/ motor f/ 15,274' to 15.433' MD 7249' TVD ADT - 2.47 hrs AST- 2.47 hrs. ECD - 11.07 ppg WOB 10/30 k RPM 0 GPM 546 @ 3190 psi Strin wt. PU 285 SO 160 Rot. 200 08/27/2006 00:00 12:00 12.00 15,443 15,658 INTRM2 DRILL DDRL X Drill w/ motor f/ 15,433' to 15,658' MD 7239' TVD ADT - 6.76 hrs ART - 4.8 AST- 1.96 hrs. ECD - 11.1 ppg WOB 5/15 k RPM 0/60 GPM 600 @ 3150 psi Strin wt. PU 280 SO 150 Rot. 205 12:00 13:15 1.25 15,658 15,711 INTRM2 DRILL DDRL X Drill w/ motor f/ 15,658' to 15,711' MD 7239' TVD ADT - 0.37 hrs ART - 0.27 AST- 0.1 hrs. ECD - 11.1 ppg WOB 5/15 k RPM 0/60 GPM 600 @ 3150 psi Strin wt. PU 280 SO 150 Rot. 205 13:15 15:15 2.00 15,711 15,711 INTRM2 DRILL CIRC X Circulate and condition mud - 600 gpm / 3050 si / 65 r m t pp ( F"~:4 E -- - . Time Logs _ ~ ~ Date From To Dur th E. De th Phase Code Subcode T RUM 08/27/2006 15:15 19:15 4.00 15,711 14,380 INTRM2 DRILL WPRT X Flow check well -Wipe hole from 15711' to 14,308' @ 440 gpm / 1700 si / 60 r m -Monitor well Static 19:15 20:15 1.00 14,380 15,645 INTRM2 DRILL TRIP X RIH f/ 14,308' to 15,645' - No problems 20:15 22:45 2.50 15,645 15,711 INTRM2 DRILL CIRC X Est. circ -wash last 60' to btm, - Circ & bump mud wt. f/ 10.2 ppg to 10.5 22:45 00:00 1.25 15,711 15,711 INTRM2 DRILL CIRC X Spot hole strengthening pill &csg running pill to bit -POOH & spotting pil f/ 15„711' to 15„225' - 3.5 BPM 520 si - 08/28/2006 00:00 01:30 1.50 15,711 14,276 INTRM2 DRILL TRIP X Pump out from 15,225' to 14,276' spotting wellbore strengthening and tube pills 3.5 bpm / 520 psi -flow check well, static 01:30 04:30 3.00 14,276 12,371 INTRM2 DRILL TRIP X Pump out from 14,276' to 12,371 - 500 gpm / 2200 psi / 50 rpm @ 16K ft/Ibs - flow check well, static 04:30 12:00 7.50 12,371 3,439 INTRM2 DRILL TRIP X POOH on trip tank from 12,371' to 3,439' -wiped tight spots @ 9250', 4770' & 3,700' 12:00 12:30 0.50 3,439 3,439 INTRM2 DRILL TRIP X Flow check well @ shoe, static -pump d 'ob -blow down to drive 12:30 15:15 2.75 3,439 715 INTRM2 DRILL TRIP X POOH - LD 5" drill pipe 15:15 18:30 3.25 715 0 INTRM2 DRILL PULD X LD - HWDP - NM flex DC' Down load MWD - LD MWD -motor & bit 18:30 22:30 4.00 0 0 INTRM2 CASIN( OTHR X Pull wear bushing -Set test plug - Change top pipe rams to 7" & test to 250 & 5000 psi -Set thin wall wear bushing -Change TD saver sub & dies in TD grab - MU Frank's fill up tool - Change to long bails - PU casing elevators & spider - RU casing tongs & work latform 22:30 22:45 0.25 0 0 INTRM2 CASIN( SFTY X Held pre-job meeting with crew 22:45 00:00 1.25 0 435 INTRM2 CASIN( RNCS X Run 7" 26# L-80 MBTC casing as follows: Float shoe (Ray Oil Tools sliver bullet) 2 jts csg -Float collar(Halliburton) 2 jts. csg.(first 4 connections made up with BakerLoc - filled pipe & checked floats) 6 jts. csg to 435' 10 'ts. of 366 to run 08/29/2006 00:00 03:30 3.50 435 4,490 INTRM2 CASIN( RNCS X Run 7", 26#, L-80 casing from 435' to 4,490' . 105 'ts total 03:30 04:00 0.50 4,490 4,490 INTRM2 CASIN( CIRC X Stage pumps up to 5.0 bpm and circulate one casing volume - ICP 320 psi @ 3.5 bpm / FCP 400 psi @ 5 b m - PUW 150K SOW 125K 04:00 08:15 4.25 4,490 8,126 INTRM2 CASIN( RNCS X Run 7", 26#, L-80 casing from 4,490' to 8,126'. 190 'ts total e m_.~. _ ~.__ - _ R. _~ .._ ~ . ~..._._ ~ __~ .~... ~, ~~ _ _ .~ ..~, _ ..._ ~__ - - nm_ Time Logs _ Date From To Dur th E. De th __ Phase __ _ Code Subcode T M 08/29/2006 08:15 09:00 0.75 _ 8,126 8,126 INTRM2 CASIN( CIRC X Stage pumps up to 5.0 bpm and circulate BU -ICP 460 psi @ 3.5 bpm / FCP 560 psi @ 5 bpm -PUW 220K SOW 127K 09:00 10:30 1.50 8,126 8,640 INTRM2 CASIN( X Run 7", 26#, L-80 casing from 8,126' to 8,640'. 202 'ts total 10:30 11:30 1.00 8,640 8,640 INTRM2 RIGMN RGRP XT Change out leaking Top Drive swivel ackin assembl 11:30 15:15 3.75 8,640 11,343 INTRM2 CASIN( RNCS X Run 7", 26#, L-80 casing from 8,640' to 11,343'. 265 'ts total 15:15 16:15 1.00 11,343 11,343 INTRM2 CASIN( CIRC X Stage pumps up to 5.0 bpm and circulate BU -ICP 560 psi @ 3.6 bpm / FCP 650 psi @ 5 bpm -PUW 300K SOW 145K 16:15 17:45 1.50 11,343 14,040 INTRM2 CASIN( RNCS X Run 7", 26#, L-80 casing from 11,343' to 14,040'. 328 'ts total 17:45 21:15 3.50 14,040 14,040 INTRM2 CASIN( CIRC X Stage pumps up to 5.0 bpm and circulate BU -ICP 475 psi @ 3.5 bpm / FCP 690 psi @ 5 bpm -PUW 330K SOW 145K. 21:15 00:00 2.75 14,040 15,695 INTRM2 CASIN( RNCS X Run 7", 26#, L-80 casing from 14,040' to 15,658'. (366 jts total). Landed casin on han er 15,695'. 08/30/2006 00:00 00:30 0.50 15,696 15,696 INTRM2 CEMEI~ RURD X Lay down fill up tool -blow down top drive - ri u cement head 00:30 04:30 4.00 15,696 15,696 INTRM2 CEME~ CIRC X Stage pumps up to 7 bpm - circ and condition mud -lower mud wt. to 10.2 - FCP 810 si 04:30 07:15 2.75 15,696 15,696 INTRM2 CEMEI~ DISP X PJSM on cmt job -Cemented 7" csg as follows: Pumped 10 bbls CW100 - Tested lines to 4000 psi -pumped 30 bbls oc CW100 -Mixed & pumped 40 bbls MudPush @ 12.8 ppg - 4.4 BPM @ 470 psi -Dropped btm plug -Mixed and pumped 102 bbls of lead slurry LiteCRETE @ 11.0 ppg @ 4.6 bpm / 425 psi -Mixed & pumped 40 bbls tail slurry (Class G w/additives) - 15.8 ppg @ 4.2 BPM @ 365 psi -Dropped top plug w/ 20 bbls water f/ Dowell - switched to rig pumps & displaced cmt w/ 10.2 ppg mud @ 7 BPM for 535 bbls - 6 bpm for 35 bbls and 4 bpm last 10 bbls pumped - 580 bbls total displacement -Bumped plug w/ 1100 psi -Check floats OK CIP @ 0705 hrs.- Full returns throughout - No pipe movement 07:15 08:15 1.00 15,696 0 INTRM2 CASIN( DHEQ X RU and test casing to 3500 psi for 30 minutes -bleed off and blow down lines 08:15 09:15 1.00 0 0 INTRM2 CEMEf~ RURD X Rigged down cement head and laid down landing joint. Pulled thin wear bushin . 09:15 10:45 1.50 0 0 INTRM2 CASIN( DHEQ X Set 7" packoff and tested to 5000 psi. i . ,. ~~,'" _ . Time Logs _ _ Date From To Dur th E. De th Phase Code Subcode T M _ 08/30/2006 10:45 11:45 1.00 0 0 INTRM2 CASIN( NUND X Changed rams from 7" to VBR. 11:45 12:15 0.50 0 0 INTRM2 DRILL RURD X Rigged up bales and elevators to handle 5" Drill Pi e. 12:15 21:45 9.50 0 0 INTRM2 DRILL PULD X Laid down 104 stands of 5" Drill Pipe from derrick. 21:45 23:00 1.25 0 0 INTRM2 RIGMN RURD X Rigged down Rotary Hose from Top Drive and laid down. 23:00 00:00 1.00 0 0 INTRM2 WELCT BOPE X Set test plug and tested BOP Hydril to 250/3500 si. 08/31/2006 00:00 04:30 4.50 0 0 INTRM2 WELCT BOPE X Test rams, choke, kill, manifold and floor safety valves to 250!5000 psi Tested VBR;s with 4" and 4 1/2" pipe - perform accumulator test -lay down test plug and install wear bushing - Chuck Scheve waived witnessin tests 04:30 05:30 1.00 0 0 INTRM2 RIGMN RGRP XP Remove top section of standpipe from derrick 05:30 07:15 1.75 0 190 INTRM2 DRILL PULD MU Schumbrger 4 3/4" Power Drive assy - mu bit and function test PD. - MUPericope and MWD tools - PU nm flex collars 07:15 09:15 2.00 190 1,522 INTRM2 DRILL TRIP X RIH with hwdp - PU 36 jts of 4" drill i e to 1, 522' 09:15 09:45 0.50 1,522 1,522 INTRM2 DRILL DHEO XT Shallow test tools -determined tool initialization im ro er 09:45 12:15 2.50 1,522 1,522 INTRM2 DRILL TRIP XT POOH to 40' -reprogram Periscope - RIH to 1,522' 12:15 00:00 11.75 1,522 1,522 INTRM2 RIGMN RGRP XT PJSM -Install upper section of standpipe with new gooseneck -install new kelly hose to standpipe and top drive. New hose had wrong connections. Changed out for old hose. Attempted to test to 3500 psi. Hose connections leaked. Welding on hose connections. 09/01/2006 00:00 04:15 4.25 1,522 1,522 INTRM2 RIGMN RGRP XT Repaired Rotary Hose /standpipe - tested to 3500 si 04:15 13:45 9.50 1,522 12,386 INTRM2 DRILL TRIP X RIH from 1,522' to 12,386' picking up 4" drill i e 342 'ts 13:45 15:00 1.25 12,386 12,386 INTRM2 RIGMN SVRG X Slip and cut drilling line -service top drive and drawworks 15:00 15:30 0.50 12,386 12,576 INTRM2 DRILL TRIP X RIH from 12,386' to 12,576 -pipe flowin over 40' u 15:30 16:00 0.50 12,576 12,576 INTRM2 DRILL CIRC X Mix and pump 25 bbls of 12.5 ppg slug 16:00 17:45 1.75 12,576 15,440 INTRM2 DRILL TRIP X RIH from 12,576' to 15,440'. Tagged cement strin er. 17:45 19:15 1.50 15,440 15,607 INTRM2 CEMEI~ DRLG X Washed and reamed from 15,440' to 15,607'. FC . 19:15 22:15 3.00 15,607 15,711 INTRM2 CEMEf~ DRLG X Drilled Shoetrack from 15,607' to 15,695'. Cleaned out rathole to 15,711'. Time Logs Date From To ____ Dur th E. ne~th Phase Code. Subcode T M __ 09/01/2006 22:15 22:45 0.50 15,711 15,731 INTRM2 DRILL DDRL X Drilled with Rotary Steerable from 15,711' to 15,731'. ADT .33 hrs. WOB 5/10 RPM 60. GPM 231 @ 2340 psi. Wt up 290 Down 125 Rotating 175. Tor ue on/off. 22:45 00:00 1.25 15,731 15,731 INTRM2 DRILL CIRC X CBU @ 231 GPM 2410 psi. 09/02/2006 00:00 01:00 1.00 15,731 15,731 INTRM2 CEMEf~ FIT X RU and perform PIT to 12.5 ppg - RD/ blow down lines 01:00 01:30 0.50 15,731 15,730 INTRM2 DRILL CIRC X Displace drill string with 9.2 ppg FloPro mud 01:30 12:00 10.50 15,730 16,389 INTRM2 DRILL DDRL P Drill w/ Power Drive RS f/ 15,731' to 16,389' MD 7235' TVD ADT - 7.04 hrs ECD - 10.9 -11.1 ppg WOB 5/7 k RPM 130 GPM 245 @ 2810 psi Strin wt. PU 237 SO 132 Rot. 174 12:00 00:00 12.00 16,389 17,344 INTRM2 DRILL DDRL P Drill w/ Power Drive RS f/ 16,389' to 17,344' MD 7230' TVD ADT - 6.74 hrs ECD - 10.9 -11.1 ppg WOB 6/10 k RPM 130 GPM 245 @ 2820 psi String wt. PU 240 SO 135 Rot. 175 Tor ue on/off 17,500/15,500 ft lbs. 09/03/2006 00:00 12:00 12.00 17,344 18,200 -NTRM2 DRILL DDRL P Drill w/ Power Drive RS f/ 17,344' to 18,200' MD 7222' TVD ADT - 7.77 hrs ECD - 11.1 -11.3 ppg WOB 6/10 k RPM 130 GPM 220 @ 2330 psi String wt. PU 240 SO 125 Rot. 174 Torque on/off 17,000/15,500 ft lbs. Drilled across fractures @ 17,756' and 18052' -encountered mud loss of 70 bph initial slowing to 40-50 bph Total losses to noon 313 bbls. 12:00 00:00 12.00 18,200 19,000 INTRM2 DRILL DDRL P Drill w/ Power Drive RS f/ 18,200' to 19,000' MD 7219' TVD ADT - 7.77 hrs ECD - 11.1 -11.4 ppg WOB 6/10 k RPM 130 GPM 220 @ 2340 psi String wt. PU 240 SO 125 Rot. 175 Torque on/off 17,000/15,500 ft lbs. Mud loss of 40-70 bph Total losses last 12 hrs 465 bbls. 09/04/2006 00:00 12:00 12.00 19,000 19,380 INTRM2 DRILL DDRL P Drill w/ Power Drive RS f/ 19,000' to 19,380' MD 7217' TVD ADT - 8.98 hrs ECD - 11.4 -11.6 ppg WOB 4/14 k RPM 130 GPM 260 @ 3270 psi String wt. PU 237 SO 125 Rot. 172 Torque on/off 15,500/14,500 ft lbs. Mud loss of 40-70 bph Total losses last 12 hrs 549 bbls. ~®~ ~.a~ _ _~_.m a.~ s ~ ___ .m..a. ~ .... ~ -~._~ .eee . _a. ® .. .~~~s~_ ~; Time Logs Date From To Dur pth E. Die th Phase Code Subcode T _ M __ 09/04/2006 12:00 00:00 12.00 19,38© 19,756 INTRM2 DRILL DDRL P Drill w/ Power Drive RS f/ 19,380' to 19,756' MD 7222' TVD ADT - 10.20 hrs ECD - 11.4 -11.6 pP9 WOB 4/14 k RPM 130 GPM 252 @ 3210 psi String wt. PU 235 SO 125 Rot. 173 Torque on/off 16,500/15,500 ft lbs. Mud loss of 25-70 bph Total losses last 12 hrs 400 bbls. Accumulated losses to well 1722 bbls Time drilled from 1800 to 2400 hrs 32' @ 6 FPH Attempting to drill thru Siderite tense 09/05/2006 00:00 12:00 12.00 19,756 20,042 INTRM2 DRILL DDRL P Drill w/ Power Drive RS f/ 19,756' to 20,042' MD 7216' TVD ADT - 9.09 hrs ECD - 11.4 -11.7 ppg WOB 4/9 k RPM 130 GPM 258 @ 3380 psi String wt. PU 237 SO 120 Rot. 170 Torque on/off 17,500/16,000 ft lbs. Mud loss of 25-60 bph Total losses last 12 hrs 368 bb Time drilled from 0000 to 0200 hrs 14' @ 6 FPH Attempting to drill thru Siderite tense. 12:00 23:15 11.25 20,042 20,612 INTRM2 DRILL DDRL P Drill w/ Power Drive RS f/ 20,042' to 20,612' MD 7213' TVD ADT - 8.00 hrs ECD - 11.4 -11.8 ppg WOB 7/14 k RPM 130 GPM 252 @ 3210 psi String wt. PU 235 SO 115 Rot. 170 Torque on/off 18,500/17,000 ft lbs. Mud loss of 25-70 bph Total losses last 12 hrs 300 bbls. Accumulated losses to well 2390 bbls 23:15 00:00 0.75 20,612 20,612 INTRM2 DRILL CIRC P CBU @ 252 GPM 130 RPM. 09/06/2006 00:00 03:30 3.50 20,612 20,612 INTRM2 DRILL CIRC P CBU X 3 @ 5.8 BPM 130 RPM. 03:30 12:00 8.50 20,612 16,870 INTRM2 DRILL TRIP P Flow checked well breathing. POOH backreaming with 200 GPM. 100 RPM. from 20,612' to 16,870'. 12:00 14:00 2.00 16,870 15,695 INTRM2 DRILL TRIP P POOH backreaming with 200 GPM. 100 RPM. from 16,870' to 15,695'. 14:00 14:30 0.50 15,695 15,695 INTRM2 WELCT OWFF P Flow checked well and dropped drift. 14:30 18:00 3.50 15,695 13,528 INTRM2 DRILL TRIP P POOH with pump @ 2 BPM from 15,695' to 13,528'. 18:00 20:30 2.50 13,528 13,528 INTRM2 DRILL CIRC P Flow checked well. PJSM. Displaced well to 9.6 PPG Brine. Flow checked well. 20:30 00:00 3.50 13,528 8,287 INTRM2 DRILL TRIP P POOH on trip tank from 13,528' to 8,287'. 09/07/2006 00:00 03:00 3.00 8,287 379 INTRM2 DRILL TRIP P Continue POOH on trip tank from 8,287' to 379'. 4 3`` ;~ of t~ Time Logs _ Date From To Dur th E De th Phase Code Subcode T _ M 09/07/2006 03:00 05:30 2.50 379 0 INTRM2 DRILL PULD P Laid down BHA and cleared floor. 05:30 06:00 0.50 0 0 INTRM2 CASIN( RURD P Rigged up to run 4.5" liner. 06:00 11:30 5.50 0 5,084 INTRM2 CASIN( RNCS P PJSM and Ran 127 Jts 4.5" L-80 12.6# SLHT Liner. 11:30 20:30 9.00 5,084 20,612 INTRM2 CASIN( RUNL P Made up Liner Hanger and RIH on 4" drill pipe from 5,084' to 20,612' dropped ball. 20:30 21:15 0.75 20,612 20,602 INTRM2 CASIN( CIRC P Pumped down ball with liner on depth @ 20,602'. Set liner hanger with 3900 psi. checked liner with 50 K down weight. Bled off pressure and released liner. 21:15 22:00 0.75 20,602 15,061 INTRM2 DRILL TRIP P POOH to 15,061'. 22:00 23:00 1.00 15,061 15,061 INTRM2 DRILL CIRC P CBU with 5.5 BPM. ICP 1160 psi. FCP 1090 si. 23:00 00:00 1.00 15,061 15,061 INTRM2 RIGMN RGRP T Repair and replace Electric Brake on Draw works. Well on tri tank. 09/08/2006 00:00 12:00 12.00 15,061 15,061 INTRM2 RIGMN RGRP T Repaired Electric brake on draw works. 12:00 15:00 3.00 15,061 15,061 INTRM2 RIGMN T Repaired Electric brake on draw works. 15:00 20:00 5.00 15,061 9,533 INTRM2 DRILL TRIP P POOH on trip tank from 15,061' to 9,533'. 20:00 21:15 1.25 9,533 9,533 INTRM2 RIGMN SVRG P Slipped and cut drilling line. 21:15 23:30 2.25 9,533 0 INTRM2 DRILL TRIP P POOH on trip tank from 9,533' to 0'. 23:30 00:00 0.50 0 0 INTRM2 DRILL PULD P Laid down running tool and pulled wear rin . 09/09/2006 00:00 01:00 1.00 0 0 INTRM2 RPCOh RURD P Rigged up to run Upper Completion and PJSM. 01:00 12:00 11.00 0 12,111 INTRM2 RPCOh RCST P Ran 4.5" 12.6# L 80 IBT tubing and 'ewele to 12,111' 286'ts . 12:00 13:00 1.00 12,111 13,234 INTRM2 RPCOh RCST P Ran 4.5" 12.6# L 80 IBT tubing and 'ewele from 12,111' to 13234' 30 'ts . 13:00 14:00 1.00 13,234 13,234 INTRM2 RPCOh PULD P Picked up and tested SSSV. 14:00 17:00 3.00 13,234 15,541 INTRM2 RPCOh RCST P Ran 4.5" 12.6# L 80 IBT tubing and jewelery with dual control lines from 13,234' to 15,541' 58 'ts . 17:00 19:00 2.00 15,541 15,541 INTRM2 RPCOh HOSO P Spaced out and made up tubing han er. Landed tubin . 19:00 20:30 1.50 15,541 0 INTRM2 RPCOti DHEQ P Laid down landing jt A and installed two way check. Installed landing jt B and tested tubing hanger seal to 5,000 si. Laid down Landin 't. 20:30 00:00 3.50 0 0 INTRM2 RPCOh NUND P Nippled down BOP and worked on control line. 09/10/2006 00:00 02:00 2.00 0 0 INTRM2 RPCOti NUND P Installed Xmas tree and tested to 5000 si. 02:00 03:00 1.00 0 0 INTRM2 RPCOh NUND P Rigged up lubracator and tested. Pulled TWC. Rigged down FMC lubracator. 3 f ,,,..e~,-,.,, _~..... ~--. ~,,,,,,,,,,,,,,,,~ ...~__._d ..~.. _......._ ~ _.. Time Logs ~- Date From To Dur th E. De th Phase Code Subcode T 1~M 09/10/2006 03:00 08:00 5.00 0 0 INTRM2 RPCOti FRZP P Rigged up squeeze manifold. Dowell tested lines to 5000 psi. Pumped 240 Bbls 9.5 PPG inhibited brine followed by 285 Bbls diesel @ 3 BPM to freeze protect well. Tubing pressure after dis lacement 875 si. 08:00 09:30 1.50 0 0 INTRM2 RPCOh PACK P Dropped Ball/Rod and Pressured up on tubing to 4900 psi to set packer. Bled off tubing pressure to 3500 psi and tested tubing 30 min. Bled off tubing pressure to 2000 psi. Pumped annulus up to 3500 psi and tested for 30 min. Bled annulus to 0 psi. Bled tubing to 875 si. 09:30 11:00 1.50 0 0 INTRM2 RPCOh PULD P Rigged up lubracator and set BPV. Ri ed down FMC lubracator. 11:00 12:00 1.00 0 0 INTRM2 DRILL PULD P PJSM and rigged up to Lay down DP from derrick. La in down DP. 12:00 17:00 5.00 0 0 INTRM2 DRILL PULD P Laid down 4" DP from derrick. 17:00 17:30 0.50 0 0 INTRM2 RIGMN SVRG P Serviced rig. 17:30 23:00 5.50 0 0 INTRM2 DRILL PULD P Continue laying down 4" DP, HWDP, and jars from derrick. Total 300 jts 4" DP laid down. 23:00 00:00 1.00 0 0 INTRM2 DRILL RURD P Cleared rig flooor and cleaned pipe rack for move. . a.. ~ _ .__ _____ m®.®. __ ~ z m ..~ ~. ~ ~ e.. ......_ __ __~ _........ __ _ « ..,... ~., ___....._...._..__ ____. ~ _.._ . _. ~ ........_ _ _ _ .__._i Update on Extending the TD of CD4-318a • 1 of 2 Subject: Updateon Extending the TD of CD4-318a From: "Galiunas, Elizabeth C" <Elizabeth.GGaliunas@conocophillips.com> Date: Tue, OS Sep2006 16:11:05 -0800 To: Thomas E '~1aun~ler ~ "tom maui~dcr<<r)ac~min.statc.akus=~ CC: stew d~ivies(~uadmin.state.~ik.us Tom, ~~ ^ ~~ ~ After talking with the asset today, we are planning on ending the well at ±20,775' MD (475') from original XY. The goal is to keep the TD less than 500' from the permitted TD. If by chance the assert would like to extend the well further, we will contact you and follow up with the 401. Thanks, Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-265-6247 Cell: (907)-441-4871 -----Original Message----- From: Thomas E Maunder [mailto:tom °t:aunderzadtnin,state.ak.us) Sent: Monday, September 04, 2006 3:58 PM To: Galiunas, Elizabeth C Cc: Alvord, Chip; Johnson, Vern; sieve davies==admin.state.ak.us Subject: Re: Extending the TD of CD4-318a Liz, Some good news for a change on this well. Drilling beyond 20,800' is acceptable. I understand the uncertainty regarding how far you might drill. In order to reduce the paperwork, I suggest that you be really optimistic about a new TD. There isn't a problem with not reaching where you'd like to get. Actual BHL gets corrected when the completion report is filed. The only thought that comes to mind is will the extended well length still be in the defined pool area. That would be one to look at. I will look forward to seeing the new permit application tomorrow. Tom Maunder, PE AOGCC ----- Original Message ----- From: "Galiunas, Elizabeth C" <Eli.zabeth.C.Gali.urzas~~conocop=kill=.ps.com> Date: Monday, September 4, 2006 12:58 pm Subject: Extending the TD of CD4-318a Tom, As discussed today, drilling the horizontal is going well. The sand is 10 ft thick. The asset would like to keep drilling to see how much sandthere is. Currently we are at 19,500' and the permitted XY is 20,300'.We will reach 20,800 (500' beyond the permitted XY) tonight. The geologist do not have a specific XY for TD, the plan it to follow the same azimuth and the dip of the sand. They would like to go beyond the 500' permitted XY if the sand is still as good. Anew 401 will follow tomorrow with the new directional plan and the ~~~v~~~ ~~~ ~0 ~ Ito 10/30(2006 9:09 AM STATE OF ALASKA "~ 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: dim reG~ ~aomin.state.a~c.~~s ao~c: pr~~d~ae '3:Y~ad:nn.s~tae.uk.us brh eckenstein:~adrr:i:~.state.a>~.i~s Contractor: Doyon Rig No.: 19 DATE: 8/31/2006 Rig Rep.: Krupa/Sena Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Burley/Hill Field/Unit & Well No.: Colville Rv CD4-318a PTD # 2tK-113 Operation: Drlg: x Test: Initial: Test Pressure: Rams: 250/5000 Workover: Weekly: Annular: 250/3500 Explor.: Bi-Weekly x Valves: 250/5000 MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13-5/8 P Pipe Rams 1 3-1/2x 6 P Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1/8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P TEST DATA Test Result P_ P FLOOR SAFETY VALVES: Quantity Test R Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3150 P Pressure After Closure 1550 P 20D psi Attained 31 P Full Pressure Attained 3 min 38 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ 2050 psi Test Results Number of Failures: 0 Test Time: 5 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervises at: jirtl re~.~~adn:in.state.a>i.~~s~ Remarks: Good test. Also tested upper and lower variable pipe rams with 4-1/2" test joint. 24 HOUR NOTICE GIVEN YES X NO Waived By Chuck Scheve Date 08/29/06 Time 7:30am Witness Sena/Hill Test start Finish BOP Test (for rigs) BFL 11/09/04 Doyon19 8-31-06 CD4-318a.xls ~~~ ~ ~ ~~_. ~`~~,~~ ~ ~.~~u,.:i -~ ~:~ ~,~..~ .> ~~ s~ ~_. g ~~ ~ ~ l )3 ~ ~ ,t~ ~," y FRANK H. MURKOWSK/, GOVERNOR _,_ __~ , s' ~-~t~~ O~ ~ ~ ~nY, 333 W. 7T" AVENUE, SUITE 100 C011TSER~ATIOI~T COl-'II-'IISSIOlY ANCHORAGE, ALASKA 99507-3539 PHONE (907) 279-7433 Brian Noel FAx (so7) 27s-7sa2 Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Nanuq-Nanuq Oil Pool, CD4-318a Sundry Number: 306-267 Dear Mr. Noel: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31:05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of August, 2006 Encl. ~~°~~3 Sincerely, ~v ~II9/ STATE o ALASKA RECE(VEC A OIL AND GAS CONSERVATION COMIV~ON %~~~~~ Q~ APPLICATION FOR SUNDRY APPROVALS G 1 Y 2006 20 AAC 25.280 ~~__~._ n•...._ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ~ e Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^Anchorage Change approved program ~ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ,~/J ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 20 ZC~~- //3 !"' 8 ~~ ~~. 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 103-20519-01 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ CD4-318a 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 38077, 384209, 387209 36.5' Colville River Field / Nanu Kupark Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15242' 7255' 14836' vr! bridge plug 7242' Brige plug for whipstock 3.93' of mill and sub: Believed and whipstock at 14827' to be at TD 14836' Casing Length Size MD TVD Burst Collapse Structural Conductor 114' 16" 114 114 Surtace 3448 9.625" 3485 2375 5750 3090 Intermediate 15010 7" 15047 7252 7240 5410 Production Liner Pertoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type: Packers and SSSV MD (ft): 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development ^~ ~ Service ^ 15. Estimated Date for 8/10/2006 16. Well Status after proposed work: Commencing Operations: Oil Q Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Yes Dater 8/10/2006 WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Tom Maunder 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Liz Galiunas 265-6247 Printed Name Brian Noel for Chip Alvord 265-6120 Title Alpine Drilling Team Lead Signature Phone Date 8/10/2006 ~ 3 .~=.~ . Z~S-~~~~ ~~,aio~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ - D~ L Plug Integrity ^ BOP Te t ^ Mechanical Integrity Test ^ Location Clea rance ^ s ` r ` ( Other: An~ ~~v\~ ~!r~TS fiY ~~_rc DAM i ~ ~b ~~~ ~JG°~~~ 2 S'1i~E~~ QP~` l ' RBDIVIS BFL auc 1 ~ zoos Subsequent Form Required: ~~~ ~~ ~C-n~ ,~ APPROVED BY ~ / /f Approved by: ISSIONER THE COMMISSION Date: ~ 6 y Form 10-403 Revised 06/2006 ORIGINAL / /~ j •f`f .p~ 8~lf~f~f Submit in Duplicate • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 August 10, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 • ConocoPhillips Re: Application for change to Approved Program- Plug back abandonment and suspension operations CD4-318a (permit no. 2~5-~F96j~ 20~- ~f 3 ~ P' ~~°~ Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies fora Permit for change to Approved Programs for CD4-318a. Drilling operations on CD4-318 began on 12/4/2005 with Doyon 19 (permit no. 205-196). While drilling the intermediate section we could not get into the sand due to a layer of siderite. The decision was made to set intermediate casing at that point and go in with a clean out assembly to get into the sand and then drill the horizontal section. This did not work. We went in with an insert bit and motor and left three cones in the hole, but around 40' of sand was opened. The decision was made to complete the well temporarily and return since the ice road had opened and the rig was needed on CD3. The well was flow tested this winter. And re-permitted as CD4-318a. The rig returned July 28, 2006 to decomplete the well, attempt to mill out the cones, and drill the horizontal. Due to problems caused by the shale outside the casing shoe, the decision was made to abandon this hole section, set a bridge plug and whipstock, and sidetrack out of the casing. After milling out the window and 15' of new hole, a motor and PDC were bit run in to try and get through the shale and into the sand. The shale was causing the assembly to packoff and therefore stalling out the motor. A milling assembly was run in to try and clean up the shales and window. An additional 2' of hole was made. This run looked to have helped the situation, but upon pulling of the hole with the milling assembly it was found that the mill and the bit sub were left in the hole. After assessing options, it was concluded that the best option for getting a usable well is to cut and pull the 7" casing at 160' below the surface casing shoe. To abandon the 7" casing and side track the hole, please see attached proposed plug back and drilling program and plug back schematic for more details. The redrilled well will be kicked off right outside the surface casing shoe and will be landed 200' of the original intermediate casing shoe. The well will be completed as , originally permitted with minor changes in depths. Please find attached the information: 1. Form 10-403 APPLICATION FOR Sundry approval 2. A proposed plug back and drilling program 3. Proposed plug back schematic 4. Proposed completion diagram. 5. New proposed directional plan • If you have any questions or require further information, please contact Liz Galiunas at 265-6247 or Chip Alvord at 265-6120. Sincerely, r ~~/~D 4~ L Ga nas Drilling Engineer Attachments cc: CD4-318 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Vern Johnson ATO 1702 Chris Seaman ATO 1746 Lanston Chin Kuukpik Corporation • Alpine : CD4-318a Procedure 1. MU cement retainer and run in hole. Set cement retainer at 14760' MD. Cement from TD (14,836' MD) to the bridge plug and Set 50' cement plug above the retainer to +/-14710' MD. Use 15.8 ppg cement. Test casing to 3500 psi for 30 mins. 2. The wellbore will have 9.6 ppg brine. 3. MU second bridge plug assembly and run in hole. Set bridge plug at 3775' MD and test 3500 psi for 30 mins. 4. MU casing cutter and cut casing at 3645' MD (+/- 150' below the surface shoe). 5. Ensure the 7" casing is free and circulate the annulus with LSND mud. Pull out of the hole with the 7" casing and lay down. 6. RIH with cement stinger and tag top bridge plug. Set 17 ppg cement plug from bridge plug to 3285' (+/- 200' inside the surface casing). 7. Make up 8 3/" assembly and polish off the cement plug. Kick off and drill into the Kurpark C sand.' 8. Run and cement 7" casing per program. Carry out a leak off test down the 9 5/8" x 7" casing annulus to - confirm the fracture pressure referenced to the casing shoe. Freeze protect the annulus and casing. 9. Continue normal operations following the original permit to drill application. • Abandonment plug schematic: I-~ Updated 08/10/06 Wellhead Bridge Plug 9.8 ppg Brine in hole 16" Conductor to 114' 9-5/8" 40 ppf L-80 BTCM Surface Casing @ 3485' MD / 2375' TVD Pluq #3:490' (Too at +/- ` MD /' TVD). 17 ooa. 360 ft Cut 7" casing at 3.645' MD ~ i 130 ft 14,720' Plug #2 : +/- 50 above Bridge Plua Ca) 14710'. 15.8 ooa 50' 14,770' Plua #1 : +/- 50 above window CtD Bridge Plug ~ 14760'. 15.8 ooa Plug #1 To~of Window: 14.807' MD Cad 85° Bottom of Window 14,819' MD Bridge Plug set at 14,824' TD in Kalu~iik Shale _ .~ 14,836' MD/ 7424' TVD Predicted ToD Kuparuk Reservoir at +/-15729' MD / 7256' ND • ~ Completion Schematic 16" Insulated Conductor to -114' 4-%:" 12.6 ppf L-80 IBT Mod. Tubing 3.812" BAL-O Landing Nipple 2300' MD / 1868' TVD 9-5/8" 40 ppf L-80 BTCM Surface Casing 3485' MD / 2375' TVD ~poe r Completion: ~~Q IYL Item 1) Tubing Hanger 32' 32' 2) 4'/z",12.6#/ft, IBT-Mod Tubing 3) 4-''/z" BAL-O Landing Nipple (3.812") 2300' 1868' 4) 4-''/z" 12.6#/ft L-80 IBT Mod 5) Camco KBG-2 GLM (3.833" ID) 5829' 3400' 6) 4-''/z" 12.6#/ft L-80 IBT Mod (Jts) 7) Camco KBG-2 GLM (3.833" ID) 11180' 5700' 8) 4-''/z" 12.6#/ft L-80 IBT Mod 9) Camco KBG-2 GLM (3.833" ID) 13500' 6777' w/ DCK-2 shear out valve (pinned for 3000 psi) 10) 4-''/z" 12.6#/ft L-80 IBT Mod (2 jts) 11) Baker Premier Packer 13600' 6824' 12) 4'/~" 12.6#/ft L-80 IBT Mod (1 Jt) 13) HES No-Go XN (3.725") @ 63 deg 13650' 6847' 14) 4'/~" 12.6#/ft L-80 IBT Mod (30 Jts) 15) BOT stinger with fluted WLEG stinger 14880' 7231' Stung into tie extension 10' off bottom of at 14887' Lowe r Com lep lion: Top MD ~(Q Item 16) Baker 5" x 7" Flexlock Liner Hanger 14897' 7233' 17) 4'/z", 12.6#/ft, SLHT Tubing +/- 4 jts 18) 4-''/z" 12.6#/ft SLHT liner w/ blank across shale and slots across sand 19) Baker V Set Shoe 19768' 7235' Top of cement \ 11637' MD / 5896' TVD Top Reservoir at +/- Nanuq 12384' MD / 6230' TVD Kuparuk 14973' MD / 7251' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ +/-90° 15,047' MD, 7,252' TVD 4'/z" 12.6#/ft L-80 IBT Mod Slotted liner Pattern: 32 slots / ft. 2-'/<" x 1 /8" slots TD 6-1/8" hole 19,778' MD / 7235' TVD • • ConocoPhillips Alaska Plan: CD4-318b wp01 Sperry Drilling Services Proposal Report -Geographic 10 August, 2006 ConocoPhillips Alaska Inc. Colville River Unit Alpine CD4 CD4-318 / CD4-3~Gt, l/ _ ~ w„~'ll ~ bw~ ~~ ~- P "~ ~~ ~ ~ ,,~~s ~s ~~~ ~~~~,~ /~' . o~ Local Coordinate Origin: Centered on Well CD4-318 ~• /~ Viewing Datum: Planned Doyon 19 @ 55.10ft (Doyon 19 (36.1 + 19)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet HALLIBURTON Sperry Drilling Services Z .~ 0 u F L m ~ N c W m i ~ O G - - ~ I r O Q o ~~ ~~ i ~ i ~ m 2 O _ O I a O O 3 ~ i ~ j ~ I -- __ ~ ~ ~ - _ e r M ~ Q ~ ~ _ M ~ p p - ~ ~ m d U ~ i M ~ V = _ _ - - - -- -- ~ ~ - - -- --- -- I p O tG ~ $' er 3 ~ r ~.. ~ ~ ~ ~~~~ ~mM ~ I ~ 0 ~ 0 MM Q ~ I ~ ~ G ~ O O O~~ O I i, :.: ;;-dam a - i i r ~ ~ a` ~ I ' U v ~ ~ ~:. v N O _- o ~ o v M o 60 ~ I I i § o o 5 u E ~s~ o ~ ~ /~ i I I ', i i ~~ I li O O ~ S ~ _ ~ ~ E~~.~mm @) YES'- m ~ i I ~ ~ $yr WS~~ ° ~m$o~ ~~Om i i I ~ 5 i~E ~`~ m Vann I ~ ~ a U _ m) X Y J C N N ' i - -- - O C ~~ C ~ c7 z '° iw L CI Y ~ ~ ~ l ~ U Vf ~ Y ~a _ - ~ M Y N '. N Y a _ y ___ ~i I l) i- ~ m Y = ~._ .._ ~ a Y .. Y a ~ ~[ - O ~ ~ M A Y m ~ N N Y R A C A d ~ C ~~ r M N U m a a ~ ~ ~ 0 ! V 0 O O O I O O O 0 r M `CC t00 ti V (u!/~~ 005 ~) y~dad ~e~i~aa~, ar?~ ~. CalcWatlon McMod: Mlnlmum Curvature Error Sritem: ISCWSA k~ Project: Colville River Unit HALLIBURTON :ag'~:<e'E ~,~ SE ~I OcedC r I O apine CD4 ConocoPhillips w•mlrgMethod: &ulnBSaed Site:W ca~oaau 9 °ON°4~ e roe im ~da CD4318 Sperry Drilling Services eccM aos Alaska Wellbore: CD4318b Ground Level: 79.00 Plan: CD4318b w 01 ~Ke Penn„a<I,»y~,,,~~r,~~;,,~I:o~~>•,~~„~i,~,,,.,,,~ p ,,v 3 „ >~< ~ 318b Wp ~ p4 - - - - C D4318b wp01 Toe ~~ 1500 g 5~g" C 0 0 T ~/ + -3000 . . - . t O Z . 1g ~ ~ CDq.3 1 $Q~ + + 1 ~ -4500 N ~" "~ ~ ~. CD 4318b wp01 Heel 7" -6000 - -7500 __. -12000 -10500 -9000 -7500 -6000 -4500 -3000 -1500 0 West(-)/East(+) (1500 ftlin) • • / Philli C Sperry Drilling Services HALLIBURTON onoco ps Alaska Planning Report -Geographic Sperry f7rilling Services Database: EDM_2003.11_B48 focal Co-ordinate Reference: Well CD4-318 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 @ 55.10ft (Doyon 19 (36.1 + 19)) Project: Colville River Unit MD Reference: Planned Doyon 19 @ 55.10ft (Doyon 19 (36.1 + 19)) Site: Alpine CD4 North Reference: True Well: CD4-318 Survey Calculation Method: Minimum Curvature Wellbore: CD4-318b Design: CD4-318b wp01 Project Colville River Unit, North Slope Alaska, U nited States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Postion +N/-S +E/-W Position Uncertainty Wellbore CD4 0.00 ft Northing: 5,957,446.62 ft 0.00 ft Easting: 377,843.88 ft 0.00 ft Wellhead Elevation: ft Latitude: Longitude: Ground Level: 70°17'32.131"N 150° 59' 20.366" W 19.00 ft BGGM2005 8/10/2006 23.25 80.63 57,501 Plan Summary Measured Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/-S +E/_yy Rate Rate Rate TFO (g) (°) (°) (R) (ff) (R) (°I100ft) (°/100ft) (°/100ft) (°) 3,580.00 64.69 231.26 2,415.92 -1,219.71 -1,753.86 0.00 0.00 0.00 0.00 3,730.00 64.84 224.63 2,479.92 -1,310.53 -1,854.53 4.00 0.10 -4.42 -90.00 4,130.00 64.84 226.87 2,649.99 -1,563.14 -2,113.85 0.51 0.00 0.56 90.54 4,284.96 65.00 232.00 2,715.71 -1,654.37 -2,220.42 3.00 0.10 3.31 89.12 12,334.96 65.00 232.00 6,117.79 -6,146.10 -7,969.57 0.00 0.00 0.00 0.00 12,636.99 65.00 242.00 6,245.70 -6,294.93 -8,198.75 3.00 0.00 3.31 92.12 14,072.10 67.57 301.19 6,869.30 -6,253.69 -9,432.42 3.75 0.18 4.12 100.40 14,233.32 67.57 301.19 6,930.81 -6,176.53 -9,559.90 0.00 0.00 0.00 0.00 15,526.86 85.00 348.08 7,253.49 -5,176.04 -10,245.88 3.75 1.35 3.63 76.16 15,556.86 85.00 348.08 7,256.10 -5,146.80 -10,252.05 0.00 0.00 0.00 0.00 15,689.36 90.30 348.08 7,261.53 -5,017.31 -10,279.39 4.00 4.00 0.00 -0.05 20,057.12 90.39 348.08 7,235.10 -743.88 -11,181.85 0.00 0.00 0.00 0.00 8/10/2006 4:24:54PM Page 2 of 8 COMPASS 2003.11 Build 50 • • `'~'' Philli C Sperry Drilling Services HALLIBURTON onoc o ps Alaska Planning Report-Geographic Sperry Drilling Services Database: EDM_2003.11_B48 Local Co-ordinate Reference: Well CD4-318 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 @ 55.10ft (Doyon 19 (36.1 + 19)) Project: Colville River Unit MD Reference: Planned Doyon 19 @ 55.10ft (Doyon 19 (36.1 + 19)) Site: Alpine CD4 North Reference: True Well: CD4-318 Survey Calculation Method: Minimum Curvature Wellbore: CD4-318b Design: CD4-318b wp01 Planned Survey CD4-318b w p01 Map Map MD Inclination Azimuth TVD SSTVD +Nf-S +E/_yy Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 3,485.20 64.57 231.30 2,375.32 2,320.22 -1,166.12 -1,687.02 5,956,308.16 376,138.28 0.00 1,672.79 9 5/8" 3,580.00 64.69 231.26 2,415.92 2,360.82 -1,219.71 -1,753.86 5,956,255.67 376,070.58 0.13 1,746.00 3,594.59 64.70 230.62 2,422.16 2,367.06 -1,228.02 -1,764.10 5,956,247.53 376,060.21 4.00 1,757.32 C-30 3,600.00 64.70 230.38 2,424.47 2,369.37 -1,231.13 -1,767.87 5,956,244.48 376,056.38 3.99 1,761.53 3,700.00 64.79 225.96 2,467.16 2,412.06 -1,291.43 -1,835.23 5,956,185.29 375,988.06 4.00 1,841.23 3,730.00 64.84 224.63 2,479.92 2,424.82 -1,310.53 -1,854.53 5,956,166.51 375,968.46 4.00 1,865.78 3,800.00 64.84 225.02 2,509.68 2,454.58 -1,355.47 -1,899.19 5,956,122.31 375,923.07 0.51 1,923.28 3,900.00 64.84 225.58 2,552.20 2,497.10 -1,419.13 -1,963.53 5,956,059.70 375,857.71 0.51 2,005.11 4,000.00 64.84 226.14 2,594.72 2,539.62 -1,482.16 -2,028.49 5,955,997.74 375,791.75 0.51 2,086.56 4,100.00 64.84 226.70 2,637.24 2,582.14 -1,544.55 -2,094.06 5,955,936.43 375,725.18 0.51 2,167.61 4,130.00 64.84 226.87 2,649.99 2,594.89 -1,563.14 -2,113.85 5,955,918.16 375,705.09 0.51 2,191.85 4,200.00 64.89 229.19 2,679.73 2,624.63 -1,605.52 -2,160.96 5,955,876.56 375,657.30 3.00 2,247.78 4,284.96 65.00 232.00 2,715.71 2,660.61 -1,654.37 -2,220.42 5,955,828.69 375,597.06 3.00 2,314.03 4,300.00 65.00 232.00 2,722.07 2,666.97 -1,662.76 -2,231.16 5,955,820.47 375,586.18 0.00 2,325.59 4,400.00 65.00 232.00 2,764.33 2,709.23 -1,718.56 -2,302.58 5,955,765.84 375,513.87 0.00 2,402.45 4,472.56 65.00 232.00 2,795.00 2,739.90 -1,759.05 -2,354.40 5,955,726.21 375,461.40 0.00 2,458.22 C-20 4,500.00 65.00 232.00 2,806.59 2,751.49 -1,774.36 -2,374.00 5,955,711.22 375,441.56 0.00 2,479.30 4,600.00 65.00 232.00 2,848.86 2,793.76 -1,830.15 -2,445.41 5,955,656.59 375,369.25 0.00 2,556.16 4,700.00 65.00 232.00 2,891.12 2,836.02 -1,885.95 -2,516.83 5,955,601.97 375,296.94 0.00 2,633.02 4,800.00 65.00 232.00 2,933.38 2,878.28 -1,941.75 -2,588.25 5,955,547.34 375,224.64 0.00 2,709.88 4,900.00 65.00 232.00 2,975.64 2,920.54 -1,997.55 -2,659.67 5,955,492.72 375,152.33 0.00 2,786.74 5,000.00 65.00 232.00 3,017.90 2,962.80 -2,053.35 -2,731.09 5,955,438.09 375,080.02 0.00 2,863.60 5,100.00 65.00 232.00 3,060.17 3,005.07 -2,109.14 -2,802.51 5,955,383.47 375,007.71 0.00 2,940.46 5,200.00 65.00 232.00 3,102.43 3,047.33 -2,164.94 -2,873.92 5,955,328.84 374,935.40 0.00 3,017.32 5,300.00 65.00 232.00 3,144.69 3,089.59 -2,220.74 -2,945.34 5,955,274.22 374,863.09 0.00 3,094.18 5,400.00 65.00 232.00 3,186.95 3,131.85 -2,276.54 -3,016.76 5,955,219.59 374,790.78 0.00 3,171.04 5,500.00 65.00 232.00 3,229.21 3,174.11 -2,332.34 -3,088.18 5,955,164.96 374,718.47 0.00 3,247.90 5,600.00 65.00 232.00 3,271.47 3,216.37 -2,388.13 -3,159.60 5,955,110.34 374,646.16 0.00 3,324.76 5,700.00 65.00 232.00 3,313.74 3,258.64 -2,443.93 -3,231.01 5,955,055.71 374,573.85 0.00 3,401.62 5,800.00 65.00 232.00 3,356.00 3,300.90 -2,499.73 -3,302.43 5,955,001.09 374,501.54 0.00 3,478.47 5,900.00 65.00 232.00 3,398.26 3,343.16 -2,555.53 -3,373.85 5,954,946.46 374,429.23 0.00 3,555.33 6,000.00 65.00 232.00 3,440.52 3,385.42 -2,611.32 -3,445.27 5,954,891.84 374,356.92 0.00 3,632.19 6,100.00 65.00 232.00 3,482.78 3,427.68 -2,667.12 -3,516.69 5,954,837.21 374,284.61 0.00 3,709.05 6,200.00 65.00 232.00 3,525.05 3,469.95 -2,722.92 -3,588.10 5,954,782.59 374,212.31 0.00 3,785.91 6,300.00 65.00 232.00 3,567.31 3,512.21 -2,778.72 -3,659.52 5,954,727.96 374,140.00 0.00 3,862.77 6,400.00 65.00 232.00 3,609.57 3,554.47 -2,834.52 -3,730.94 5,954,673.34 374,067.69 0.00 3,939.63 6,500.00 65.00 232.00 3,651.83 3,596.73 -2,890.31 -3,802.36 5,954,618.71 373,995.38 0.00 4,016.49 6,600.00 65.00 232.00 3,694.09 3,638.99 -2,946.11 -3,873.78 5,954,564.08 373,923.07 0.00 4,093.35 6,700.00 65.00 232.00 3,736.35 3,681.25 -3,001.91 -3,945.19 5,954,509.46 373,850.76 0.00 4,170.21 6,800.00 65.00 232.00 3,778.62 3,723.52 -3,057.71 -4,016.61 5,954,454.83 373,778.45 0.00 4,247.07 6,900.00 65.00 232.00 3,820.88 3,765.78 -3,113.51 -4,088.03 5,954,400.21 373,706.14 0.00 4,323.93 7,000.00 65.00 232.00 3,863.14 3,808.04 -3,169.30 -4,159.45 5,954,345.58 373,633.83 0.00 4,400.79 8/10/2006 4:24:54PM Page 3 of 8 COMPASS 2003.11 Build 50 ~ C Philli Sperry Drilling Services HALLIBURTON onoc o ps Alaska Planning Report-Geographic Sperry Drilling Services Database: EDM_2003.11_848 Local Co-ordinate Reference: Well CD4-318 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 @ 55.10ft (Doyon 19 (36.1 + 19)) Project: Colville River Unit MD Reference: Planned Doyon 19 @ 55.10ft (Doyon 19 (36.1 + 19)) Site: Alpine CD4 North Reference: True Well: CD4-318 Survey Calculation Method: Minimum Curvature Wellbore: CD4318b Design: CD4-318b wp01 Planned Survey CD4-318b wp01 Map Map MD Inclination Azimuth ND SSTVD +N/S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (tt) {R) (ft) (it) (ff) (~) (°/100ft) (ft) 7,006.53 65.00 232.00 3,865.90 3,810.80 -3,172.95 -4,164.11 5,954,342.02 373,629.11 0.00 4,405.80 K-3 7,100.00 65.00 232.00 3,905.40 3,850.30 -3,225.10 -4,230.87 5,954,290.96 373,561.52 0.00 4,477.65 7,200.00 65.00 232.00 3,947.66 3,892.56 -3,280.90 -4,302.28 5,954,236.33 373,489.21 0.00 4,554.50 7,300.00 65.00 232.00 3,989.93 3,934.83 -3,336.70 -4,373.70 5,954,181.71 373,416.90 0.00 4,631.36 7,400.00 65.00 232.00 4,032.19 3,977.09 -3,392.50 -4,445.12 5,954,127.08 373,344.59 0.00 4,708.22 7,500.00 65.00 232.00 4,074.45 4,019.35 -3,448.29 -4,516.54 5,954,072.46 373,272.28 0.00 4,785.08 7,525.20 65.00 232.00 4,085.10 4,030.00 -3,462.35 -4,534.54 5,954,058.69 373,254.06 0.00 4,804.45 Base K3 7,600.00 65.00 232.00 4,116.71 4,061.61 -3,504.09 -4,587.96 5,954,017.83 373,199.97 0.00 4,861.94 7,638.16 65.00 232.00 4,132.84 4,077.74 -3,525.39 -4,615.21 5,953,996.98 373,172.38 0.00 4,891.27 K-2 7,700.00 65.00 232.00 4,158.97 4,103.87 -3,559.89 -4,659.37 5,953,963.20 373,127.67 0.00 4,938.80 7,800.00 65.00 232.00 4,201.23 4,146.13 -3,615.69 -4,730.79 5,953,908.58 373,055.36 0.00 5,015.66 7,851.74 65.00 232.00 4,223.10 4,168.00 -3,644.55 -4,767.74 5,953,880.32 373,017.95 0.00 5,055.42 Base K-2 7,900.00 65.00 232.00 4,243.50 4,188.40 -3,671.48 -4,802.21 5,953,853.95 372,983.05 0.00 5,092.52 8,000.00 65.00 232.00 4,285.76 4,230.66 -3,727.28 -4,873.63 5,953,799.33 372,910.74 0.00 5,169.38 8,100.00 65.00 232.00 4,328.02 4,272.92 -3,783.08 -4,945.05 5,953,744.70 372,838.43 0.00 5,246.24 8,200.00 65.00 232.00 4,370.28 4,315.18 -3,838.88 -5,016.46 5,953,690.08 372,766.12 0.00 5,323.10 8,300.00 65.00 232.00 4,412.54 4,357.44 -3,894.68 -5,087.88 5,953,635.45 372,693.81 0.00 5,399.96 8,400.00 65.00 232.00 4,454.81 4,399.71 -3,950.47 -5,159.30 5,953,580.83 372,621.50 0.00 5,476.82 8,500.00 65.00 232.00 4,497.07 4,441.97 -4,006.27 -5,230.72 5,953,526.20 372,549.19 0.00 5,553.67 8,600.00 65.00 232.00 4,539.33 4,484.23 -4,062.07 -5,302.14 5,953,471.58 372,476.88 0.00 5,630.53 8,700.00 65.00 232.00 4,581.59 4,526.49 -4,117.87 -5,373.55 5,953,416.95 372,404.57 0.00 5,707.39 8,800.00 65.00 232.00 4,623.85 4,568.75 -4,173.67 -5,444.97 5,953,362.32 372,332.26 0.00 5,784.25 8,900.00 65.00 232.00 4,666.12 4,611.02 -4,229.46 -5,516.39 5,953,307.70 372,259.95 0.00 5,861.11 9,000.00 65.00 232.00 4,708.38 4,653.28 -4,285.26 -5,587.81 5,953,253.07 372,187.64 0.00 5,937.97 9,100.00 65.00 232.00 4,750.64 4,695.54 -4,341.06 -5,659.23 5,953,198.45 372,115.34 0.00 6,014.83 9,200.00 65.00 232.00 4,792.90 4,737.80 -4,396.86 -5,730.64 5,953,143.82 372,043.03 0.00 6,091.69 9,300.00 65.00 232.00 4,835.16 4,780.06 -4,452.65 -5,802.06 5,953,089.20 371,970.72 0.00 6,168.55 9,400.00 65.00 232.00 4,877.42 4,822.32 -4,508.45 -5,873.48 5,953,034.57 371,898.41 0.00 6,245.41 9,500.00 65.00 232.00 4,919.69 4,864.59 -4,564.25 -5,944.90 5,952,979.95 371,826.10 0.00 6,322.27 9,600.00 65.00 232.00 4,961.95 4,906.85 -4,620.05 -6,016.32 5,952,925.32 371,753.79 0.00 6,399.13 9,700.00 65.00 232.00 5,004.21 4,949.11 -4,675.85 -6,087.73 5,952,870.70 371,681.48 0.00 6,475.99 9,800.00 65.00 232.00 5,046.47 4,991.37 -4,731.64 -6,159.15 5,952,816.07 371,609.17 0.00 6,552.85 9,900.00 65.00 232.00 5,088.73 5,033.63 -4,787.44 -6,230.57 5,952,761.44 371,536.86 0.00 6,629.70 10,000.00 65.00 232.00 5,131.00 5,075.90 -4,843.24 -6,301.99 5,952,706.82 371,464.55 0.00 6,706.56 10,100.00 65.00 232.00 5,173.26 5,118.16 -4,899.04 -6,373.41 5,952,652.19 371,392.24 0.00 6,783.42 10,200.00 65.00 232.00 5,215.52 5,160.42 -4,954.84 -6,444.82 5,952,597.57 371,319.93 0.00 6,860.28 10,300.00 65.00 232.00 5,257.78 5,202.68 -5,010.63 -6,516.24 5,952,542.94 371,247.62 0.00 6,937.14 10,400.00 65.00 232.00 5,300.04 5,244.94 -5,066.43 -6,587.66 5,952,488.32 371,175.31 0.00 7,014.00 10,500.00 65.00 232.00 5,342.30 5,287.20 -5,122.23 -6,659.08 5,952,433.69 371,103.01 0.00 7,090.86 10,600.00 65.00 232.00 5,384.57 5,329.47 -5,178.03 -6,730.50 5,952,379.07 371,030.70 0.00 7,167.72 10,700.00 65.00 232.00 5,426.83 5,371.73 -5,233.83 -6,801.91 5,952,324.44 370,958.39 0.00 7,244.58 10,800.00 65.00 232.00 5,469.09 5,413.99 -5,289.62 -6,873.33 5,952,269.82 370,886.08 0.00 7,321.44 8/10/2006 4:24:54PM Page 4 of 8 COMPASS 2003.11 Build 50 • i °~ Sperry Drilling Services HALLIBURTON ConocoPhillips Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM_2003.11_648 Local Coordinate Reference: Well CD4-318 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 @ 55.10ft (Doyon 19 (36.1 + 19)) Project: Colville River Unit MD Reference: Planned Doyon 19 @ 55.10ft (Doyon 19 (36.1 + 19)) Site: Alpine CD4 North Reference: True Well: CD4318 Survey Calculation Method: Minimum Curvature Wellbore: CD4-318b Design: CD4-318b wp01 Planned Surve y CD4-318b w p01 Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (R) l°) (°) (ft) (ft) (R) (ff) (ff) (ft) (°/100ft) (ft) 10,900.00 65.00 232.00 5,511.35 5,456.25 -5,345.42 -6,944.75 5,952,215.19 370,813.77 0.00 7,398.30 11,000.00 65.00 232.00 5,553.61 5,498.51 -5,401.22 -7,016.17 5,952,160.57 370,741.46 0.00 7,475.16 11,100.00 65.00 232.00 5,595.88 5,540.78 -5,457.02 -7,087.59 5,952,105.94 370,669.15 0.00 7,552.02 11,200.00 65.00 232.00 5,638.14 5,583.04 -5,512.81 -7,159.00 5,952,051.31 370,596.84 0.00 7,628.87 11,300.00 65.00 232.00 5,680.40 5,625.30 -5,568.61 -7,230.42 5,951,996.69 370,524.53 0.00 7,705.73 11,400.00 65.00 232.00 5,722.66 5,667.56 -5,624.41 -7,301.84 5,951,942.06 370,452.22 0.00 7,782.59 11,500.00 65.00 232.00 5,764.92 5,709.82 -5,680.21 -7,373.26 5,951,887.44 370,379.91 0.00 7,859.45 11,600.00 65.00 232.00 5,807.18 5,752.08 -5,736.01 -7,444.68 5,951,832.81 370,307.60 0.00 7,936.31 11,602.36 65.00 232.00 5,808.18 5,753.08 -5,737.32 -7,446.36 5,951,831.53 370,305.90 0.00 7,938.12 Albian 97 11,700.00 65.00 232.00 5,849.45 5,794.35 -5,791.80 -7,516.09 5,951,778.19 370,235.29 0.00 8,013.17 11,800.00 65.00 232.00 5,891.71 5,836.61 -5,847.60 -7,587.51 5,951,723.56 370,162.98 0.00 8,090.03 11,900.00 65.00 232.00 5,933.97 5,878.87 -5,903.40 -7,658.93 5,951,668.94 370,090.68 0.00 8,166.89 12,000.00 65.00 232.00 5,976.23 5,921.13 -5,959.20 -7,730.35 5,951,614.31 370,018.37 0.00 8,243.75 12,100.00 65.00 232.00 6,018.49 5,963.39 -6,015.00 -7,801.77 5,951,559.69 369,946.06 0.00 8,320.61 12,200.00 65.00 232.00 6,060.76 6,005.66 -6,070.79 -7,873.19 5,951,505.06 369,873.75 0.00 8,397.47 12,300.00 65.00 232.00 6,103.02 6,047.92 -6,126.59 -7,944.60 5,951,450.43 369,801.44 0.00 8,474.33 12,334.96 65.00 232.00 6,117.79 6,062.69 -6,146.10 -7,969.57 5,951,431.34 369,776.16 0.00 8,501.20 12,400.00 64.94 234.15 6,145.31 6,090.21 -6,181.50 -8,016.68 5,951,396.71 369,728.48 3.00 8,550.58 12,500.00 64.92 237.46 6,187.69 6,132.59 -6,232.39 -8,091.59 5,951,347.04 369,652.76 3.00 8,624.02 12,600.00 64.96 240.77 6,230.06 6,174.96 -6,278.88 -8,169.32 5,951,301.83 369,574.29 3.00 8,694.28 12,601.19 64.97 240.82 6,230.56 6,175.46 -6,279.40 -8,170.26 5,951,301.33 369,573.35 3.13 8,695.10 Albian 96 12,636.99 65.00 242.00 6,245.70 6,190.60 -6,294.93 -8,198.75 5,951,286.26 369,544.61 3.00 8,719.43 12,700.00 64.60 244.57 6,272.54 6,217.44 -6,320.55 -8,249.67 5,951,261.47 369,493.29 3.75 8,760.93 12,800.00 64.05 248.69 6,315.88 6,260.78 -6,356.30 -8,332.37 5,951,227.08 369,410.02 3.75 8,822.80 12,900.00 63.62 252.84 6,360.00 6,304.90 -6,385.86 -8,417.08 5,951,198.90 369,324.85 3.75 8,879.56 13,000.00 63.30 257.02 6,404.70 6,349.60 -6,409.12 -8,503.44 5,951,177.04 369,238.13 3.75 8,930.95 13,100.00 63.12 261.21 6,449.79 6,394.69 -6,425.98 -8,591.07 5,951,161.62 369,150.25 3.75 8,976.76 13,200.00 63.05 265.42 6,495.08 6,439.98 -6,436.35 -8,679.60 5,951,152.68 369,061.57 3.75 9,016.79 13,300.00 63.11 269.62 6,540.36 6,485.26 -6,440.21 -8,768.65 5,951,150.28 368,972.47 3.75 9,050.87 13,400.00 63.30 273.82 6,585.46 6,530.36 -6,437.52 -8,857.85 5,951,154.41 368,883.34 3.75 9,078.86 13,500.00 63.60 278.00 6,630.17 6,575.07 -6,428.31 -8,946.80 5,951,165.06 368,794.56 3.75 9,100.62 13,600.00 64.03 282.15 6,674.31 6,619.21 -6,412.61 -9,035.13 5,951,182.19 368,706.50 3.75 9,116.08 13,700.00 64.58 286.26 6,717.68 6,662.58 -6,390.50 -9,122.45 5,951,205.72 368,619.55 3.75 9,125.17 13,800.00 65.24 290.34 6,760.11 6,705.01 -6,362.05 -9,208.41 5,951,235.56 368,534.08 3.75 9,127.83 13,900.00 66.01 294.37 6,801.40 6,746.30 -6,327.41 -9,292.62 5,951,271.57 368,450.45 3.75 9,124.08 14,000.00 66.88 298.35 6,841.38 6,786.28 -6,286.70 -9,374.72 5,951,313.59 368,369.03 3.75 9,113.91 14,072.10 67.57 301.19 6,869.30 6,814.20 -6,253.69 -9,432.42 5,951,347.53 368,311.88 3.75 9,102.63 14,100.00 67.57 301.19 6,879.94 6,824.84 -6,240.34 -9,454.48 5,951,361.24 368,290.04 0.00 9,097.62 14,200.00 67.57 301.19 6,918.10 6,863.00 -6,192.47 -9,533.55 5,951,410.38 368,211.76 0.00 9,079.69 14,233.32 67.57 301.19 6,930.81 6,875.71 -6,176.53 -9,559.90 5,951,426.76 368,185.68 0.00 9,073.71 14,300.00 68.19 303.80 6,955.93 6,900.83 -6,143.34 -9,611.99 5,951,460.78 368,134.14 3.75 9,060.35 14,397.89 69.17 307.60 6,991.53 6,936.43 -6,090.13 -9,686.02 5,951,515.18 368,060.99 3.75 9,035.66 Top HR2 14,400.00 69.19 307.68 6,992.28 6,937.18 -6,088.93 -9,687.58 5,951,516.41 368,059.45 3.65 9,035.07 14,500.00 70.28 311.50 7,026.92 6,971.82 -6,029.14 -9,759.84 5,951,577.36 367,988.17 3.75 9,003.60 8/10/2006 4:24:54PM Page 5 of 8 COMPASS 2003.11 Build 50 • 1r' Sperry Drilling Services ConocoPhillips Planning Report -Geographic Alaska r1 HALLIBURTON Sperry Drilling Services Database: EDM_2003.11_648 Local Co-ordinate Reference: Well CD4-318 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 @ 55.10ft (Doyon 19 (36.1 + 19)) Project: Colville River Unit MD Reference: Planned Doyon 19 @ 55.10ft (Doyon 19 (36.1 + 19)) Site: Alpine CD4 North Reference: True Well: CD4-318 Survey Calculation Method: Minimum Curvature Wellbore: CD4-318b Design: CD4316b wp01 Planned Survey CD4318b wp01 Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (~) (ft) (ft) (°/100ft) (ff) 14,600.00 71.45 315.28 7,059.71 7,004.61 -5,964.25 -9,828.47 5,951,643.36 367,920.61 3.75 8,966.09 14,700.00 72.70 318.99 7,090.49 7,035.39 -5,894.51 -9,893.18 5,951,714.12 367,857.06 3.75 8,922.70 14,800.00 74.01 322.66 7,119.15 7,064.05 -5,820.25 -9,953.67 5,951,789.36 367,797.78 3.75 8,873.60 14,821.72 74.30 323.45 7,125.08 7,069.98 -5,803.54 -9,966.23 5,951,806.26 367,785.49 3.76 8,862.20 Base Hrz 14,900.00 75.38 326.28 7,145.55 7,090.45 -5,741.76 -10,009.70 5,951,868.74 367,743.04 3.75 8,819.01 15,000.00 76.81 329.85 7,169.59 7,114.49 -5,659.39 -10,061.03 5,951,951.92 367,693.06 3.75 8,759.16 15,030.50 77.26 330.93 7,176.43 7,121.33 -5,633.55 -10,075.71 5,951,977.99 367,678.80 3.76 8,739.90 K-1 Marker 15,100.00 78.29 333.38 7,191.15 7,136.05 -5,573.50 -10,107.43 5,952,038.55 367,648.07 3.75 8,694.32 15,200.00 79.81 336.87 7,210.16 7,155.06 -5,484.44 -10,148.70 5,952,128.26 367,608.24 3.75 8,624.75 15,242.70 80.47 338.35 7,217.47 7,162.37 -5,445.54 -10,164.72 5,952,167.41 367,592.86 3.76 8,593.68 Kuparuk D 15,300.00 81.36 340.33 7,226.52 7,171.42 -5,392.60 -10,184.68 5,952,220.67 367,573.77 3.75 8,550.75 15,400.00 82.95 343.76 7,240.17 7,185.07 -5,298.37 -10,215.21 5,952,315.37 367,544.78 3.75 8,472.65 15,494.33 84.47 346.98 7,250.50 7,195.40 -5,207.67 -10,238.88 5,952,406.44 367,522.59 3.75 8,395.51 Kuparuk C 15,500.00 84.56 347.17 7,251.04 7,195.94 -5,202.16 -10,240.14 5,952,411.96 367,521.41 3.71 8,390.77 15,526.86 85.00 348.08 7,253.49 7,198.39 -5,176.04 -10,245.88 5,952,438.17 367,516.10 3.76 8,368.18 15,556.86 85.00 348.08 7,256.10 7,201.00 -5,146.80 -10,252.05 5,952,467.51 367,510.41 0.00 8,342.82 CD4-318b wp01 Heel -C D4-318b CP1 15,600.00 86.72 348.08 7,259.21 7,204.11 -5,104.70 -10,260.94 5,952,509.75 367,502.21 3.99 8,306.29 15,689.36 90.30 348.08 7,261.53 7,206.43 -5,017.31 -10,279.39 5,952,597.41 367,485.18 4.00 8,230.49 7" -CD4-318b wp01 Toe 15,700.00 90.30 348.08 7,261.48 7,206.38 -5,006.90 -10,281.59 5,952,607.86 367,483.15 0.00 8,221.46 15,800.00 90.30 348.08 7,260.95 7,205.85 -4,909.06 -10,302.25 5,952,706.01 367,464.08 0.00 8,136.58 15,900.00 90.30 348.08 7,260.42 7,205.32 -4,811.22 -10,322.91 5,952,804.17 367,445.01 0.00 8,051.71 16,000.00 90.31 348.08 7,259.89 7,204.79 -4,713.38 -10,343.57 5,952,902.32 367,425.95 0.00 7,966.84 16,100.00 90.31 348.08 7,259.35 7,204.25 -4,615.54 -10,364.24 5,953,000.48 367,406.88 0.00 7,881.96 16,200.00 90.31 348.08 7,258.81 7,203.71 -4,517.70 -10,384.90 5,953,098.64 367,387.81 0.00 7,797.09 16,300.00 90.31 348.08 7,258.26 7,203.16 -4,419.85 -10,405.56 5,953,196.79 367,368.74 0.00 7,712.22 16,400.00 90.32 348.08 7,257.72 7,202.62 -4,322.01 -10,426.22 5,953,294.95 367,349.67 0.00 7,627.34 16,500.00 90.32 348.08 7,257.16 7,202.06 -4,224.17 -10,446.88 5,953,393.10 367,330.61 0.00 7,542.47 16,600.00 90.32 348.08 7,256.61 7,201.51 -4,126.33 -10,467.55 5,953,491.26 367,311.54 0.00 7,457.60 16,700.00 90.32 348.08 7,256.05 7,200.95 -4,028.49 -10,488.21 5,953,589.41 367,292.47 0.00 7,372.72 16,800.00 90.32 348.08 7,255.49 7,200.39 -3,930.65 -10,508.87 5,953,687.57 367,273.40 0.00 7,287.85 16,900.00 90.33 348.08 7,254.92 7,199.82 -3,832.81 -10,529.53 5,953,785.72 367,254.34 0.00 7,202.98 17,000.00 90.33 348.08 7,254.35 7,199.25 -3,734.97 -10,550.19 5,953,883.88 367,235.27 0.00 7,118.10 17,100.00 90.33 348.08 7,253.77 7,198.67 -3,637.13 -10,570.86 5,953,982.03 367,216.20 0.00 7,033.23 17,200.00 90.33 348.08 7,253.20 7,198.10 -3,539.29 -10,591.52 5,954,080.19 367,197.13 0.00 6,948.36 17,300.00 90.33 348.08 7,252.61 7,197.51 -3,441.45 -10,612.18 5,954,178.34 367,178.07 0.00 6,863.48 17,400.00 90.34 348.08 7,252.03 7,196.93 -3,343.61 -10,632.84 5,954,276.50 367,159.00 0.00 6,778.61 17,500.00 90.34 348.08 7,251.44 7,196.34 -3,245.77 -10,653.50 5,954,374.65 367,139.93 0.00 6,693.74 17,600.00 90.34 348.08 7,250.85 7,195.75 -3,147.93 -10,674.16 5,954,472.81 367,120.86 0.00 6,608.86 17,700.00 90.34 348.08 7,250.25 7,195.15 -3,050.09 -10,694.83 5,954,570.96 367,101.79 0.00 6,523.99 8/10/2006 4:24:54PM Page 6 of 8 COMPASS 2003.11 Build 50 ConocoPhillips Alaska Sperry Drilling Services Planning Report -Geographic • HALLIBURTON Sperry Drilling Services Database: EDM _2003.11_B48 Local Coord inate Reference: Well CD4-318 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 @ 55.10ft (Doyon 19 (36.1 + 19)) Project: Colville River Unit MD Reference: Planned Doyon 19 @ 55.10ft (Doyon 19 (36.1 + 19)) Site: Alpine CD4 North Reference: True Well: CD4-318 Survey Calculation Method: Minimum Curvature Wellbore: CD4318b Design: CD4-318b wp01 Planned Surve y CD4-318b w p01 Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (tt) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 17,800.00 90.35 348.08 7,249.65 7,194.55 -2,952.25 -10,715.49 5,954,669.12 367,082.73 0.00 6,439.12 17,900.00 90.35 348.08 7,249.04 7,193.94 -2,854.41 -10,736.15 5,954,767.27 367,063.66 0.00 6,354.25 18,000.00 90.35 348.08 7,248.44 7,193.34 -2,756.57 -10,756.81 5,954,865.43 367,044.59 0.00 6,269.37 18,100.00 90.35 348.08 7,247.82 7,192.72 -2,658.73 -10,777.47 5,954,963.58 367,025.52 0.00 6,184.50 18,200.00 90.35 348.08 7,247.21 7,192.11 -2,560.89 -10,798.14 5,955,061.74 367,006.46 0.00 6,099.63 18,300.00 90.36 348.08 7,246.59 7,191.49 -2,463.05 -10,818.80 5,955,159.89 366,987.39 0.00 6,014.75 18,400.00 90.36 348.08 7,245.97 7,190.87 -2,365.21 -10,839.46 5,955,258.05 366,968.32 0.00 5,929.88 18,500.00 90.36 348.08 7,245.34 7,190.24 -2,267.37 -10,860.12 5,955,356.20 366,949.25 0.00 5,845.01 18,600.00 90.36 348.08 7,244.71 7,189.61 -2,169.53 -10,880.78 5,955,454.36 366,930.19 0.00 5,760.13 18,700.00 90.36 348.08 7,244.08 7,188.98 -2,071.69 -10,901.44 5,955,552.51 366,911.12 0.00 5,675.26 18,800.00 90.37 348.08 7,243.44 7,188.34 -1,973.85 -10,922.11 5,955,650.67 366,892.05 0.00 5,590.39 18,900.00 90.37 348.08 7,242.80 7,187.70 -1,876.01 -10,942.77 5,955,748.82 366,872.98 0.00 5,505.52 19,000.00 90.37 348.08 7,242.15 7,187.05 -1,778.17 -10,963.43 5,955,846.98 366,853.92 0.00 5,420.64 19,100.00 90.37 348.08 7,241.50 7,186.40 -1,680.33 -10,984.09 5,955,945.13 366,834.85 0.00 5,335.77 19,200.00 90.38 348.08 7,240.85 7,185.75 -1,582.49 -11,004.75 5,956,043.29 366,815.78 0.00 5,250.90 19,300.00 90.38 348.08 7,240.19 7,185.09 -1,484.65 -11,025.42 5,956,141.44 366,796.71 0.00 5,166.02 19,400.00 90.38 348.08 7,239.53 7,184.43 -1,386.81 -11,046.08 5,956,239.59 366,777.65 0.00 5,081.15 19,500.00 90.38 348.08 7,238.87 7,183.77 -1,288.97 -11,066.74 5,956,337.75 366,758.58 0.00 4,996.28 19,600.00 90.38 348.08 7,238.20 7,183.10 -1,191.13 -11,087.40 5,956,435.90 366,739.51 0.00 4,911.41 19,700.00 90.39 348.08 7,237.53 7,182.43 -1,093.29 -11,108.06 5,956,534.06 366,720.44 0.00 4,826.53 19,800.00 90.39 348.08 7,236.85 7,181.75 -995.45 -11,128.72 5,956,632.21 366,701.38 0.00 4,741.66 19,900.00 90.39 348.08 7,236.17 7,181.07 -897.61 -11,149.39 5,956,730.37 366,682.31 0.00 4,656.79 20,000.00 90.39 348.08 7,235.49 7,180.39 -799.77 -11,170.05 5,956,828.52 366,663.24 0.00 4,571.92 20,057.12 90.39 348.08 7,235.10 7,180.00 -743.88 -11,181.85 5,956,884.59 366,652.35 0.00 4,523.43 Geologic Targets CD4-318b T1/p a rget h;; +N/-S +E/-W Northing Easting (tt) - Shz •, ft ft (ft) (ft) 7,256.10 .. .. ... .. .... . . -5,146.80 -10,252.05 5,952,467.51 367,510.41 -Polygon Point 1 0.00 0.00 5,952,467.51 367,510.41 Point 2 4,402.92 -929.80 5,956,884.59 366,652.35 7,235.10 CD4-318b wp01 Toe -743.88 -11,181.85 5,956,884.59 366,652.35 - Circle (rad ius 100.00) 7,256.10 C04-318b wp01 Heel -5,146.80 -10,252.05 5,952,467.51 367,510.41 - Circle (radius 100.00) 8/10/2006 4:24:54PM Page 7 of 8 COMPASS 2003.11 Build 50 • • ~ C Philli Sperry Drilling Services HALLIBURTON onoc o ps Alaska Planning Report -Geographic Sperry Drilling Services Database: EDM_2003.11_648 Local Co-orclinate Reference: Well CD4-318 Company: ConocoPhillips Alaska Inc. TVD Reference: Planned Doyon 19 @ 55.10ft (Doyon 19 (36.1 + 19)) Project: Colville River Unit MD Reference: Planned Doyon 19 @ 55.10ft (Doyon 19 (36.1 + 19)) Site: Alpine CD4 North Reference: True t Well: CD4-318 Survey Calculation Method: Minimum Curvature Wellbore: CD4-318b Design: CD4-318b wp01 Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (~) (ff) ("1 (") 3,485.20 2,375.32 9-5/S 12-1/4 15,689.36 7,261.53 7 8-3i4 Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N!-E +E/-W (~) (°) l°) (~) (ft) (~) Name 3,594.59 64.70 230.62 2,422.16 -1,228.02 -1,764.10 C-30 4,472.56 65.00 232.00 2,795.00 -1,759.05 -2,354.40 C-20 7,006.53 65.00 232.00 3,865.90 -3,172.95 -4,164.11 K-3 7,525.20 65.00 232.00 4,085.10 -3,462.35 -4,534.54 Base K3 7,638.16 65.00 232.00 4,132.84 -3,525.39 -4,615.21 K-2 7,851.74 65.00 232.00 4,223.10 -3,644.55 -4,767.74 Base K-2 11,602.36 65.00 232.00 5,808.18 -5,737.32 -7,446.36 Albian 97 12,601.19 64.97 240.82 6,230.56 -6,279.40 -8,170.26 Albian 96 14,397.89 69.17 307.60 6,991.53 -6,090.13 -9,686.02 Top HRZ 14,821.72 74.30 323.45 7,125.08 -5,803.54 -9,966.23 Base Hrz 15,030.50 77.26 330.93 7,176.43 -5,633.55 -10,075.71 K-1 Marker 15,242.70 80.47 338.35 7,217.47 -5,445.54 -10,164.72 Kuparuk D 15,494.33 84.47 346.98 7,250.50 -5,207.67 -10,238.88 Kuparuk C 8/10/2006 4:24:54PM Page 8 of 8 COMPASS 2003.11 Build 50 STATE OF ALASKA 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPS Test Report Submit to: aim re~~;~~3~adrl~:in.state.a>i.us ao~c; prud~oe b:y~~d:~1n.s~tate.ak.us bol fecl~enster~ ;~adrr:i:~.state.~ak.us Contractor: Doyon Rig No.: 19 DATE: 8/16/2006 Rig Rep.: Hunnington/Krupa Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Mickey/Lutrick Field/Unit & Well No.: Colville Rv CD4-318a PTD # 206-113 Operation: Drlg: x Workover: Test: Initial: Weekly: Test Pressure: Rams: 250/5000 Annular: 250/3500 TEST DATA MISC. INSPECTIONS: Test Result Test Result Location Gen.: P Well Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13-5/8 P Pipe Rams 1 3-1/2x 6 P Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1/8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results Explor.: Bi-Weekly x Valves: 250/5000 FLOOR SAFETY VALVES: Quantity Test R Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test R No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 3200 P Pressure After Closure 1600 P 200 psi Attained 22 P Full Pressure Attained 3 min 18 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ 2000 psi Number of Failures: 0 Test Time: 4.5 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: )im r~~~;~adrr:i:~.state.alc.u~ Remarks: Good test. 24 HOUR NOTICE GIVEN YES X NO Waived By John Date 08/12/06 Time 5:30pm Witness Huntingti Test start 10:OOgm8/15 Finish BOP Test (for rigs) BFL 11/09/04 Doyon19 8-16-06 CD4-318a.xls CD4-318a Notice C7 C Subject: CD4-318a Notice From: "Galiunas, Elizabeth C" ~~Elizabeth.C.Galittnas@conocophillips.conl Date: ~~'cd, 1 b Atli 2006 10:=~~2 ~ -0800 To: Thomas Maunder <.tom maundcr(~i~admin.state.ak.us= Tom, a©~ -~~~ The difference in the bottom abandonment plug from the sundry is as follows. The abandon casing was left with 400' of cement in the window/whip stock/casing (TD of 14819'), up to 14419' MD. The cement retainer was jammed, so we decided not to run it and cement off the lower section. The top plug was executed as proposed in the sundry. Thanks, Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-265-6247 Cell: (907)-441-4871 l of 1 8!16/2006 10:57 AM Re: CD4-318a Update Suhject: Re: CD4-318a Update From: Thomas Maunder <tommaunder@adinin.state.ak.us= Date: Thtt, 10 :~u~~ ?UU(i 1 ~:~ ~:?3 -(1500 To: "Galiunas, Elizabeth C" <Elizabeth.C.Galiunas(a'conocophillips.com> CC: Brian Noel <Brian.Noel(uconocophillips.com Liz, Your plans confirm our discussion this morning. I will look forward to the sundry. Your have "verbal" approval to proceed as planned. ~s ~~~~ ~~~~~~~~ ~~~ Tom Maunder, PE Galiunas, Elizabeth C wrote, On 8/10/2006 3:41 PM: ~ ,~~~-- ~~~ ~~~~~ ~ ` ~~N Tom, -~-O~~Cr~ c~~-T'l~ hu.~;> ~p'~'' ~, ~'~~~ ~V~ 1 am currently working on the sundry to get over to you. It will be there tomorrow. ~~--/ ~` l ~` ', To summarize our the well's history and plan forward: Drilling operations on CD4-318 began on 12!4!2005 with Doyon 19 (permit no. 205-196). While drilling the intermediate section we could not get into the sand due to a layer of siderite. The decision was made to set intermediate casing at that point and go in with a clean out assembly to get into the sand and then drill the horizontal section. This did not work. We went in with an insert bit and motor and left three cones in the hole, but around 40' of sand was opened. The decision was made to complete the well temporarily and return since the ice road had opened and the rig was needed on CD3. The well was flow tested this winter. The rig returned July 28, 2006 to decomplete the well, attempt to mill out the cones, and drill the horizontal. Due to problems caused by the shale outside the casing shoe, the decision was made to abandon this hole section, set a bridge plug and whipstock, and sidetrack out of the casing. After milling out the window and 15' of new hole, a motor and PDC bit was run in to try and get through the shale and into the sand. The shale was causing the assembly to packoff and therefore stalling out the motor. A milling assembly was run in to try and clean up the shales and through the window. This run looked to have helped the situation, but upon pulling of the hole with the milling assembly it was found that the mill and the bent sub was left in the hole. After assessing options, it was concluded that the best option for getting a usable well is to cut and pull the 7" casing outside of the surface casing shoe. To do this, we are going to cement the open hole, plus an additional 50', set a bridge plug at 14,760'. Also we will seta +50' cement plug above the bridge plug to 14,710'. A casing test will be done at this time: 3500 psi for 30 mins. Set a bridge p{ug at 3775' MD which is 130' below the desired casing cutting depth of 3645' MD. The casing is cut 160' below the surface casing shoe. A cement plug to kick off the casing stub will be +/-200' inside the surface casing to 3285'. 1 of 2 8/16/2006 9:53 AM Re: CD4-318a Update The well will be kicked off right outside tr within around 200' of the original wellbore. appropriate paper work will follow. • surface casing shoe and stay well If the new wellbore exceeds 500' the As we talked earlier, this well will still be called CD4-318a. I will get the sundry to you as soon as possible. Thanks, Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-265-6247 Cell: (907)-441-4871 2 of 2 8/16/2006 9:53 AM Re: RE: FW: CD4-318 GR Res PDF format ~~ Subject: Re: RE: FW; CD4-31$ GR Res PDF formni From: Thomas ~. I~~]aundcr <tome-maunder(a~~~admin.state.ak us> Date: Sat, 05 Auer ?006 07:56:00 i1801i To: "Galiunas, E~izabeih C" ~=E.lizabeth.C.Galiunas(r%conocophillips.con>> CC: Doyon 19 Company Man <doyon 1 ~uconocophillips.conti, Liz, Your proposal is acceptable. You have specific knowledge of the conditions at the shoe and the whipstock will not be much tvd shallower. Good luck. Tom Maunder, PE AOGCC ----- Original Message ----- From: "Galiunas, Elizabeth C" <Elizabeth.C.GaliunasC~conocophillips.com> Date: Friday, August 4, 2006 5:09 pm Subject: RE: FW: CD4-318 GR Res PDF format Tom, We also wanted to verify that just pressure testing once we drill out and not actually doing another FIT, preventing aggravating the shales again. We did flow test this well back and therefore know the reservoir pressure and this well had a solid FIT of 12.5 ppg. We will pressure test to the max ECD seen on the shoe. With 10 ppg (max mud weight possible used without barite) the max ECD at the shoe is 11.8 ppg. Thanks, Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-265-6247 Cell: (907)-441-4871 -----Original Message----- From: Thomas Maunder [~r;ailto:tom maunde~~admin.state.ak.us] Sent: Friday, August 04, 2006 2:37 PM To: Galiunas, Elizabeth C Cc: Noel, Brian Subject: Re: FW: CD4-318 GR Res PDF format Liz, I spoke with Brian a little earlier on this. It appears that the combination of shale and bit cones will not allow you to proceed as planned. The well is at horizontal at the top of the zone so there really isn't anything to be realized by placing cement. You are planning to employ a whipstock to bypass junk. This is acceptable. I am not sure if you drilled sufficient hole to call that section PB1, regardless the wellbore name should still be CD4-318A, Call or message with any questions. Tom Maunder, PE AOGCC Galiunas, Elizabeth C wrote, On 8/4/2006 11:28 AM: Tom, here is the log and the schematic before we re-entered 1 of 2 8/16/2006 9:54 AM Re: RE: FW: CD4-318 GR Res PDF format the well. You may have this, but we wanted to be sure. We also ', wanted to ', ask you about needing cement in the hole we are going to abandon. ', Sincecurrently with the horizontal section a cement plug would not be good ', enough to ensure a good place to redrill through. This well is a producer. Is is possible to just run a bridge plug and use that as our base for the whipstock? let me know what you think. Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-265-6247. Cell: (907)-441-4871 -----Original Message----- From: Sulyn Moy [mailto:SMoytanchorage.oiifield.slb.com] Sent: Friday, August 04, 2006 7:33 AM To: Galiunas, Elizabeth C Subject: CD4-318 GR Res PDF format Liz What is promise. CD4-318 GR, Res in pdf format Cheers Sulyn Sulyn Moy Drilling Service Field Engineer Schlumberger Oilfield Service DRILLING AND MEASUREMENTS 2525 Gambell Street. Suite 400 Anchorage, Alaska 99503 Home telephone number:907- 644-2803 Anchorage Office 907-273-1700 Prudhoe Bay Unit: 907- 448-2055 Fax (Prudhoe Bay): +1 907 659 2745 e-mail: SMa~rCanchora~e_oil_.'ield..slb.com 2 of 2 8/16/2006 9:54 AM "" STATE OF ALASKA ' 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: dim r~:gg,;,;~3~adn:i:~.5tate.ak.~~s ao~. pr~Ed~ae b~:~ad¢nin.state.ak.u5 bol_r _eckensten;~3a~~:i:~.5tate.a~.i1~~ Contractor: Doyon Rig No.: 19 DATE: 8/1/2006 Rig Rep.: Hunnington/Lupton Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Mickey Field/Unit & Well No.: Colville Rv CD4-318a PTD # 206-113 Operation: Drlg: x Test: Initial: x Test Pressure: Rams: 250/5000 Workover: Weekly: Annular: 250/3500 Explor.: Bi-Weekly Valves: 250/5000 MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Quantity Size Annular Preventer 1 13-5/8 Pipe Rams 1 3-1/2x 6 P Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1 /8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P TEST DATA Test Result P_ P FLOOR SAFETY VALVES: Quantity Test R Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test R No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 3100 P Pressure After Closure 1650 P 200 psi Attained 28 P Full Pressure Attained 2 min 40 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ 2000 psi Test Result P Test Results Number of Failures: 0 Test Time: 6.25 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: dim re q,~yadmin.5tate.ak.us Remarks: Good test. 24 HOUR NOTICE GIVEN YES X NO By Chuck Scheve Date 07/30/06 Time 14:33 Witness Lu Test start 21:45pm Finish 4:OOam BOP Test (for rigs) BFL 11/09/04 Doyon19 7-31-06 CD4-318a.xls ~ ~ ~ ~ ~ ~ ~~ + ' ~ ; ~ ~ ~ ~ ~ ~ ~ ~ ~ 1 ~ t ,~ ~~ ~ ~ % FRANK H. MURKOWSK/, GOVERNOR i e' ~~~~ ~~~~rr ~1a~ ~t~~+ x AJ1A7~ O~ ~ ~ ~~ 333 W. 7"' AVENUE, SUITE 100 COI~TSER~ATI011T COMI~IISSIOI~T j, ANCHORAGE, ALASKA 99501-3539 a' PHONE (907) 279-1433 ' FAX (907) 276-7542 July 27, 2006 Mr. Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Administrative Abandonment Action Colville River Unit CD4-318 Permit # 205-196 Dear Mr. Alvord, Colville River Unit ("CRU") well CD4-318A (permit #206-113, API # 50-103-20519-01) will replace CD4-318 (permit #205-196, API # 50-103-20519-00} effective the date that permit 206-113 is approved by the Commission. CRU CD4-318A incorporates an extension to a new bottom hole location from the existing CRU CD4- 318 well bore. This extension, along with the original well bore, will be used for production of hydrocarbons. A review of the well history file for CD4-318 and the proposed operations in CD4-318A indicates administrative abandonment of the originating well bore is appropriate according to current Commission procedures for wells when an additional permitted extension is drilled from an existing well bore. 20 AAC 25.005(a) requires a Permit to Drill for each hole drilled below the conductor unless drilled to straighten the original hole, sidetrack junk, or correct mechanical difficulties. In addition, Commission databases require one permit number and API number for each conductor. Administrative abandonment of the original well bore only eliminates duplication in databases. Information for the original well bore and its replacement will be maintained in their respective files. Please notify other affected personnel in your organi n o that the well will be correctly identified on subsequent reports and applications submitted to th o ssion. cc: Commission Well History File #205-196 Commission Well History File #206-113 ' (± ~ i ~ ~~ 3 ~ ~ ~ ~ s ~ ) FRANK H MURKOWSK/ GOVERNOR ~t ~~ u ~ ~ ; ~~I ~ 3 ®~' ~ ~ :~ ~ a . , ~-7~ OI~ ~ aTl~-7 T ` ' J' 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE ALASKA COI~ SE RQA7 IO1~T CO1~II~ IISSIOIQ , 99501-3539 7 ~' PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Nanuq Kuparuk Oil Pool CD4-318a ConocoPhillips Alaska, Inc. Permit No: 206-113 Surface Location: 2312' FSL, 400' FEL, Sec. 24, T1N, R4E, UM Bottomhole Location: 3719' FNL, 821' .FEL Sec. 22, T11N, R3E, UM Dear Mr. Alford, Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this ~/7 day of July, 2006 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. ~.EIVED ~~~,~ .i ~ L 2 7 2006 STATE OF ALASKA r~ ALASKA OIL AND GAS CONSERVATION COMMISSION wisSl(d iii L~ Ci3S S+Qn$. COCT1n11S510n PERMIT TO DRILL ~n~horage 20 AAC 25.005 1 a. Type of Work: 1 b. Current Well Class: Exploratory ^ Development Oil ^ 1 c. Specify if well is proposed for: Drill ^ Re-drill ^ Stratigraphic Test ^ Service ^ Development Gas ^ Coalbed Methane ^ Gas Hydrates ^ Re-entry ~ Multiple Zone^ Single Zone Q Shale Gas ^ 2. Operator Name: 5. Bond: ~ Blanket Single Well 1 1. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 CD4-318a 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 19778' ' TVD: 7235' Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation: lx ~,Z? p` Surface: 2312' FSL, 400' FEL, Sec. 24, T11 N, R4E, UM ADL 380077, 38 , 38 Nanuq Kuparuk Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1560' FSL, 2101' FWL, Sec. 26, T11 N, R4E, UM ALK 38077 7/31/2007 Total Deptly / ' ^-` ~. p(~ y 68 ZZ /~' 7` Z 9. Acres in Properly: 14. Distance to ~`~'~.y»y1„~ 3 f 860' FNL ADL 39067i P t i ~~i/ Zgg'' ,p1~"1 Sec.~Q'T11N, R4E, UM 2560 + roper y: Nearest 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest t Surface: x- 377844 y- 5957447 Zone- 4 (Height above GL): 36.5' RKB feet Well within Pool: CD4-319 , 5536 16. Deviated wells: Kickoff depth: f15~z$~~~ ft.a 1 ~M~ xi um Anticipated Pressures in psig (see 20 AAC 25.035) " Maximum Hole Angle: ~0° deg Downhole: 3281 psig + Surface: 2550 psig 18. Casing Program Specifications Setting Depth Quantity of Cement or sacks f Bottom c T . . op Size Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 16" 62.5# H-40 Weld 77 37 37 114 114 pre installed 12.25" 9.625" 40# L-80 BTC-M 3448 37 37 3485 • 2375 520 Sx AS Lite & 233 sx 15.8 g 8.75" 7" 26# L80 BTC-M 15010 37 37 15047 7252 - 108 Sx 15.8 G & 173 Sx 11 ppg LCret~ 6.125" 4.5 12.6# L80 IBT-M 4871 14897 7233 19768 7235 slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural 16 Pre installed Surface 9.5/8 520 Sx AS Lite & 233 sx 15.8 g 3485 2,375.00 Intermediate 7 108 Sx 15.8 G & 173 Sx 11 ppg 15047 7,252.00 Production Liner 4-1 /2" na 19,768.00 7,235.00 Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee Q BOP Sketch^ Drilling Program Q Time v. Depth Plot Shallow Hazard Analysis /^ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program O 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Vern Johnson @ 2&5-6081 Printed Name C. Alvord Title Alpine Drilling Team Leader Signature ~~ ~ ~ Phone ~, ~~~ ,.~. / ~ ~ Date -~ ~~~~ ~~~ ~~~ Pre r d b V rn has n °° Commission Use Only Permit to Drill API Number: / ~ , Permit Approval ~ ~ ~ ? See cover letter uirements ther re f b N ~~ ~ ~ ~3 50- f D3~ ~~` ~ ~ Date: q or o um er: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed meths ,gas hydrates, as ontained in shales: ~ ~~~(~ `~ Samples req'd: Yes ^ No to q'd: Yes ^ No []v Other: 3`~ ~'"'' ~~ ~~~~`~`~~vO~ ~'' ~ H2S measures: Yes ^ No Di al s req'd: Yes ~ No ^ N ~ P OVED BY THE COMMISSIO Z7 D ~ ~ ,COMMISSIONER DATE: r,..... 1n_nn1 Re.deeri 17/9M~, ~~'/,Submit in Duplicate r~,~ ~yE Cb .L7~i JUL-27-2006 14 36 ~INE ANCHORAGE ~ 907 265 1515 P. 02 CD4-318A Heel ~IUL 2 7 2006 Alaska Uil & Gas Cons. Commission Anchorage TOTAL P.02 • • CD4-318A Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 6-1/8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 8.8 ppg. Pressure ~ Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low ~ HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers OR161NAL Alpine :CD4-318A Procedure Procedure 1. Before moving on CD4-318a, confirm that a BPV has been set. (PHASE: DECOMP) r~ ~--~ 2. Move on Doyon 19, dewater cellar as needed. (PHASE: DECOMP) 3. Rig up over CD4-318a (PHASE: DECOMP) 4. Pull BPV and displace well to 9.2 ppg brine, taking returns to an open top tank. There will be diesel in the tubing and the top +/- 2600 ft MD annulus as freeze protection. 185 bbls of diesel has been pumped since the rig moved off the well. See the Well Service Reports for more details. (PHASE: DECOMP) i 5. Install two way check, nipple down the tree. (PHASE: DECOMP) ~ 6. Nipple up and test BOP. (PHASE: DECOMP) 7. Pull two way check. (PHASE: DECOMP) 8. Attempt to pull tubing hanger to floor. Only pull 40,000 Ibs over on the packer, if not moving, then rig up E- Line to re-cut the packer. See Baker Oil Tools Fishing contingency plan, Attachment 6, if not able to pull " ~ tubing. Check pipe for Normally Occurring completion. If possible, pull out of hole laying down 3-1/2 Radioactive Material (NORM). (PHASE: DECOMP) 9. RIH with BOT milling BHA to 7" shoe depth. Displace well to 9.2 ppg Flo-Pro. Establish all up, down, and rotating weights. Begin washing and reaming open hole to TD. The bit cones should be on bottom. Mill and attempt to make 2-3' of hole. CBU and then POOH. (PHASE: PROD) ~i J ~11 1 12 13 14 IS ©- A~A~ L=~ 10. M/U and run the AnadrilUSchlumberger "Periscope" LWD / Powerdrive rotary steerable drilling assembly (GR/RES/PWD/DIR). (PHASE: PROD) Dri116-1/8" horizontal section in the Kuparuk sand to well TD at 19,778' MD / 7,235' TVD. (PHASE: PROD). Circulate hole clean and displace to 9.5 ppg mud. Pump out to casing shoe. (PHASE: PROD) Continue to pull out of hole and lay down BHA. (PHASE: PROD) Pick up and run in hole with lower completion; complete with Baker V Set shoe, 4- ''/z" 12.6ppf slotted /blank liner, Baker Flex lock hanger, 5" liner setting sleeve w/ extension, Baker HR liner running tool. (PHASE: CMPLTN) Set the 4- %z" liner +/- 10' off bottom (Assure liner hanger is not set in collar). Pump the setting ball and ensure hanger is set. Pressure up to release the setting tool. (PHASE: CMPLTN) 16. Displace well to 9.5 ppg. (PHASE: CMPLTN) 17. Pull out and LD running tools. (PHASE: CMPLTN) 18. Run upper completion consisting of: Baker fluted WLEG, 4-''/z" 12.6ppf L-80 IBT, No-go XN Nipple (3.725"), Baker Premier Packer, 3 gas lift mandrels with dummy valves and DCK-2 Shear valve in bottom mandrel (3400'TVD, 5700' TVD, 2 joints above packer +/- 7433' MD/ 6790' TVD), BAL-O Landing Nipple (3.812"), and 4-''/z" 12.6ppf L-80 IBT Mod tubing. (PHASE: CMPLTN) 19. Tag setting sleeve, space out, land hanger. Back out landing joint. Insta112-way check with rods. M/U landing joint and test hanger seals to 5000 psi. (PHASE: CMPLTN) 20. Nipple down BOP. (PHASE: CMPLTN) 21. Install wellhead adapter assembly. Terminate the control line from the BAL-O landing nipple. Pressure test adapter assembly to 5000 psi. Remove 2-way check with lubricator. (PHASE: CMPLTN) ORIGINAL r • 22. Circulate conventionally inhibited brine and diesel freeze protect. (PHASE: CMPLTN) 23. MU the lubricator with roller/stem ball and rod installed. Drop ball and rod assembly. Test tubing to 3500 psi / 30 min. Test casing annulus against the liner hanger to 3500 psi / 30 min (keep 2000 psi on tubing while testing annulus to prevent the shear valve in the bottom GLM from shearing.) (PHASE: CMPLTN) 24. Set BPV and secure well. Move rig off (PHASE: CMPLTN) Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD4-319 will be the closest well to CD4-318A. Well separation is 5536' @ 18650' ~ MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. ' Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing oint-12'/" Intermediate hole to 7" casing point - 8 %" Production Hole Section - 6 1/8" Density 9.0-9.6 ppg PV 10 -15 YP 25 -30 Funnel Viscosity Initial Gels 10-15 10 minute gels Previously drilled Previously drilled and 12-20 API Filtrate and cemented cemented NA HPHT Fluid Loss at 160 12-14 cc/30 min PH 9.0-9.5 KCL 6% Oil /water ratio Surface Hole: Previously drilled and cemented. Intermediate Hole Section: Previously drilled and cemented. Production Hole Section The horizontal production interval will be drilled with an M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with ± 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. OR161NAL ,d ~M ~ ~ R CD4 -Nanuq Kuparuk Producer Completion 16" Insulated Conductor to 114' 4 Yi' 12.6 ppf L-80 IBT Mod. Tubing 3.812" BAL-0 Landing Nipple 2300' MD / 1868' TVD 9-5/8" 40 ppf L-80 BTCM Surface Casing 3485' MD / 2375' TVD I Iffi er Completion: ~Q TVD f~T. 1) Tubing Hanger 32' 32' 2) 4'/i',12.6#/ft, IBT-Mod Tubing 3) 4 ''/i' BAL-O Landing Nipple (3.812") 2300' 1868' 4) 4 ''/i' 12.6#/ft L-80 IBT Mod 5) Camco KBG-2 GLM (3.833" ID) 5829' 3400' 6) 4'/~' 12.6#/ft L-80 IBT Mod (Jts) 7) Camco KBG-2 GLM (3.833" ID) 11180' 5700' 8) 4 Y~' 12.6#/ft L-80 IBT Mod 9) Camco KBG-2 GLM (3.833" ID) 13500' 6777' w/ DCK-2 shear out valve (pinned for 3000 psi) 10) 4 '/~' 12.6#/ft L-80 IBT Mod (2 jts) 11) Baker Premier Packer 13600' 6824' 12) 4-%' 12.6#/ft L-80 IBT Mod (1 Jt) 13) HES No-Go XN (3.725") @ 63 deg 13650' 6847' 14) 4 ''/i' 12.6#/ft L-80 IBT Mod (30 Jts) 15) BOT stinger with fluted WLEG stinger 14880' 7231' Stung into tie extension 10' off bottom of at 14887' Lower Com lei Too MD ND Item 16) Baker 5" x 7" Flexlock Liner Hanger 14897' 7233' 17) 4'/i', 12.6#/ft, SLHT Tubing +/- 4 jts 18) 4-'/i' 12.6#/ft SLHT liner w/ blank across shale and slots across sand 19) Baker V Set Shoe 19768' 7235' Top of cement \ 11637' MD / 5896' TVD Top Reservoir at +/- Nanuq 12384' MD / 6230' TVD Kuparuk 14973' MD / 7251' TVD 4-'/z' 12.6#/ft L-80 IBT Mod Slotted liner Pattern: 7" 26 ppf L-80 BTC Mod Production Casing @ +/-90° 15,047' MD, 7,252' TVD TD 6-1/8" hole 19,778' MD / 7235' TVD ' ORIGINAL CD4-318A PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) Csg Setting Depth MD/TVD ft Fracture Gradient (Ibs. / al Pore pressure (psi) ASP Drilling (psi) 16 N/A N/A N/A N/A 9 5/8 N/A N/A N/A N/A 7" 15047 / 7252 16.0 3281 - 2556 - N/A 19778 / 7235 16.0 3274 N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to minimum 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1 ]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3281 - (0.1 x 7252') = 2556 psi 2. Drilling to TD = 3274 - (0.1 x 7235') = 2550 psi ' ORIGINAL Sperry Drilling Services CPAI Plan Report Company: ConocoPhillips Alaska Ina Date: 7/26/2006 Time: 15:38:20 Page: ' 1 Field: Colville River Unit Co-ordinate(NE) Reference: WeIL• CD4-318, True North . Site: Alpine CD4 Vertical (TVD) Reference: CD4-318: 54.9 Well: CD4-318 Section (VS) Reference: Well (O.OON,O.OOE,348.OOAzi) Wellpath: Plan: CD4-318A Sarvey Calculation-Method: Minimum Curvature Db: Oracle Plan: CD4-318Awp09 Date Composed: 7/26/2006 extension Version: 1 Principal: Yes Tied-to: From: Definitive Path Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: Alpine CD4 Site Position: Northing: 5957526.10 ft Latitude: 70 17 32.966 N From: Map Easting: 378174.70 ft Longitude: 150 59 10.763 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.93 deg Well: CD4-318 Slot Name: Alpine CD4 Well Position: +N/-S -84.84 ft Northing: 5957446.62 ft Latitude: 70 17 32.131 N +E/-W -329.52 ft Easting : 377843.88 ft Longitude: 150 59 20.366 W Position Uncertainty: 0.00 ft Wellpath: Plan: CD4-318A Drilled From: CD4-318 Tie-on Depth: 15184.03 ft Current Datum: CD4-318: Height 54.86 ft Above System Datum: Mean Sea Level Magnetic Data: 7/26/2006 Declination: 23.26 deg Field Strength: 57502 nT Mag Dip Angle: 80.63 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 35.86 0.00 0.00 348.00 Survey Program for Defmitive Wellpath Date: 7/26/2006 Validated: No Version: 0 Actual From To Survey Toolcode Tool Name ft ft Plan Section Information 11'ID Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target" ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 15184.03 88.15 344.72 7252.69 -5147.47 -10032.13 0.00 0.00 0.00 0.00 15242.00 88.15 344.72 7254.56 -5091.57 -10047.40 0.00 0.00 0.00 0.00 15354.22 90.28 347.91 7256.10 -4982.57 -10073.94 3.42 1.90 2.84 56.30 19689.10 90.28 347.91 7235.10 -743.88 -10981.85 0.00 0.00 0.00 175.53 CD4-318Awp09 Toe Survey MD ft 3485.20 15047.03 15184.03 15200.00 ,~ 15242.00 15300.00 15354.22 15400.00 15500.00 15600.00 15700.00 15800.00 Incl Azim TVD Sys TVD N/S E/W deg deg ft ft ft ft 64.58 231.30 2375.36 2320.50 -1166.11 -1686.99 90.02 339.72 7252.75 7197.89 -5277.90 -9990.41 88.15 344.72 7252.69 7197.83 -5147.47 -1.Oe04 88.15 344.72 7253.21 7198.35 -5132.07 -1.Oe04 88.15 344.72 7254.56 7199.70 -5091.57 -1.Oe04 89.25 346.37 7255.88 7201.02 -5035.43 -1.Oe04 90.28 347.91 7256.10 7201.24 -4982.57 -1.Oe04 90.28 347.91 7255.88 7201.02 -4937.81 -1.Oe04 90.28 347.91 7255.39 7200.53 -4840.03 -1.Oe04 90.28 347.91 7254.90 7200.04 -4742.24 -1.Oe04 90.28 347.91 7254.41 7199.55 -4644.46 -1.Oe04 90.28 347.91 7253.92 7199.06 -4546.68 -1.Oe04 MapN MapR DL5 ' VS Comm ft ft deg/100ft ft 5956308.17 376138.31 0.00 -789.88 9 5/8" 5952332.18 367769.86 0.92 -3085.44 7" 5952463.27 367730.27 3.90 -2949.18 Tie in point; 151 5952478.73 367726.32 0.00 -2933.25 5952519.40 367715.91 0.00 -2891.34 Kick off; 15242' --'~---• 5952575.77 367702.36 3.42 2833.41 5952628.80 367691.15 3.42 -2779.20 Target Heel; 15 5952673.72 367682.29 0.00 -2733.42 5952771.82 367662.94 0.00 -2633.42 5952869.92 367643.59 0.00 -2533.42 5952968.02 367624.24 0.00 -2433.42 5953066.12 367604.89 0.00 -2333.43 ORIGINAL Sperry Drilling Services CPAI Plan Report Company: ConocoPhillips Alaska' inc. Dater 7/26/2006 Time:. 15 :38:20 Page: 2 Field: Colville RiverUnit Co-ordinate(NE) Reference: WeIL CD4-318, True North Site: Alpi ne CD4 Vertical (TVD) Refe rence: C D4-318: 54.9 Well: CD4-318 Section (VS) Referen ce: Well ( O.OON,O.OOE,348.OOAzi) Wellpatb: Plan: CD4-3 18A Survey Calculation Method: Minimum Curva ture. Db: Oracle Survey T MD Incl Azim TVD Sys TVD N/S E/W ` MapN MapE DLS VS Comore t ft deg deg ft ft ft ft ft ft deg/100ft ft 15900. 00 90.28 347. 91 7253.44 7198 .58 -4448. 90 -1.Oe04 5953164. 22 367585 .53 0.00 -2233 .43 16000. 00 90.28 347. 91 7252.95 7198 .09 -4351. 12 -1.Oe04 5953262. 32 367566 .18 0.00 -2133 .43 16100. 00 90.28 347. 91 7252.46 7197 .60 -4253. 34 -1.Oe04 5953360. 42 367546 .83 0.00 -2033 .43 16200. 00 90.28 347. 91 7251.97 7197 .11 -4155. 56 -1.Oe04 5953458. 52 367527 .48 0.00 -1933 .43 16300. 00 90.28 347. 91 7251.49 7196 .63 -4057. 78 -1.Oe04 5953556. 62 367508 .13 0.00 -1833 .43 16400. 00 90.28 347. 91 7251.00 7196 .14 -3960. 00 -1.Oe04 5953654. 72 367488 .78 0.00 -1733 .43 16500. 00 90.28 347. 91 7250.51 7195 .65 -3862. 22 -1.Oe04 5953752. 82 367469 .43 0.00 -1633 .43 16600. 00 90.28 347. 91 7250.03 7195 .17 -3764. 44 -1.Oe04 5953850. 92 367450 .08 0.00 -1533 .44 16700. 00 90.28 347. 91 7249.54 7194 .68 -3666. 66 -1.Oe04 5953949. 02 367430 .73 0.00 -1433 .44 16800. 00 90.28 347. 91 7249.06 7194 .20 -3568. 87 -1.Oe04 5954047. 12 367411 .37 0.00 -1333 .44 16900. 00 90.28 347. 91 7248.57 7193 .71 -3471. 09 -1.Oe04 5954145. 22 367392 .02 0.00 -1233 .44 17000. 00 90.28 347. 91 7248.08 7193 .22 -3373. 31 -1.Oe04 5954243. 32 367372 .67 0.00 -1133 .44 17100. 00 90.28 347. 91 7247.60 7192 .74 -3275. 53 -1.Oe04 5954341. 42 367353 .32 0.00 -1033 .44 17200. 00 90.28 347. 91 7247.11 7192 .25 -3177. 75 -1.Oe04 5954439. 52 367333 .97 0.00 -933 .44 17300. 00 90.28 347. 91 7246.63 7191 .77 -3079. 97 -1.Oe04 5954537. 62 367314 .62 0.00 -833 .44 17400. 00 90.28 347. 91 7246.14 7191 .28 -2982. 19 -1.Oe04 5954635. 72 367295 .27 0.00 -733 .45 17500. 00 90.28 347. 91 7245.66 7190 .80 -2884. 41 -1.Oe04 5954733. 82 367275 .92 0.00 -633 .45 17600. 00 90.28 347. 91 7245.17 7190 .31 -2786. 63 -1.Oe04 5954831. 92 367256 .57 0.00 -533 .45 17700. 00 90.28 347. 91 7244.69 7189 .83 -2688. 85 -1.Oe04 5954930. 02 367237 .22 0.00 -433 .45 17800. 00 90.28 347. 91 7244.21 7189 .35 -2591. 07 -1.Oe04 5955028. 12 367217 .87 0.00 -333 .45 17900. 00 90.28 347. 91 7243.72 7188 .86 -2493. 28 -1.Oe04 5955126. 22 367198 .51 0.00 -233 .45 18000. 00 90.28 347. 91 7243.24 7188 .38 -2395. 50 -1.Oe04 5955224. 32 367179 .16 0.00 -133 .45 18100. 00 90.28 347. 91 7242.76 7187 .90 -2297. 72 -1.Oe04 5955322. 42 367159 .81 0.00 -33 .46 18200. 00 90.28 347. 91 7242.27 7187 .41 -2199. 94 -1.Oe04 5955420. 52 367140 .46 0.00 66 .54 18300. 00 90.28 347. 91 7241.79 7186 .93 -2102. 16 -1.Oe04 5955518. 62 367121 .11 0.00 166 .54 18400. 00 90.28 347. 91 7241.31 7186 .45 -2004. 38 -1.Oe04 5955616. 72 367101 .76 0.00 266 .54 18500. 00 90.28 347. 91 7240.82 7185 .96 -1906. 60 -1.Oe04 5955714. 82 367082 .41 0.00 366 .54 18600. 00 90.28 347. 91 7240.34 7185 .48 -1808. 82 -1.Oe04 5955812 .92 367063 .06 0.00 466 .54 18700. 00 90.28 347. 91 7239.86 7185 .00 -1711. 04 -1.Oe04 5955911. 02 367043 .71 0.00 566 .54 18800. 00 90.28 347. 91 7239.38 7184 .52 -1613. 26 -1.Oe04 5956009 .12 367024 .36 0.00 666 .54 18900. 00 90.28 347. 91 7238.90 7184 .04 -1515. 48 -1.Oe04 5956107 .22 367005 .01 0.00 766 .53 19000. 00 90.28 347. 91 7238.41 7183 .55 -1417. 69 -1.Oe04 5956205 .32 366985 .66 0.00 866 .53 19100. 00 90.28 347. 91 7237.93 7183 .07 -1319. 91 -1.Oe04 5956303 .42 366966 .30 0.00 966 .53 19200. 00 90.28 347. 91 7237.45 7182 .59 -1222. 13 -1.Oe04 5956401. 52 366946 .95 0.00 1066 .53 19300. 00 90.28 347. 91 7236.97 7182 .11 -1124. 35 -1.Oe04 5956499. 62 366927 .60 0.00 1166 .53 19400. 00 90.28 347. 91 7236.49 7181 .63 -1026. 57 -1.Oe04 5956597. 72 366908 .25 0.00 1266 .53 19500. 00 90.28 347. 91 7236.01 7181 .15 -928. 79 -1.Oe04 5956695. 83 366888 .90 0.00 1366 .53 19600. 00 90.28 347. 91 7235.53 7180 .67 -831. 01 -1.Oe04 5956793. 93 366869 .55 0.00 1466 .53 19689. 10 90.28 347. 91 7235.10 7180 .24 -743. 88 -1.Oe04 5956881 .34 366852 .31 0.00 1555 .63 CD4-318Awp09 I ~(~n ~l ~: a ~ ~ w1F ~ ~ ~ ~H~ a !rlti v Gb~- ~,,,~a,,,Q-. o (. y ?. 9' ORIGINAL L° ~^J DDDf I I.1Q11°rb('J R~ ^ °5 0 -- --- - J- o h --- O W H ~-- '6 ~ ~ 4] a . i M ~ A F ~ ~ ~ ~ +O ~ M A I (,a ~~` o n ~} p E ~d H \ Q ~3 . 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Date: 7/26!2006 Time: 15:49:18 Page: i Field: Colville River Unit Reference Site: Alpine CD4 Co-ordinate(NE) References Well: CD4-318, True.: North Reference Well: CD4-318 Vertical (TVD) Reference: CD4-318: 54.9 Reference Wellpath: Plan: CD4-318A Dbc Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: CD4-31$Awp09 & NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 15242.00 to 19689.10 ft Scan Method: Trav Cylinder North Maximum Radius: 2165.32 ft Error Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 3485.20 2375.36 9.625 12.250 9 5/8" 15047.03 7252.75 7.000 8.750 7" 19689.10 7235.10 4.500 6.125 41/2" Plan: CD4-318Awp09 Date Composed: 7/26/2006 extension Version: 1 Principal: Yes Tied-to: From: Definitive Path Summary <------ Offset Wellgath ---.> Reference Offset Ctr-Ctr No-Go Allowable' Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Alpine CD4 CD4-318 CD4-318 V6 15242.00 15242.00 0.00 0.00 0.00 FAIL: No Errors Alpine CD4 CD4-318 CD4-318P61 V3 15429.33 14850.00 205.52 No Reference Casings Alpine CD4 Plan: CD4-17 Plan: CD4-17 V1 Plan: 19594.19 13025.00 1360.22 149.92 1210.30 Pass: Major Risk Alpine CD4 Plan: CD4-321 Plan: CD4-321 V2 Plan: 17686.15 13425.00 1651.03 144.79 1506.24 Pass: Major Risk tOGRAM ORIGINAL ;~ _ ,: . °": s ~ eeeeeeeeeeeeeeeee°eeo°„o°°eaeeeeeeeoeo°oM1° ~hrM b e e ae „r° re.,n~enehenehon°~ern~°" ~~s"a~~xsas~"s"ss .....,.. ~ nh.°i.~iti.+N e~iww1M r~i.~i r~~i ~~n nrn.. .. .. ..~~h ~ ~ i; a ~~ _ ~oooo oee ~g~ee(~OMO ° °~.'1pN On°n°h Onen en ona n°O,nO ~ d~y'F ~( A ~ Nnhei.Ninh°~.1~P tv h eVn tna $i~0~ h ~~yy e r+ cc 11~~.. hN 7R'7- n 4+~ienninw w.r ~n .n.~hf'. $~~ODPS QO. i-1 .°+° ..i .ti.r..~ ~ " _ _ _ - -______ ~ o ~ ~~ yy 88° '~ F ~R~ ii ~~~ ii e I I ~ ~ I' I ~ ~p{ 'v SRxg°g„ ~ ~ 'S~'.~ t ~~~ -- - ~,~,,` ~ rr, fir' ~ lY;l CC^: 6 ! -~'~'~ ~ - -;r. ~-_ ~ - ~ ys s _ _~__~-_ }- -t- r r ~ p~e ~^ F e M M h ~ h n e M1 M1 d .~~. ! 7~ 1 1 I I I 1 I I I I 1 ~ jY es use LLF""' 8 ~` ~~~e3 ~~s~ ~ ~~ ~x~`~ €a€~ ~ ~e eOneeeeeeoeeeeeeeeeeeo~oeeeoeeeeeeeeee~°eo~o°onee°~e°o„oeoeeeeneee~o°e~o°o°o°e~e° .~,n°~.°,n°~.°,n°er.°~n°er.°.n°~...-,n ssvv nn epc~~y (M1, "'~'.°-~.".."3.M1.c°.r~n..Nr°-""„'M~~~~-°,.~-~rC-~°~~~~F'n~$Fd$~8~~o~~oeee rnh.°i.~r.r.tir nnrmrn ~n ~n••+rtnnn n.. .. .. ..~hh~$ W ~~O.PO~O~N H.°iti.-~.y.y.ti.ti.y.y...i.~'+ti.y.-,.y.y.-~.ti.~.y.y.r.r~.ti.-~.y.-I.r .y .y.y.y H.y .r .y ~v svc~r ~ ~e~e°°ee°°„ee°°°°°eOee°°°°e„neeeeeeee °ee a eee eeee eeeeee°eeee ,~ n^~~~~~r~~MMMM°s:~~~rn~°....~ r1:~~~~~~~MMM~~~~~'°~~~'~~~~~~~~sa~~as~so~n ~vN N ~ g~B _ a-~ g ~ r _ _ - . _ - ---_-_ ~~ Lr p ~.°.~ s 8 ~ ~ ` ~~ ~ 8 - - ~. ~' ~~~ ~ ~4 5 ~y __ - __ '+5 6 c_+ S s + - n z c ~ ~ I i _s ~t i g 8 ~ ~ - ~i 55~ 6 ~I r 66 v - ~ -. 5 _ r B ~ 1 _ _ _ _ -_ - - a P r ' ~S ~~~ P ~ r~r~~r~~yy~ M w GG¢ x , ~ III - ; h ° h ~~ 0 z n r ti M a • S O O O O O OO O O O O O O O O O O P 0~0 ^~~ O ~'J N ~^ O P P N a P U P P P a P P P OL681 bOZC9E - .. ... 60Z99E -i ---~ -.- _ ~- -I- I OLbLI $ ~ s ~ $ ~ bozs9E -T--t-r~-T~-T1-T-I-T-I-?-?-' ` bozo9E -t-f-i-l-tl-t-i-t-F-t-F-~-N £ ` _ 60ZE9E -LJ-LJ-1J_LJ-1_L1-L1-L. OL691 i I I I I I i_I 60ZZBE ---rZ-rr-T1-r,-T-rT I-'7-t-' bozoae - --L.1-LJ-IJ-LJ-1-L1_L1_L. OL6St bozb[e ---- ~ I I i I 60ZBLE ---~-~~-i-~-~~-±~-t-F-t-~ OL641 bozLLe ~--~-L.1-LJ-LJ_LJ-1-Ll_L 60Z9CE _.----T~-T1-T1-T~-T-(-T-I-.. 60ZSL£ ---1-+--}-~~-f1-tl-t-f ~----- ~ ° OLb£l u 60ZE[E p y OL6Z1 ~ bOZZLE { 60ZlLE 1 ~ E ~ bOZO[E OL611 ~ ~ x E ; r $ 60269E i i ~ ~ ~ ~ ~ 60299E 602[9£ -~ OL601 60299E ~ ~ - U bozs9E ~-~- 60Z 69£ -1-L' OL66 602£9£ .*-r. 60229E ~ -~-I"'~ 602 i 9E --~-~-L. OC68-c bozo9e ------ _T-r.7-r. a 60Z6SE -~-}~-}~-+~-Y--I-+-H+-~~-~~ OL6L> a y 8 8 bozese --L~-~-J--~-~-f~--F-~~ ~~-~~ 3 a a ~ ~ boz[se --r-r-r--~-r~-r~-t-rT-r7-r' °' N Z9sE --;-~-+-~-+~-+~-+-I-+-I-~-1- 8 I v zSSE - OL69` 3 _LJ_LJ_JJ_LJ_i_Li_L1_L. °' > ,_I ! 1 1 1 1 1 I I I I I I 3 e case --rr-r-,---7--r-r-rt-r--~-r o $ I o zese -----~-~~-r-------I-+-'F--~-~ o[bso $ Ld_ zzsE v v c d ei c !p > s~. N I< C ; P ~ 3 ~' ~o>- 3 3 3 v __ ~vvv3 0~~~ v Oooo~M~ ~ ~ ~ o~ ~ c ~o ~r ao 'O g r y ~ M I~ M ~ ~O ~O N 3 N N N ~ M N C H ~ M > > ~O v ~ C C N x> ~ ~ v v 0 ZUZZU ~:~~ OLbV o u ~ ati a OLb£ ~ ~L6L ` OLbI OL6 ~£- 0£01- 0£OZ- o£o£- o£ov- o£os- `~ i °-' ~ _ 0£09 I I ~ I p 0£OL- I V I Vf 0£08- ORIGINAL 41daa lo~lua~ anal wals,(g Closest in POOL '`~ /iY/ ~~~ .....~.~ Closest Approach: Reference Well: CD4-318w p07 Plan Offset Well: CD4-319 Coords. - Coords. - 3-D ctr- ASP ASP ctrMin. Meas. Incl. TRUE Subsea N(+)/S(-) ~/~ewVS Meas. Incl. TRUE Subsea N(+)/S(-) VewVS Dist. De th An le Azi. TVD E + /W - 348° Comments De th An le Azi. 1'VD E + /W _ 348° CommerNs in is nce in istance (5536.18 ft) in POOL (5536.18 ft) in POOL (7074 - 7120 Subsea (7074 - 7120 Subsea ND) to CD4$19 ND) to CD4- 5536.18 18650 90 348.08 7109.876 5955825 367056.5 479.6499 SLB MWD 17125 91.05 347.98 7092.912 5956885 372490.4 477.2204 318wp07 Flan Closest Approach: Reference Well: CD4-318w p07 Plan Offset Well: Nanuq 3 Coords. - Coords. - 3-D ctr- ASP ASP ctrMin. Meas. incl. TRUE Subsea N(+)/S(-) VewVS Meas. Incl. TRUE Subsea N(+)/S(-) UewVS Dist. ih An le Azi. TVD E + /W - 348° Comments De th An le Azi. TVD E + /W _ 3q8° Comments m istance POOL Min Distance (6364.19 ft) in POOL (6364.19 ft) in POOL (7074- 7120 Subsea (7074 - 7120 Subsea ND) to CD4- 6364.19 18975 90 348.08 7109.876 5956144 366994.8 804.6496 ND) to Nanuq 3 8575 22.12 271.5 7100.244 5957356 373242.5 794.8554 318wp07 Plan Closest A proach: Reference Well: CD4-318w p07 Plan Offset Well: Nanuq 2 Coords. - Coords. - 3-D ctr- ASP ASP ctrMin. Meas. Incl. TRUE Subsea N(+)/S(-) VewVS Meas. Incl. TRUE Suluea N(+)/S(-) UiewVS Dist. De th An le Azi. TVD E + /W - 348° Comments ih An le Azi. TVD E + /W _ 348° Comments in istance POOL Min Distance (6798.93 ft) in POOL (6798.93 ft) in POOL (7074 - 7120 Subsea (7074 - 7120 Subsea ND) to CD4- 6798.93 15900 90 348.08 7109.876 5953125 367581 -2270.35 ND) to Nanuq 2 8025 0.19 188.37 7114.058 5954428 374254 -2306.84 318wp07 Plan Closest Approach: Reference Well: CD 4-318w p07 Plan Offset Well: CD2-60 Coords. - Coords. - 3-D ctr- ASP ASP ctrMin. Meas. Incl. TRUE Subsea N(+)/S(-) ~liewVS Meas. Incl. TRUE Subsea N(+)/S(-) VewVS Dist. De tl~ An le Azi. TVD E + /W - 348° Comments De th An le Azi. TVD E + /W _ 348° Comments in is ante in is ante (7237.65 ft) in FOOL (7237.65 ft) in POOL (7074 - 7120 Subsea (7074 - 7120 Subsea ND) to CD2-60 ND) to CD4- 7237.65 19726 90 348.08 7109.876 5956881 366851.7 1555.649 Rig IFR 13375 67.34 178.13 7118.371 5963740 369163.8 7836.09 318wp07 Ftan FOOL Summaryl.xls 11/308005 2:17 PM • JUL-27-2006 14:36 ~INE ANCHORAGE Cor~oca~h~~li s p Alaska, Inc, FACSIMILE TRANSMI'I'TAL SI3EET DATE: ~~2 ~~G6 TO: ~i ~ vt~- i,:~-S . FROM: !/ ~~ ~ ~ ~,so~-•- o~G S-' -~a ~' / 907 265 1515 P.01 Notes: NO.OF PAGES FOLLOWING COVER: 1 Faux: (90']~ 265-1515 ~~ - .,t ,~v ~~~h;,.. a ~~ rn~„ q . ~~x. r~~ Phone: (907) 263-4414 JUL-27-2006 14 36 ~INE RNCHORAGE ~ 907 265 1515 P.02 CD4-31 SA Heel >~' ~~: ;;,,„. a:; CI74-318Awp49 Toe ~~~~, ,, r ~ 1 8 ~ ~ ' i' ~~ '?~' TOTAL P.02 ConocoPhillips Alaska, Inc Post C?ffice Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 26, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD4-318A Dear Sir or Madam: r COnOCaPhilllp5 ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD4 drilling pad. The intended re-entry date for this well is July 31, 2006. It is intended that Doyon Rig 19 drill the well. CD4-318 was drilled earlier this year, however after drilling a short horizontal and running a temporary completion, drilling operations were stopped, and Doyon 19 was moved to CD3 to maximize time at GD3 during the winter drilling season. After moving Doyon 19 over the well, the tubing and associated completion equipment will be removed and the current openhole section will be lengthened approximately 4536' ` to the originally planned location. At the end of the work program the well will be shut in awaiting surface connection and will b e put on production during pad startup, Q4 2006. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Vern Johnson at 907-265-6081. ly ~~~~~ ~~ Vern Johnson Drilling Engineer • Attachments cc: CD4-318A Well File /Sharon Allsup Drake Chip Alvord Vern Johnsonr Tim Schneider Doug Knock Lanston Chin • ATO 1530 ATO 1700 ATO 1702/1704 ATO 1768 ATO 1756/1752 Anadarko -Houston Kuukpik Corporation ,zv~ - /13 ~_~ • Subject: [Fwd: Re: Returning to CD4-318] From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Wed, 26 Jul 2006 07:33:19 -0800 To: Chip Alvord <Chip.Alvord@conocophillips.com> CC: Vern Johnson <Vern.Johnson@conocophillips.com>, Brian Ncel <Brian.Ncel@conocophillips.com>, Steve Davies <steve_davies@admin.state.ak.us>, Steve McMains <steve_mcmains@admin.state.ak.us> Chip,Vern and Brian, I left a message for Liz yesterday about this. Wanted to make sure it didn't get missed. Steve Davies and I looked at the file and it is our assessment that a new permit for CD4-318A needs to be submitted. According to the 407, the well was reported completed and there was cleanup production reported. This is similar to CD2-17 and CD2-17A, although you didn't drill as far. Are your plans to pull the completion and then just go in and drill on or will you be setting some cement or a retainer? If you are just going to drill on, then a sundry won't be necessary. CD4-318 can be administratively abandoned. If there is some "plugging" planned, then a sundry is necessary. The pull completion work can be authorized with the new permit to drill. Call or message with any questions. Tom Maunder, PE AOGCC -------- Original Message -------- Subject:Re: Returning to CD4-318 Date:Tue, 25 Ju12006 13:29:53 -0800 From:Thomas Maunder <tom maunderna,admin.state.ak.us> Organization:State of Alaska To:Galiunas, Elizabeth C <Elizabeth.C.Galiunas ti conocophillips.com> References:<21AB430C00045B46A94FSCSD9465EB3EOF0512(c~ancexmb2.conoco.net> Liz, I remember difficulties being encountered and I have some notes about calls from Vern. I cannot fmd any emails regarding the matter. Is it you all's intent to pull the "guts and feathers" and then drill on to the original BHL? I looked at the file and a 407 was received on June 7 with the well listed as a completed oil well. I have to do some checking, but since the well has been reported as completed with some production as well, it may be that CP will have to apply for a new drilling permit as CD4-318A. Tom Maunder, PE AOGCC Galiunas, Elizabeth C wrote, On 7/24/2006 4:37 PM: Hi, Tom. I wanted to update you on re-entering CD4-318. This well was suspended in January this year due to having hole problems right out of the 7" shoe and losing the cones off our insert bit. Also we were in a hurry to get on the ice road to CD3. We should be moving the rig to CD4-318 early next week. Let me know if there is anything we need to do from here. Hope all is well, Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907}265-6247 Cell: (907)-441-4871 • • • CJ TRANSMITTAL LETTER CH2ECQK/L~IST WELL NAME ~~u- ~~ ~~JIU~y PTD# ~~p " ~ l 3 Development Service Ex lorato Strati ra h' p ry g p is Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing we l1 (If last two digits in permit No. API No. 50- - - API number are , between 60-69) ~ Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of welly until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company NameZmust contact the Commission to obtain advance approval of such water well testing rogram. Rev: 1 /25/06 C:\jody\transmittal checklist ~ ~ ^fJ y ~ n O L ~ ~ = C ~ ~ O ~ ~ O 7 ~ N Z ~ L i N, n i a U, a c .3 ~ 0 ~ o ~ c r c m ~, ~; ~: ~ a t M d ~ N ~ ~ m 0 • 3 3 c o> o ~ ~. - o. Q N 'm c ~ ~ ~ u~ ~ U i : . ~ : c U Qy m o - ~ N ° ° ~ ~ O c, ~ 3: • as 2. 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To improve the readability of the Well History file and to simplify finding infom~ation, infom~ation of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made 1o chronologically organize this category of information. Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Sep 15 13:47:42 2006 Reel Header Service name .............LISTPE Date .....................06/09/15 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/09/15 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Colville River Nanuq Kuparuk MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA Scientific Technical Services Scientific Technical Services CD4-318A 501032051901 ConocoPhillips Alaska Inc Sperry Drilling Services 15-SEP-06 MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: W-0004123605 W-0004123605 W-0004123605 LOGGING ENGINEER: RICHARDSON RICHARDSON E. QUAM OPERATOR WITNESS: D. LUTRICK D. LUTRICK D. BURLEY MWD RUN 4 JOB NUMBER: W-0004123605 LOGGING ENGINEER: E. QUAM OPERATOR WITNESS: D. BURLEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE ao~-~~t3 24 11N 4E 2312 400 55.90 19.60 CASING DRILLERS ~ I Sll ~l BIT S~ (IN) 1ST STRING 8.750 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: SIZE (IN) DEPTH (FT) 9.625 3485.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS EFFECTED BY DRILLING OFF OF A CEMENT PLUG, THE TOP OF WHICH WAS AT THE 9 5/8" CASING SHOE (3485'MD/2374'TVD) IN THE CD4-318 PB1 WELLBORE. THIS WELLBORE IS A REDRILL OF THE ENTIRE INTERMEDIATE SECTION OF CD4-318/CD4-318 PB1. 4. MWD RUNS 1-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) GEOPILOT ROTARY-STEERABLE BHA (GP) WAS ALSO INCLUDED ON MWD RUNS 2,3. 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1-4 REPRESENT WELL CD4-318A WITH API#: 50-103-20519-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15711'MD/7238'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/09/15 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD ~ Depth shifted and clippe urves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 3484.5 RPD 3486.0 RPS 3486.0 RPM 3486.0 FET 3486.0 RPX 3486.0 ROP 3525.5 all bit runs merged. STOP DEPTH 15670.5 15662.5 15662.5 15662.5 15662.5 15662.5 15711.0 • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 1 3484.5 2 6894.0 3 13940.0 4 15274.0 REMARKS: MERGED MAIN PASS. MERGE BASE 6894.0 13940.0 15274.0 15711.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3484.5 15711 9597.75 24454 3484.5 15711 RPD MWD OHMM 0.64 2000 13.4405 24354 3486 15662.5 RPM MWD OHMM 0.67 1743.45 9.40937 24354 3486 15662.5 RPS MWD OHMM 1 1914.99 6.94608 24354 3486 15662.5 RPX MWD OHMM 1.11 1740.2 6.61196 24354 3486 15662.5 FET MWD HOUR 0.2 36.74 0.92248 24354 3486 15662.5 GR MWD API 40.11 401.13 112.751 24373 3484.5 15670.5 ROP MWD FT/H 0.02 279.65 152.833 24372 3525.5 15711 First Reading For Entire File..........3484.5 Last Reading For Entire Fil~.........15711 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/09/15 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/09/15 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3484.5 6853.0 RPD 3486.0 6845.5 RPM 34$6.0 6845.5 RPX 3486.0 6845.5 RPS 3486.0 6845.5 FET 3486.0 6845.5 ROP 3525.5 6894.0 LOG HEADER DATA DATE LOGGED: 19-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6894.0 TOP LOG INTERVAL (FT) 3485.0 BOTTOM LOG INTERVAL (FT) 6894.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 60.8 MAXIMUM ANGLE: 66.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.750 3485.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 • Fresh Water Gel 9.60 34.0 8.8 3900 1.0 .500 71.0 .340 113.0 .290 71.0 .780 71.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWDO10 OHMM 4 1 68 4 2 RPM MWDO10 OHMM 4 1 68 8 3 RPS MWDO10 OHMM 4 1 68 12 4 RPX MWDO10 OHMM 4 1 68 16 5 FET MWDO10 HOUR 4 1 68 20 6 GR MWDO10 API 4 1 68 24 7 ROP MWDO10 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3484.5 6894 5189.25 6820 3484.5 6894 RPD MWDO10 OHMM 0.64 1874.16 6.49719 6720 3486 6845.5 RPM MWDO10 OHMM 0.67 495.97 5.30312 6720 3486 6845.5 RPS MWDO10 OHMM 1 1914.99 5.51564 6720 3486 6845.5 RPX MWDO10 OHMM 1.11 1740.2 5.3351 6720 3486 6845.5 FET MWDO10 HOUR 0.21 6.46 0.642615 6720 3486 6845.5 GR MWDO10 API 54.13 185.68 123.288 6738 3484.5 6853 ROP MWDO10 FT/H 0.49 279.65 152.23 6738 3525.5 6894 First Reading For Entire File..........3484.5 Last Reading For Entire File...........6894 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation....../09/15 • Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/09/15 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 6846.0 13894.0 FET 6846.0 13894.0 RPM 6846.0 13894.0 RPD 6846.0 13894.0 RPS 6846.0 13894.0 GR 6853.5 13901.5 ROP 6894.5 13940.0 LOG HEADER DATA DATE LOGGED: 23-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 13940.0 TOP LOG INTERVAL (FT) 6894.0 BOTTOM LOG INTERVAL (FT) 13940.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 63.0 MAXIMUM ANGLE: 66.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 3485.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.80 MUD VISCOSITY (S) 37.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3) 7.0 ~ RESIST IVITY (OHMM) AT MPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.100 74.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.250 129.0 MUD FILTRATE AT MT: 1.700 74.0 MUD CAKE AT MT: 2.600 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6846 13940 10393 14189 6846 13940 RPD MWD020 OHMM 1.95 16.39 7.43883 14097 6846 13894 RPM MWD020 OHMM 1.81 19.37 7.35721 14097 6846 13894 RPS MWD020 OHMM 1.81 18.37 7.20792 14097 6846 13894 RPX MWD020 OHMM 2.86 23.27 7.06746 14097 6846 13894 FET MWD020 HOUR 0.2 22.72 0.578554 14097 6846 13894 GR MWD020 API 50.34 159.56 99.7176 14097 6853.5 13901.5 ROP MWD020 FT/H 6.49 271.55 167.246 14092 6894.5 13940 First Reading For Entire File..........6846 Last Reading For Entire File...........13940 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/09/15 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/09/15 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 13894.5 15229.0 FET 13894.5 15229.0 RPM 13894.5 15229.0 RPX 13894.5 15229.0 RPD 13894.5 15229.0 GR 13902.0 15236.5 ROP 13940.5 15274.0 LOG HEADER DATA DATE LOGGED: 25-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 15274.0 TOP LOG INTERVAL (FT) 13940.0 BOTTOM LOG INTERVAL (FT) 15274.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 63.6 MAXIMUM ANGLE: 83.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.750 3485.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Fresh Water Gel 10.00 42.0 9.2 450 6.8 1.400 68.0 .720 138.0 1.200 6$.0 2.000 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13894.5 15274 14584.3 2760 13894.5 15274 RPD MWD030 OHMM 4.1 90.4 8.69874 2670 13894.5 15229 RPM MWD030 OHMM 3.81 81.81 8.61205 2670 13894.5 15229 RPS MWD030 OHMM 3.46 19.96 6.38038 2670 13894.5 15229 RPX MWD030 OHMM 3.16 14.34 5.66894 2670 13894.5 15229 FET MWD030 HOUR 0.32 36.1 1.8874 2670 13894.5 15229 GR MWD030 API 71.49 401.13 158.471 2670 13902 15236.5 ROP MWD030 FT/H 0.02 185 106.391 2668 13940.5 15274 First Reading For Entire File..........13894.5 Last Reading For Entire File...........15274 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/09/15 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/09/15 Maximum Physical Record.~535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 15229.5 15662.5 RPX 15229.5 15662.5 RPS 15229.5 15662.5 RPD 15229.5 15662.5 FET 15229.5 15662.5 GR 15237.0 15670.5 ROP 15274.5 15711.0 LOG HEADER DATA DATE LOGGED: 27-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 15711.0 TOP LOG INTERVAL (FT) 15274.0 BOTTOM LOG INTERVAL (FT) 15711.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 82.6 MAXIMUM ANGLE: 94.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.750 3485.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Fresh Water Gel 10.20 44.0 9.2 400 5.6 1.420 68.0 .660 153.0 1.600 68.0 .880 68.0 REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel i DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 15229.5 15711 15470.3 964 15229.5 15711 RPD MWD040 OHMM 2.64 2000 179.443 867 15229.5 15662.5 RPM MWD040 OHMM 2.77 1743.45 77.0589 867 15229.5 15662.5 RPS MWD040 OHMM 2.49 127.54 15.5179 867 15229.5 15662.5 RPX MWD040 OHMM 2.27 96.06 12.0064 867 15229.5 15662.5 FET MWD040 HOUR 0.51 36.74 5.71219 867 15229.5 15662.5 GR MWD040 API 40.11 155.69 101.984 868 15237 15670.5 ROP MWD040 FT/H 0.53 251.9 66.8566 874 15274.5 15711 First Reading For Entire File..........15229.5 Last Reading For Entire File...........15711 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/09/15 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/09/15 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/09/15 Origin ..................~5 • Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
