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207-094
1 Regg, James B (OGC) From:NSK DHD Field Supervisor <n2238@conocophillips.com> Sent:Tuesday, June 13, 2023 7:37 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:WNS Integrity Subject:CPAI 10-426 form for Non-witnessed shut in tests on CD4-213, 306, 322 and 594 on 6/13/23 Attachments:MIT CRU CD4-213,306,322 & 594 SI TESTS 06-13-23.xlsx Please see the attached 10‐426 form for Non‐witnessed shut in MIT‐IA’s that were performed at CD4 pad on 6/13/23. Please let me know if you have any questions or concerns. Thank you, Shelby Sumrall / Bruce Richwine DHD Field Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659‐7022 Cell phone: (907) 943‐0167 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CRU CD4-306PTD 2070940 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2120050 Type Inj N Tubing 3 330 320 315 Type Test P Packer TVD 7291 BBL Pump 3.8 IA 3 3320 3260 3245 Interval 4 Test psi 1823 BBL Return 3.8 OA 89 98 98 98 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2070940 Type Inj N Tubing 295 400 410 405 Type Test P Packer TVD 6898 BBL Pump 2.7 IA 90 3300 3200 3180 Interval 4 Test psi 1725 BBL Return 2.7 OA 0 0 0 0 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2071010 Type Inj N Tubing 280 575 605 605 Type Test P Packer TVD 7161 BBL Pump 4.5 IA 295 3300 3260 3255 Interval V Test psi 3000 BBL Return 4.4 OA 42 68 68 68 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2191150 Type Inj N Tubing 300 335 305 300 Type Test P Packer TVD 4007 BBL Pump 3.6 IA 365 2020 1950 1930 Interval 4 Test psi 1500 BBL Return 3.5 OA 291 314 314 313 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Alpine / CRU / CD4 PAD Miller 06/13/23 Notes:Tubing plug set at 11,931' MD. Notes: CD4-213B CD4-306 CD4-594 Notes: CD4-322 Notes:MITIA to maximum anticipated injection pressure per AIO 18C.005 Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2023-0613_MIT_CRU_CD4-pad_4wells jbr From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD4-306 (PTD# 207-094) on Injection Date:Thursday, October 28, 2021 3:12:49 PM From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Wednesday, October 27, 2021 2:00 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD4-306 (PTD# 207-094) on Injection Chris— An update on CRU injector CD4-306 (PTD# 207-094). The well completed its 30-day monitoring period without signs of problematic behavior in the OA. However, due to low injectivity to the reservoir, it was only able to be on injection for 14 days of the 30-day period. During this period, it did pass an AOGCC witnessed MITIA reported to you earlier. Because of the difficulty achieving reservoir injectivity, we are decisioning a path forward on the possibility of an AA for continued injection. The well will remain shut-in while we determine the proper avenue for this well, and submit paperwork at a later date if necessary. Please let me know if you have any questions or disagree with the plan. Travis From: Smith, Travis T Sent: Friday, September 17, 2021 11:32 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD4-306 (PTD# 207-094) on Injection Chris— CRU injector CD4-306 (PTD# 207-094) has returned to water injection. This well has been shut-in for a period of time for reservoir management reasons but at this point our intent is to return to the plan outlined in our correspondence on 4/29/2020. The well has a deep surface casing leak that cannot be fixed with a surface casing excavation. A surface casing shoe was pumped in 2020 and the well has not been on injection since. Our intended path forward is to place the well on a 30-day monitoring period to verify that the OA pressure is stable post-cementing. During this time we will perform an AOGCC-witnessed MIT-IA. If no problematic behavior is seen during the monitoring period, we will submit paperwork for an AA asking for water-only injection with a known surface casing leak. MEMORANDUM TO: Jim Regg P.I. Supervisor l FROM: Austin McLeod Petroleum Inspector I Well Name COLVILLE RIV CD4 -306 Insp Num: mitSAM210925205915 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, October 4, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhitlips Alaska, Inc - C134 -306 COLVILLE RIV C134-306 Src: Inspector Reviewed By- P.I. Supry J Comm API Well Number 50-103-20550-00-00 Inspector Name' Austin McLeod Permit Number: 207-094-0 Inspection Date: 9/25/2021 -- Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min -- --- - -- Well CD4-306TYPe IoJ w TVD 6898 Tubing 2685 - --- - - -- 2675 2790 2795 - PTD 2070940 'Type Test; SPT'", p IA 640 4190 4140- 4130 " YP Test psi 1 na � i- -- _ - - �-- ` - - -- p 3.z OA - --- s 5 BBL Pum ed: 3_z ,BBL Ret _- - - Interval avRTST :PIF P V Notes' MITIA. Operator opted to test to possible future gas injection psi Monday, October 4, 2021 Page 1 of 1 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Wednesday, September 22, 2021 7:16 AM To:AOGCC Records (CED sponsored) Subject:FW: CRU CD4-306 (PTD# 207-094) on Injection From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Friday, September 17, 2021 11:32 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD4‐306 (PTD# 207‐094) on Injection Chris— CRU injector CD4‐306 (PTD# 207‐094) has returned to water injection. This well has been shut‐in for a period of time for reservoir management reasons but at this point our intent is to return to the plan outlined in our correspondence on 4/29/2020. The well has a deep surface casing leak that cannot be fixed with a surface casing excavation. A surface casing shoe was pumped in 2020 and the well has not been on injection since. Our intended path forward is to place the well on a 30‐day monitoring period to verify that the OA pressure is stable post‐cementing. During this time we will perform an AOGCC‐witnessed MIT‐IA. If no problematic behavior is seen during the monitoring period, we will submit paperwork for an AA asking for water‐only injection with a known surface casing leak. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907‐670‐4014 Travis.T.Smith@conocophillips.com Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Wednesday, April 29, 2020 11:42 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: CRU CD4 -306 (PTD 207-094) Update Hi Chris, CPAI has recently completed pumping an OA cement shoe on CD4 -306 (PTD 207-094). This well has a known surface casing leak estimated to be below 70' and cannot be repaired via typical excavation. Our original intention was to progress administrative approval for continued water injection with the known surface casing leak; However the OA pressure would not remain stable in shut-in or online conditions, so we did not feel it was acceptable to waiver at that time. After pumping the OA cement shoe the OA pressure has stabilized and can now be bled to 0 psi with a passing draw down test. When operationally feasibly, CPAI intends to bring the well the well online to conduct a 30 -day monitor period to validate that the OA pressure remains within acceptable criteria to progress administrative approval for continued injection. If the outer annulus is unable to maintain a stable pressure the well will be shut in. Please let us know if you have any questions or disagree with this plan. Sincerely, Sara. CarUA&(f("k.+.w) /Stepha*l�PaCk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Thursday, June 27, 2019 11:22 AM To: chris.wallace@alaska.gov Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: RE: CRU CD4 -306 (PTD 207-094) Suspect OA Behavior Chris, I wanted to update you on the status of CD4 -306. We have confirmed a surface casing (SC) leak in CD4 -306. The leak is estimated to be below 70', therefore, it cannot be repaired with a typical excavation. The injector remains shut-in. CPAI plans to review the well to confirm it can be operated safely with a known SC leak, and if so, apply for administrative approval to inject water in the near future. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From: NSK Well Integrity Supv CPF3 and WNS Sent: Tuesday, lune 11, 2019 9:45 AM To: 'ch ris.waIlace @alaska.gov' <chris.waIlace @alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: CRU CD4 -306 (PTD 207-094) Suspect OA Behavior Chris, CRU CD4 -306 (PTD 207-094) is a shut-in injector that is exhibiting suspicious OA behavior. DHD will take a look at the OA and if diagnostics are necessary, we will pursue them. If an issue is identified, we will follow-up with you on the plan forward. If no issues are identified, we will continue to treat the well as a normal injector. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: 2. Operator Name: Senior Pet. Engineer: Senior Res. Engineer: CollapseBurstTVDLengthCasing Authorized Signature with date: Authorized Name: 5. Permit to Drill Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl measured true vertical Packer WINJ WAG Water-Bbl MD 15. Well Class after work: Exploratory Development Service Stratigraphic 16. Well Status after work: Oil Gas W DSPL a GSTOR GINJ SUSP SPLUG 5.070, 25.071, & 25.283) J G Plug Perforations Fracture Stimulate Pull TubingOperations shutdown Perforate Other Stimulate Alter Casing Change Approved Program Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory StratigraphicService 6. API Number: mber): 8. Well Name and Number: onic data per 20AAC25.071): 10. Field/Pool(s): ry: ured feet feet ticalfeet feet ured feet feet ticalfeet feet epth feet epth feet true vertical depth) d and true vertical depth) summary: lumes used and final pressure: tion: ion: CollapseBurstTVD 5. Permit to Drill Number: Size Gas-Mcf g Ju easu ed 4. W ell Class Before W ork: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl ue e ca W ater-Bbl MD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations ConocoPhillips Alaska, Inc. P.O. Box 100630, Anchorage, Alaska 99508 207-094 50-103-20550-00-00 ADL 380077, 380075 CD4-306 n/a Colville River Field / Alpine Oil Pool 10346 7253 n/a n/a 10250 7191 9794 6898 Conductor 80 16" 114 114 Surface 2690 9.625" 2727 2376 Intermediate 10302 7" 10336 7247 10113 to 10124 7102 to 7110 4.5" L-80 9915' MD 6975' TVD Baker S-3 Camco DB Nipple 9794', 2124' MD 6898', 1981' TVD 1727' MD to 2727' MD Pumped 57 bbls of 15.7ppg AS1 Cement, 5 bbls Freshwater, & 46 bbls Diesel. Final pressure = 1000 psi. ----- ----- 320-137Sara Carlisle Well Integrity & Compliance Specialist Sara Carlisle / Stephanie Pilch N2549@conocophillips.com 907-659-7126 OA Cement Shoe ✔ ✔ ✔✔ ✔ Digitally signed by Sara Carlisle DN: OU=Drilling & Wells, O=ConocoPhillips Alaska, CN=Sara Carlisle, E=sara.e.carlisle@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-04-29 11:02:30 Foxit PhantomPDF Version: 9.7.0 Sara Carlisle By Samantha Carlisle at 12:38 pm, Apr 29, 2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 29 April 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for pumping an outer annulus (OA) cement shoe on injector CRU CD4-306 (PTD 207-094). Please contact Stephanie Pilch or myself at 659-7126 if you have any questions. Sincerely, Sara Carlisle Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. !"#$ % & ! '( '( )* + #,-)./0 -+* ! " ! #$!" % " "123 % + %%& " 45+ '()** #56 7 )+$, $ +((* +7 ,')- ). , ' . $ */0!$0 ) $*/0!$0 (* 89 1 815 & % %%2 %%&2 )* ) ) 3 *4, '('+(5 3 (( %%2 " %%&2 + )( %% :; 56!# )(! .< 8 5= 7> *5* ? +7 ? 8 2 ! 8+((* ' ) ) 3*-'). )1,,4*'7 18 *) ) 3 3-8%,,4) )3))*( ' ' 7'44' ),9,,4*7 ,,4*'7)*)4*4 ) ) 3 )*3 3),,4*3' 7' 3' @ (9 3 43%%':1%%1 7 43%%':%1% >8 >8/>88 // 65 8 ).A 0 .'( 0 *4, 3 ) 1"!#@ * 03! );3! /0<=0> //0 <=0> ?0 )@/! "!!A ; 3! 3 6 '0 ! B;0< 3> C0 2 2 .-'4* 7)39 ))3 (.)** )3)*33'* 2 2 ') ' .1*.' 4 )4* 3-&)*)4' ' . ,,4*. * 3'*4,) ) 3 )* ,,4*'7D)(77)*- 3) ' )' 4 ) 3-,,4* ) 3 1 *. ,,4*'7 * 3-,) )3.* 7'44' 3- '),,4*'7 ) 3 1 *. D, 3''* 2 12 * 3'4*3' ,,4*7 <E >.* 3')*)4 ( , 31* *4' 3)3' , *) ) 3-3 *-').)** )*4' 494 ,*7' D*3'* 3 )** ) ) )3' ' 12 &2 * 'B)3' ' #')%)# */0!$0 3! A = 0F C! #0 '*' . '- ./*/0!$0 /*/0!$0 *4, + 7/!; 7/!;*/C3A 3<CC> )*)4 3) 3) E"0G 45%''#11 !-"1"')1) -#"1"?-%' #'? +7 BBBBBBBBBBBBBBBBBBBBBBB P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 CPAI Well Integrity & Compliance Specialist OA Draw Down Test: CD4-306 (PTD 207-094) 4/18/2020 OA DDT (PASS) x Initial T/I/O= SI 300/451/223. OA FL @ SF. No fluid in catch drum. Bled OA to 0+ psi in 10 min. SI to monitor for 60 min. Initial T/I/O= SI 300/444/0 15 min T/I/O= SI 300/451/0 30 min T/I/O= SI 300/451/0 45 min T/I/O= SI 300/451/0 60 min T/I/O= SI 300/451/0 Final T/I/O= SI 300/451/0 Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: SLM 10,126.0 2/10/2019 CD4-306 boehmbh Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: RESET VALVE, TAG 2/10/2019 CD4-306 boehmbh Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.01 Top (ftKB) 34.0 Set Depth (ftKB) 114.0 Set Depth (TVD) (… 114.0 Wt/Len (l… 84.00 Grade K-55 Top Connection Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 36.9 Set Depth (ftKB) 2,726.6 Set Depth (TVD) (… 2,376.3 Wt/Len (l… 40.00 Grade L-80 Top Connection BTC Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 34.7 Set Depth (ftKB) 10,336.2 Set Depth (TVD) (… 7,246.6 Wt/Len (l… 26.00 Grade L-80 Top Connection BTC Tubing Strings Tubing Description TUBING - Water INJ String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 31.6 Set Depth (ft… 9,914.6 Set Depth (TVD) (f… 6,974.9 Wt (lb/ft) 12.60 Grade L-80 Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 31.631.60.00 HANGER FMC TUBING HANGER 4.500 2,124.5 1,981.9 42.10 NIPPLE CAMCO DB LANDING NIPPLE 3.812 9,793.6 6,897.8 50.79 PACKER BAKER S-3 PACKER w/MILLOUT EXTENSION 3.875 9,858.4 6,938.9 50.40 NIPPLE HOWCO 'XN' NIPPLE NO GO 3.725 9,913.3 6,974.0 50.07 WLEG WIRELINE ENTRY GUIDE 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 2,124.0 1,981.5 42.09 VALVE 3.81 DB LOCK ON A-1 INJ VALVE (HRS-45)2/10/2019 1.240 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 10,113.0 10,124.0 7,102.4 7,109.5 7/28/2007 6.0 IPERF 2-7/8" PJ OMEGA Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 9,686.1 6,830.1 CAMCO KBG-2 1 GAS LIFT DMY ??0.000 0.0 7/25/2007 Notes: General & Safety End Date Annotation 12/4/2009 NOTE: View Schematic w/ Alaska Schematic9.0 DEVIATED, CD4-306, 3/25/2020 3:58:58 PM Vertical schematic (actual) INTERMEDIATE; 34.7- 10,336.2 IPERF; 10,113.0-10,124.0 WLEG; 9,913.3 NIPPLE; 9,858.4 PACKER; 9,793.6 GAS LIFT; 9,686.1 SURFACE; 36.9-2,726.6 NIPPLE; 2,124.5 VALVE; 2,124.0 CONDUCTOR; 34.0-114.0 HANGER; 31.6 WNS INJ KB-Grd (ft) 43.83 Rig Release Date 7/25/2007 CD4-306 ... TD Act Btm (ftKB) 10,346.0 Well Attributes Field Name NANUQ KUPARUK Wellbore API/UWI 501032055000 Wellbore Status INJ Max Angle & MD Incl (°) 53.79 MD (ftKB) 3,011.15 WELLNAME WELLBORE H2S (ppm)DateComment SSSV: WRDP Annotation Last WO: End Date 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): Casing Collapse Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: Perforation Depth MD (ft): TVD BurstMDLength Size Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): approval: Notify Commission so that a representative may witness Sundry Number: BOP Test Mechanical Integrity Test Location Clearanc e ection MIT Req'd? Yes No ption Required? Yes No Subsequent Form Required: COMMISSION USE ONLY Contact Name: Contact Email: Contact Phone: Date: e: certify that the foregoing is true and the procedure approved herein will not rom without prior written approval. gnature: me: Date for 15.W ell Status after proposed work: Operations:OIL WINJ WDSPL Suspended proval:Date:GAS WAG GSTOR SPLUG Representative:GINJ Op Shutdown Abandoned nts: Proposal Summary Wellbore schematic13.W ell Class after proposed work: ations Program BOP Sketch Exploratory Stratigraphic Development Servic e SSSV Type:Packers and SSSV MD (ft) and TVD (ft): pth MD (ft):Perforation Depth TVD (ft):Tubing Size:Tubing Grade: Tubing MD (ft): g CollapseTVD BurstMDLength Size D (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): PRESENT WELL CONDITION SUMMARY quest: Abandon Plug Perforations Fracture Stimulate Reppair Well Operations shutdown Suspend Perforate Other Stimulate Pulll Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp W ell Alter Cas Other: ___er Casing ________________ __ ame:4.Current Well Class:5.Perm it to Drill Number: Exploratory Development Stratigraphic Service 6.API Num ber: g:8. Well Name and Number: ation or Conservation Order governs well spac ing in this pool? perforations require a spacing exception?Yes No esignation (Lease Number):10.Field/Pool(s): Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. ConocoPhillips Alaska, Inc. P.O. Box 100360, Anchorage, Alaska 99510 207-094 50-103-20550-00 N/A CD4-306 ADL 380077,380075 Colville River Field / Nanuq Kuparuk Oil Pool 10346 7253 10250 7191 Conductor 80 16" 114' 114' Surface 2690 9.625" 2727' 2376' Intermediate 10302 7" 10336' 7247' 10113 to 10124 7102 to 7110 4.5"L-80 9915 Camco DB Nipple, Baker S-3 Packer Nipple 2124'MD/1981'TVD, PKR 9794'MD/6898'TVD 04/06/2020 Sara Carlisle Well Integrity & Compliance Specialist Digitally signed by Sara Carlisle DN: OU=Drilling & Wells, O=ConocoPhillips Alaska, CN=Sara Carlisle, E=sara.e.carlisle@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-03-27 17:01:57 Foxit PhantomPDF Version: 9.7.0 Sara Carlisle 3/27/2020 Sara Carlisle / Stephanie Pilch N2549@conocophillips.com 907-659-7126 ✔OA Cement Shoe ✔ ✔ ✔ ✔✔ ✔ 320-137 VTL 3/31/20 DSR-3/31/2020 10-404 CO 443C X SFD 3/31/2020 Alpine -00 '76Comm. Required? Yes No 4/1/2020 JLC 4/1/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 27 March 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well CRU CD4-306 (PTD 207-094) to pump an outer annulus (OA) cement shoe. Please contact Stephanie Pilch or myself at 659-7126 if you have any questions. Sincerely, Sara Carlisle Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. By Samantha Carlisle at 5:20 pm, Mar 27, 2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 CPAI Well Integrity & Compliance Specialist PROCEDURE FOR OUTER ANNULUS CEMENT SHOE CRU CD4-306 (PTD 207-094) ConocoPhillips Alaska, Inc., (CPAI) intends to pump a cement shoe in the outer annulus (OA) of Alpine injector CRU CD4-306 (PTD 207-094). The OA in this well is the annular void between the 7” casing and 9-5/8” casing and was utilized for annular injection until 2010. The annulus does not presently contain a cement shoe. CPAI is requesting to install a cement shoe to reduce the OA pressure from shallow formations. The outcome of reducing the OA pressure by pumping a cement shoe is to be able to apply for administrative approval to return the well to water-only injection with a known surface casing leak estimated to be deeper 70’ MD, which is too deep to repair via an excavation. With approval, the OA cement shoe will require the following general steps: 1. Pump cement design to place ~1000 ft linear shoe in the OA. 2. Displace cement with freeze protection fluids. 3. Wait on cement to cure. 4. OA drawdown test. 5. Submit 10-404 to AOGCC. known surface casing leak Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: SLM 10,126.0 2/10/2019 CD4-306 boehmbh Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: RESET VALVE, TAG 2/10/2019 CD4-306 boehmbh Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.01 Top (ftKB) 34.0 Set Depth (ftKB) 114.0 Set Depth (TVD) (… 114.0 Wt/Len (l… 84.00 Grade K-55 Top Connection Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 36.9 Set Depth (ftKB) 2,726.6 Set Depth (TVD) (… 2,376.3 Wt/Len (l… 40.00 Grade L-80 Top Connection BTC Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 34.7 Set Depth (ftKB) 10,336.2 Set Depth (TVD) (… 7,246.6 Wt/Len (l… 26.00 Grade L-80 Top Connection BTC Tubing Strings Tubing Description TUBING - Water INJ String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 31.6 Set Depth (ft… 9,914.6 Set Depth (TVD) (f… 6,974.9 Wt (lb/ft) 12.60 Grade L-80 Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 31.631.60.00 HANGER FMC TUBING HANGER 4.500 2,124.5 1,981.9 42.10 NIPPLE CAMCO DB LANDING NIPPLE 3.812 9,793.6 6,897.8 50.79 PACKER BAKER S-3 PACKER w/MILLOUT EXTENSION 3.875 9,858.4 6,938.9 50.40 NIPPLE HOWCO 'XN' NIPPLE NO GO 3.725 9,913.3 6,974.0 50.07 WLEG WIRELINE ENTRY GUIDE 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 2,124.0 1,981.5 42.09 VALVE 3.81 DB LOCK ON A-1 INJ VALVE (HRS-45)2/10/2019 1.240 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 10,113.0 10,124.0 7,102.4 7,109.5 7/28/2007 6.0 IPERF 2-7/8" PJ OMEGA Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 9,686.1 6,830.1 CAMCO KBG-2 1 GAS LIFT DMY ??0.000 0.0 7/25/2007 Notes: General & Safety End Date Annotation 12/4/2009 NOTE: View Schematic w/ Alaska Schematic9.0 DEVIATED, CD4-306, 3/25/2020 3:58:58 PM Vertical schematic (actual) INTERMEDIATE; 34.7- 10,336.2 IPERF; 10,113.0-10,124.0 WLEG; 9,913.3 NIPPLE; 9,858.4 PACKER; 9,793.6 GAS LIFT; 9,686.1 SURFACE; 36.9-2,726.6 NIPPLE; 2,124.5 VALVE; 2,124.0 CONDUCTOR; 34.0-114.0 HANGER; 31.6 WNS INJ KB-Grd (ft) 43.83 Rig Release Date 7/25/2007 CD4-306 ... TD Act Btm (ftKB) 10,346.0 Well Attributes Field Name NANUQ KUPARUK Wellbore API/UWI 501032055000 Wellbore Status INJ Max Angle & MD Incl (°) 53.79 MD (ftKB) 3,011.15 WELLNAME WELLBORE H2S (ppm)DateComment SSSV: WRDP Annotation Last WO: End Date Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Thursday, June 27, 2019 11:22 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: CRU CD4 -306 (PTD 207-094) Suspect OA Behavior Chris, I wanted to update you on the status of CD4 -306. We have confirmed a surface casing (SC) leak in CD4 -306. The leak is estimated to be below 70', therefore, it cannot be repaired with a typical excavation. The injector remains shut-in. CPAI plans to review the well to confirm it can be operated safely with a known SC leak, and if so, apply for administrative approval to inject water in the near future. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From: NSK Well Integrity Supv CPF3 and WNS Sent: Tuesday, June 11, 2019 9:45 AM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: CPA Wells Supt <nl030@conocophillips.com> Subject: CRU CD4 -306 (PTD 207-094) Suspect OA Behavior Chris, CRU CD4 -306 (PTD 207-094) is a shut-in injector that is exhibiting suspicious OA behavior. DHD will take a look at the OA and if diagnostics are necessary, we will pursue them. If an issue is identified, we will follow-up with you on the plan forward. If no issues are identified, we will continue to treat the well as a normal injector. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 Wallace, Chris D (CED) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Tuesday, June 11, 2019 9:45 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: CRU CD4 -306 (PTD 207-094) Suspect OA Behavior Chris, CRU CD4 -306 (PTD 207-094) is a shut-in injector that is exhibiting suspicious OA behavior. DHD will take a look at the OA and if diagnostics are necessary, we will pursue them. If an issue is identified, we will follow-up with you on the plan forward. If no issues are identified, we will continue to treat the well as a normal injector. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,June 16,2015 P.I.Supervisor I`'4cc 6(17(1 5 SUBJECT: Mechanical Integrity Tests 1 CONOCOPHILLIPS ALASKA INC CD4-306 FROM: Johnnie Hill COLVILLE RIV NAN-K CD4-306 Petroleum Inspector Src: Inspector Reviewed By: P.1.Suprv, NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-K CD4-306 API Well Number 50-103-20550-00-00 Inspector Name: Johnnie Hill Permit Number: 207-094-0 Inspection Date: 6/12/2015 Insp Num: miJWH150613153907 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well1 CD4-306 FType Inj ''- TVD 6898 'Tubing 1824 - 1835 - 1825 - 1823 - PTD' Type 2070940 Test SPT Test psi 1724 L IA 1182 2808 - 2771 - 2763 Interval 4YRTST — — Pf' P ✓ OA 608 , 749 - 738 738 Notes: 2 bbls diesel • 0 r (1x �J1: Tuesday,June 16,2015 Page 1 of 1 ~ , ~~~ ~ ~~~~~~ ~~~ ~~~~~~ ~~~~ ~~~~ ~ ~ Org-an;zing ~aone, 12ES AN Color Items: ^ Greyscale items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria Project Proo~ng BY: ~. Maria _ Scanning Preparation BY: Maria Production Scanning •/ i ~ ~_ x 30 =~+ I d = TOTAL PAGES~ (Count does not include cover sheet) ~ Date: ~ ~S~ IIIII'IIII~III I~II) Stage 1 Page Count from Scanned File: ~(Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: q~ S l ~~ ~S~ ~ / ~ 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. II I(I II II I II ~) I I III ReScanned II I II'I II I I III I I(II BY: Maria Date: ~S~ Comments about this file: Quality Checked III II II~I ~II II~I ~II ^ Two-sided I~~ ~~'~II ~I lO~ ~I I~I D6GITAL DATA Diskettes, No.' ^ Other, No/Type: ^ Rescan Needed I) I II'I II I~ ( I III III Ol1EFtSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: Date: Date: ~s~ ~i v l~ I III II'IIII~III IIIII /s/ ~- ~ 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service 0 6. Permit to Drill Number: 207 -094 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD4 -306 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG 0 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ E WDSPL ❑ 50 -103- 20550 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation ❑ or Final El 310 -142 5/21/2010 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): 27763* 200 377 28340 28 9/10/2007 10/21/2007 CD4 -07, CD4 -307, CD4 -304 2010 / 2nd 4846 100 0 4946 6 6/25/2010 6/30/2010 CD4 -23 2010 / 3rd 20245 100 0 20345 29 7/1/2010 9/19/2010 CD4 -23, CD4 -12, CD4 -25 2010/ 13269 100 0 13369 14 10/14/2010 11/21/2010 CD4 -25, CD4 -298 2011 / 1st 0 0 0 0 0 2011 / 2nd 0 0 0 0 0 Total Ending Report is due on the 20th • Volume 66123 500 377 67000 77 (bbls): of the month following the final month of the quarter. Ex: ' April 20 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): * . < :: , • ` ( 4 JUL 1 2O1 *volume from previous sundry #307 -258 I hereby certify that the foregoing is tr and correct to the best of my knowledge. ry / �l� /� , Signature: C.. lilt/\ atecz ( ti y7 Printed Name: G. L. Alvord Title: Alaska Drilling Manager ie„ . Phone Number: (907) 265 -6120 s Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 05, 2011 TO: Jim Regg P.I. Supervisor i, 7 14 I ( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4 -306 FROM: Matt Herrera COLVILLE RIV NAN -K CD4 -306 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv\P-- NON Comm Well Name: COLVILLE RIV NAN - K CD4 - 306 API Well Number: 50 103 - 20550 - 00 - 00 Inspector Name: Matt Herrera Insp Num: mitMFHl10701085153 Permit Number: 207 - 094 - Inspection Date: 6/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD4 -306 "Type Inj. N ' TVD 6898 ' IA 320 1 3100 - 3060 1 3045 -- 1 2 070940 ' I SPT P.T.DI T ype T es t Test psi 1724 ' OA 750 897 879 872 Interval 'WPM P /F, P - Tubing 2347 i 2320 2320 2320 Notes: IA tested to 3100 psi 3.6 BBL's Well was shut in and freeze protected due to lack of injectivity. v F4.�:;t r t. 2 0 i Tuesday, July 05, 2011 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service el 6. Permit to Drill Number: 207 -094 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD4 -306 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ IN WDSPL ❑ 50-103-20550 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: a Field: Initial Disposal ❑ or Continuation MI or Final ❑ 310 -142 5/21/2010 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbis): 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 tatas {bbls }: 27763* 200 377 28340 28 9/10/2007 10/21/2007 CD4 -07, CD4 -307, CD4 -304 2010 / 2nd 4846 100 0 4946 6 6/25/2010 6/30/2010 CD4 -23 2010 / 3rd 20245 100 0 20345 29 7/1/2010 9/19/2010 CD4 -23, CD4 -12, CD4 -25 201014th 13269 100 0 13369 14 10/14/2010 11/21/2010 CD4 -25, CD4 -298 2011 / 1st 0 0 0 0 0 Total Ending Report is due on the 24th • Volume 66123 500 377 67000 77 o f the month following the final month of the quarter. Ex: (bbls): � Q` April 20 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) El fourth quarter. 12. Remarks and Approved Substances tdt Description(s): "volume from previous sundry #307 -258 1 hereby certify that the foregoing is rue and correct to the best of my knowledge, Signature: '604k,_ Date: 4-(41./,t, Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • • • Slialf[E a[F A[LASEKKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Tim Schneider WNS Staff Production Engineer ConocoPhillips Alaska, Inc. a017-0 P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD4 -306 Sundry Number: 311 -043 , FE13 2 2011 Dear Mr. Schneider: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ?/". Daniel T. Seamount, Jr. Chair DATED thi day of February, 2011. Encl. . STATE OF ALASKA ( Et V . ALAS•IL AND GAS CONSERVATION COMMISS• , ill J APPLICATION FOR SUNDRY APPROVAL 9 . FEE P 01a lic 20AAC25.280 , .2.,. -I► 1. Type of Request: Abandon r Plug for RedriH r Perforate New Pool r Repairwell r " • . • ' . p a . e d ' o •ra f t s { Suspend r Plug Perforations r Perforate r Pull Tubing r ' amgvaion r Operational Shutdow n r Re -enter Susp. Well r Stimulate p ' Alter casing ("` Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory fl 207 -094 ` 3. Address: 6. API Number: Stratg " raphic Service Jai • P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20550 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No gr , CD4 -306 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 380077, 380075 Colville River Field / Nanuq Kuparuk 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): 10346 • 7253 • 10250' 7191' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 114' 114' SURFACE 2690 9 -5/8" 2727' 2376' INTERMEDIATE 10302 7" 10336' 7247' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10113'- 10124' 7102' -7110' 4.5 L - 9915 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER S -3 PACKER W /MILLOUT EXTENSION MD= 9794 TVD= 6898 CAMCO 'DB' NIPPLE MD= 2124 TVD= 1981 12. Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program BOP Sketch r Exploratory Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/282011 Oil r Gas r WDSPL r Suspended fl 16. Verbal Approval: Date: WINJ Fi , GINJ j WAG E Abandoned Commission Representative: GSTOR r SPLUG 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Schneider © 265 - 6859 Printed Name Tim Schneider Title: WNS Production Engineer Signature 1.4",e4,, .e. Phone: 265 -6859 Date 2_ /Z -/ /• Commission Use Only Sundry Number:: \ ly ` t (, Conditions of approval: Notify Commission so that a representative may witness 1 v Plug Integrity " BOP Test r Mechanical Integrity Test r Location Clearance Other: Subsequent Form Required: /, , g o / � APPROVED BY vie Approved b // COMMISSIONER THE COMMISSION Date: 1 Form 10 -40 -'.: $'2 2' 5 2011 r�,g o -2 •/ / Submit in Duplicate RIGINAL % -. • WNS • CD4 -306 A i i Ct'�t'1C)Ci'3P1lll! r Well Attributes Max Angle & MD 1 Alaska Inc - ; Wellborn APUUWI Field Name Well Status Inc! 1') IMD (ftKB) (Act Btm (f1KB) t.4x1xs,,,,,,PS';. 501032055000 NANUQ KUPARUK INJ 53.79 3,011 15 10.346.0 "' Comrnent /125 (ppm) I Date 'Annotation End Date KB - Grd (ft) Rig Release Date SSSV WRDP Last WO 1 43.83 Well (0000: DEVIATED (0430012 /4/200950656 AM : 7/25201)7 Schematic Actual Annotation Depth (ftKB) I End Date (Annotation Last Mod ._ End Date Last Tag_ I Rev Reason: QC TALLIES Imosbor 12/4/2009 Casin • Strin • s Casing Description String 0. 'String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String -.. String Top Thrd CONDUCTOR 16 I 15.010 34 0 114.0 114 0 84 00 K r ,,.. Casing Description String 0 'String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd e 'm SURFACE 95/8 8.835 36.9 2,726.6 2,376.3 40.00 L B1C HANGER, 32 ; j p Casing Description String 0... String ID - _ Top (ftKB) Set Depth (f... Set Depth (ND) .. String Wt... String String Top Thrd INTERMEDIATE / 6.276 34.7 10,336.2 7,246 6 26.00 L-80 Bl C .' Tubing Strings ' Y- r Tubing Description String O . .String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) .. (String WI... . String ... String Top Thrd TUBING - Water INJ 4 1/2 3.958 ` 31 6 9,914.6 I 6,9/4.7 12 -60 L-80 Completion Details Top Depth r. (TVD) Top Inc' N '... '' Top (ftKB) (ftKB) P KB) C) Item Description _., Comment ID (in) 31.6 31.6 -0.05 HANGER FMC TUBING HANGER 4.500 2,124.5 1,981.6 42.10 NIPPLE CAMCO DB LANDING NIPPLE 3.812 1k 0 co„, /lr,8SA!I'11t ',, ':. J 9,793.6 6,897.8 50.79 PACKER BAKER S-3 PACKER w /MILLOUT EXTENSION 3.875 .'. 9,858.4 6,938.9 50.40 NIPPLE HOWCO'XN' NIPPLE NO GO 3.725 CONDUCTOR, 1 ` 9.913.3 (,973.8 49.53 — ' — -- W `, ` WLEG WIRELINE ENTRY GUIDE 3.958 3a -114 .k Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) - Top Depth' u (TVD) Top Inc! Top (ftKB) (ftKB) (1 Description Comment Run Date ID (in) VALVE, 2,1za - - - 2,124 1,981 2 42.09 VALVE A - 1 INJECTION VALVE (HWS 8/15/2007 1.240 NIPPLE, 2,125 — Ilta Perforations & Slots :' Shot Top (TVD) Btm (TVD) Dens T op (ftKB) Btm (ftKB) (ftKB) (ftKB) ,.- - Zone Date l h Type Comment - - °` 10,113 10,124 7,102.4 7,109.5 7!28/2007 6.0 IPERF 2 -7/8" PJ OMEGA Notes: General & Safety End Date Annotati n : 12/4/2009 (NOTE VIEW SCHEMATIC w /Alaska Schemahc9 0 111 11. SURFACE, _ .. _... _ —._. 37 -2,727 .714 1 1 1 1 1 11' el n. , GAS ,6 LIFT,_ 986 1 , I I I 11 'I1 PACKER, 9,794 NIPPLE, 9,858 — W 2- W WLEG, 9,913— P ' ' Mandrel Details Top Depth Top Port (ND) Inc' OD Valve Latch Size TRO Run 10,1131- 10,124 ._ PE RF,_ 1111' Stn Top (ftKB) (ftKB) (1 Make Model (in) Sery Type Type On) (PS) Run Data Com... - - -- 2 - -- 1 9,686.1 6,8306 51.43 CAMCO KBG -2 1 GAS LIFT DMY vz 0.000 0 0 7/25/2007 1 VTERMEDIATE, 35- 10,336 TD, 10,346 • Overview: A high pressure breakdown is proposed for the CD4 -306 Nanuq - Kuparuk slant injector to improve injectivity to support the offset oil production. Procedure: 1. MIRU nine clean insulated frac tanks with a berm surrounding the tanks that holds the tank volume plus 10 %. Load tanks with seawater from the injection system (approximately 4500 bbls are required for the treatment) 2. Rig up Schlumberger equipment along with a ball launcher in the line. 3. Install tree saver, lower stinger and set. 4. Pressure test surface lines to 9500 psi 5. Pump the following schedule at 30-40 BPM with a maximum pressure of 6000 psi, Maintain 3000 psi on the IA during the treatment. Do not exceed 6000 psi treating pressure. a. 1000 bbls slick seawater b. Drop 20 bio -balls c. Repeat a & b two more times d. 1500 bbis slick water e. Flush with linear fluid and freeze protect ✓ Total Sand: 0 lbs. Total bio- balls: 60 Total slickwater: 4000 bbls. 6. Monitor the surface pressure fall -off at the end of the job for 30 min (or until closure is verified). 7. Rig down equipment, move off location. R~~~lVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL ~ ~1 ~, (:~ ;~ 2010 Alaska 0~1 ~ ~a~ C~:~. ~ornmissior~ 1. Operator: 4a. Well Class: Stratigraphic ^ Service ~ 6. Permit to Drill Number: 207-094 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-306 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ~ WDSPL ^ 50-103-20550-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^~ or Continuation ^ or Final ^ 310-142 5/21/2010 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 ~, / ~~ ~rB1!'t ~~ U t! fluids, formation fluids and E ~~~ r, ~, ,~ any necessary water added 27763* 200 377 28340 28 9/10/2007 10/21/2007 CD4-07 CD4-307 CD4-304 totais(bbls): , , 2010 / 2nd 4846 100 4946 6 6/25/2010 6/30/2010 CD4-23 2010 / 3rd 2010 / 4th 2011 / 1st Total Ending Report is due on the 20th volume 32609 300 377 33286 34 (obis): of the month following the final month of the quarter. Ex: April 20 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 Descriptions>: *volume from revious sund #307-258 I hereby certify that the foregoing is rue and correct to the best of my knowledge. Signature: - ~ Date: ?(~~2ot o Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA - - - ALASKA OlL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator. 4a. Well Class: Stratigraphic ^ Service Q 6. Permit to Drill Number. 207-094 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-306 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^ 8. API Number P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ~ WDSPL ^ 50-103-20550-00 3. (Check one box only) 5a. Sundry number. 5b. Sundry approval date: g. Field: ' ' Initial Disposal Q or Continuation ^ or Final ^ 307-258 - - ~~ 9/6/2007 ~ - 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 pft 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 ;~ ''~~~~; f fluids, formation fluids and ` 3 S;~ i~lr any necessary water _ _ r~~4+~". added ~.~!'-"~ Previous totals (bbls>: 357* - ...357 0 - - - . 2007 / 3rd 16494 100 20'` 16614 14 9/10/2007 9/23/2007 CD4-07, CD4-307 2007 / 4th 2008 / 1st 2008 / 2nd Total Ending volume 16494 100 377* 16971 14 Report is due on the 20th cbbis): of the month following the final month of the quarter. EX: A ril 20 for the first uarter J l 20 f th d p q , u y or e secon quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 far the Other (Explain) ^ - - -~ fourth quarter... 12. Remarks and Approved Substances - Description(s): "annular flush, freeze protect volumes and infectivity test I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ - Date: illwsb~ ~~~. ~mmission yy~~~~ jj Printed Name: Randy Thomas Tdle: Kuparuk Drilling Team Leader Pho~1~'IVumbe~~ (907) 265-6830 Form 101123 Rev. 212004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate R~~~1V~D STATE OF ALASKA ~ ~ ,~ ~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~t- REPORT OF ANNULAR DISPOSAL ~faska0el~tr~£~Rie"~;~~!1ASSi0fR E#Xit;f~~f ~>~ 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: 207-094 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-306 2. Address: 4b. Well Status: ~' Oil ^ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^~ WDSPL ^ 50-103-20550-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ~ or Continuation ^ or Final ^ 310-142 5/21/2010 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: q ~= ~~'~ cement-contaminated domestic waste water descriptions in block 12) disposal F~ ~) drilling mud, completion occurred f+'~r '~ ~'~~~ r~ ~ "° fluids, formation fluids and any necessary water added 28340* 28340 totals (bbls): 2010 / 2nd 4846 100 4946 6 6/25/2010 6/30/2010 CD4-23 2010 / 3rd 2010 / 4th 2011 / 1st Total Ending Report is due on the 20th volume 33186 100 33286 6 Ex: of the month following the final month of the quarter (bbls): . 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 Descriptions>: *volume from previous sund #307-258 to the best of my knowledge. I hereby certify that the foregoing is true and co rrec t ~ ~ f ~ f ~ ~ ~~ ~ 2 t ~~"°` D ~ - a e: Signature: ~ - Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 212004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ~`' ~~ ~~ ~. ~ ~_. Y` 4 ~ ~~ ~, MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet.Files\OLK9\Micro6lm_Marker.doc •- J • • Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 ~ ~~ Anchorage, AK 99510 - - Re: Colville River Field, Nanuq-Kuparuk Oil Pool, CD4-306 Sundry Number: 310-142 { ~ C~' . ,~ Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. 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. Sincerely, Daniel T. Seamount, Jr. Chair S~" DATED this? ~ day of May, 2010 Encl. ~~~ ~~ 5~ (~" ~~~'~ 5~"~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION i~EC~luEa APR 3 ~ 2010 ANNULAR DISPOSAL APPLICATION .iasfcaal&~~.i;,~mrniasiofr 20 AAC 25.080 ~ 3. Permit to Drill 1. Operator Name: Number: 207-094 ConocoPhillips Alaska 4. API Number: 50-103-20550-00 2. Address: 5. Well Alaska Anchorage Box 100360 P O CD4-306 , , . . 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: Nanuq 3, CD4-209, CD4-210, CD4-320, CD4-17, CD4-214, Torok and Seabee formation, shale, siltstone and sandstone CD4-211, CD4-215, CD4-16, CD4-05, CD4-304, CD4-07 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 1650' MD / 1600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: 28,340 bbls (10/22/2007 last injection) densities range from diesel to 12#/gal 2225 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 70,000 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, cement rinsate, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and other 24-Jun-10 substances that the commissioner determines on application are wastes associated with the act of drillin a well permited under 20 AAC 25.005. 17. Attachments: ~ FIT Records w/LOT Graph ^ uired) ^ (if re d L B Well Schematic (Include MD and TVD) q og on Cement Surf. Casing Cementing Data ^ Other ^ arevious authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ Title: ~~^/''. Printed Phone ' Name: Chip Alvord Lo f ° Number: 265-6120 Date: ~} 2~ Commission Use Onl C p~ ~; ~,n K ZOA'AG Z $. ~~ LOT review and approval: S-ZI-(O Conditions of approval: ~ / < d ~ yZ 3 ~jl (~ Approval number: /1 ~ ~ I 1 Subsequent form required: Approved by: ~~ APPROVED BY COMMISSIONER THE COMMISSION Date: S~ 4' ! I~ _ Form S Z,If~STRUCTIONS ON REVERSE Submit in pl a'iy 6~~0 _~`7. ~~ • Annulus Disposal Transmittal Form -Well CD4-306 A(lC,(''(" RPQnlatinnc 2~ AAC 25 nRA (hl 1 Desi ation of the well or wells to receive drillin wastes: CD4-306 2 The depth to the base of freshwater aquifers and permafrost, i 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 information sufficient to support a marine shales and claystones of the Albian Torok Formation commission fording 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/1. (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 70,000 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 at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2225 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 Previously submitted: cementing reports, LOT /FIT reports base of any freshwater aquifer and permafrost, if present, and 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 Previously submitted: 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 CD4-23, CD4-12, CD4-25, CD4-303 will be enerated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com liance would be im rudent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. • • Well CD4-306 Date 4/28/2010 d d .'7 L ou .~ U 0 0 0 ore`:::; Cr-> aa::: i;!~S3i;i;i v'', I',' ~~ ~ ... a 2,377 TVD Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Assumptions Maximum 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 Version 1.0-Jaa'OS Pburst85% - PHydrosta[ic +PApplied - PFormation 4,888 = ( 2,377 * 0.052 *MWmax ) + 1500 - (0.4337 * 2,377 ) MWmax = 35.7 PPg Surface Casing Stria Size 9.625 in Weight 40 ppf Grade L 80 rbursuoo°i 5,750 Psi Pburst85% 4,888 psi Depth of Shoe 2,377 ft FIT/LOT @ Shoe 18 ppg or 2,225 psi FIT/LOT for Annulus 14.9 ppg Max Surf. Pressure 1,500 psi TOC Est. @ 4,900' MD 3,760' TVD a.s "Tubing 7,462 TVD Maximum Fluid Density avoid Collapse. of 2nd Casing Stria Pcollapse85% - PHydrostatic +PApplied - PGasGradient - PHeader 4,599 = ( 3,760 * 0.052 * MW,,,~ ) + 1,500 - (0.0700 * 3,760) - 1,000 MWmax = 22.3 PPg 2nd Casing String Size 7 in Weight 26 ppf Grade L 80 1'collapse100% 5,410 psi Pcollapse85% 4,599 psl Top of Cement 3,760 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 (2,377 * •052 * 18 ) Pmax allowable- 2,225 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". SURFACE CASING SHOE SEPARATION FROM CD4-306 CD4-306 x v Surface Casin Shoe ASP 4 Coordinates NAD 27: 377262.19 5958093.22 rstance Ann. from Surface csg. Surface csg. Surface Details ~ Disp. Ann. Object Shoe X Shoe Y Surf LOT casing TVD Annular Wells AOGCC•` Permit # Permit Date Source well Vol. Start Date End Date well` Coord. Coord. ft LOT Comments CD4-05 746 377233.4 5957348.0 18.2 2388 16.5 Not for AD (too close to Nanuq 3) CD4-07 1,~ 563 376700.4 5958052.5 16.7 2396 15.4 CD4-16 ~,~ w;ii 911 376571.7 5957499.3 18.1 2388.5 17.90 Not for annular disposal, due to proximity to Nanuq 3 CD4-97 y , ~ 1215 376416.3 5957221.0 18.1 2386.93 16.2 Not for annular disposal, due to prowmity to anuq D4-318a, CD4-320, CD4-214, CD4-~o ~ 306-183 5130/2006 CD4-321,CD4-211 61839 7/3/2006 1!412007 1566 378134.12 5956792.58 16.3 2440.26. 14.4 volume extension to 70000 bbl, permit #306-266 CD4-2~ i5 ~_ 1015 377935.02 5957333.89 14.7 2376.79 17.5 Not for annular disposal CDA-210 ,:-- y. 1166 377547.47 5956963.14 18.0 2385.97 17.3 CD4-211 r„ ; y 306-392 12/29/2006 D4-302, CD4-t6 31937 6/20/2007 7/1112007 607 377354.32 5957492.92 18.1 2400.1 15.0 2nd annular LOT, 1st ann test@18.4 ppg Not for annular disposal. High Ann test Probably ice plug, CD4-213 1526 377441.38 5956577.89 18.1 2400.5 21.40 will retest if needed CD4-214 ~ + -gat. 1170 377016.49 5956949.56 17.3 2400.8 17.6 Not for annular disposal CD4-215 y,c°~` 1281 376762.06 5956914.11 17.6 2400.4 17.50 Not for annular disposal 307-257 / 9/6/2007 Extended volume to 70,000 {64,000 bbls) 5/20!2009, CD4.302 y 309-167 5/20/2009 CD4-304, CD4-OS 56647 10/21/2007 1N/2010 2105 379247.67 5957393.4 .18.1 2390.43 17.10 second ALOT was 15.5ppg 5!27!2009 CD4-304 223 377304.4 5957874.3 16.6 2391 17.8 Nol for Annular Disposal CD4-306'---- ~;- y 307-258 91612007 CD4-3 D4-07 28330 9!11/2007 10/2112007 0 377262.19 5958093.22 .18.0 2376.29 1-x.90 CD4-318 y 306-181 5/26/2006 D4-2 ,CD4-320 942 . 5/31/2006 812!2006 2109 376138.31 5956308.1.7 18.2 2375.32 17.1 Una le to pump- SD pumping CD4-208, D4-318, CD4-209, CD4-319 y 305-373 12!912005 CD4-320 32010 12/14/2005 7/2/2005 2304 377174.72 5955790.44 18.4 2396.47 16.1 CD4-320 v 653 377915.36 5958108.91 17.1 2387.33 17.8 Not for annular disposal CD4-321 y 306-393 112/2007 CD4-306, D4-322 31117 7/14/2007 8120!2007 1863 375795.28 5956945.38 18.0 2385.47 16.3 CD4-322 y 307-293 10!2512007 CD4-301, D4-05 30832 12/8/2007 1110!2008 1628 375674.64 .5957731.19 18.0 2385.44 16.8 Nanuk 1 n 1895 379124.4 5957742.68 1792 Exploration P8A'd Nanuk 2 n Exploration P&A'd - Exploration, X-Y location calculated at 2400' TVD, NOT Nanu 3~'"i~ :-. 744 377015.63 5957391.42 11.8 1774.97 the surface shoe de th Nanu 3 2400" T VD 1044 376499.3 5957380.8 To show roxirnit to Nanu 3 at 2400' TVD Nanu 5 2136 378326.61 5956241.68 14.9 2393.75 15.1 Not for annular dis osal. *"`Soon to be CD4-12 CD4-301 n 2515 379541.0 5957028.4 14.8 2387 13.5 Too low of Surf Test? CD4-24 n 1749 377294.0 5956344.0 16.2 2389 15.1 Too close to CD4-23 CD4-28 n 1421 376757.1 5956765.1 18.0 2384 17.2 Too close to CD4-23 CD4-25 tanned 1853 376858.9 5956285.1 Planned Well TBD CD4-23 tanned 1299 377140.8 5956799.5 2400 Planned Well TBD `Lateral distance in feet, between surface casing shoes, in the X-Y plane "As of April 21, 2008 Nnte That this sheet is not the definitive record for annular disposal volumes ConocoPhillips C D4-306 Quarter Mile View G~~ Zoj~ 1800 1200 ~_ O 0 co + 600 ~~.r L Z i~ L Q O a c z -600 -1200 -3000 Goa~b -240 Goe,-111 -1800 -1200 _ -600 Goa"V 0 West(-)/East(+) (600 ft/in) 600 1200 1800 N 0 O v WELLBORE TARGET DETAILS (MP.P CO-0RDINATES) Name NDSS +N/-S +E/-W Northing Easting ShapeNo wellbore target data is availabl ~1oB -- ~o~o G VOp 110 GOp. 1 O -.. ----- -. - G~R o°Q ~ i Go°'~ cO`~I -3aG CD4-304 -- ~ ~~ ~.. GD4 1 20pB N N M ~ V i U 6 -- - - 1 - _ QA• G eJ r t~ o - ~ - '° ~ ,~ ~ ~ ~ GQA•1'1 .. r ~ D4.301 e.- ~ I ~ -- -- ~ -- ~y y A G~ ~ CD4'3 ~ - ~ ,.x 8 3/4" G A 3018 p 115 Dp.21A GOQ 61 N - - - __ ~s 13 _ - - - ~ aqa -320 GD4 _ i • ConocoPhillips Alaska, Inc. Post Office Sox 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 Apri129, 2010 Alaska Oil and Gas Conservation Commission 333 West 7r'' Avenue, Suite 100 Anchorage, Alaska 99501-3539 ConocoPhillips Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD4-306 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that the annular disposal permit for CD4-306 (sundry permit # 307- 258) be re-permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. Because of the remote location and limited available annuli on CD4, it is requested that the volume limit described in 20-ACC 25.080 d. 1. be increased from 35,000 bbl to 70,000 bbl. The other wells not yet permitted for annular disposal are either in too close a proximity to explorations wells or are not good annular disposal candidates. This leaves us with the choice of re-permitting a previously used annular disposal well to increase the allowable injection volume. Of the wells on the CD4 pad previously used for annular disposal, CD4-306 is a strong candidate for increasing the allowable injection volume. Although it is possible to haul the drilling wastes to the Alpine disposal well, no environmental benefit would be realized and additional risks of spillage and vehicular accidents are possible. Injection pressure has typically been significantly below our original surface casing shoe test pressure. CD4-306 was last used for annular disposal on October 22, 2007 after injecting 28,340 bbls. Increasing the allowable disposal volume for CD4-306 will allow for time to drill more wells and potentially other candidates for annular disposal. For further details please reference the original annular disposal permit for CD4-306, approved on September 6, 2007. Attached is an updated plot showing all the wells within quarter mile of the surface shoe on CD4-306. All the information for these wells has previously been submitted to the AOGCC. Also attached is the updated annular disposal transmittal form. If you have any questions or require further information, please contact Nina Anderson at 265-6403 or Ryan Robertson at 265-6318; Chip Alvord can also be reached by calling 265-6120. Sincerely, ;'~ Y~, ~ ~, Nina Anderson Drilling Engineer cc: CD4-306 Well File Chip Alvord Sharon Allsup-Drake ATO-1570 ATO-1530 Note to File CD4-306 (207-094...310-142) Re-Permit Colville River Unit (Nanuq-Kuparuk) ConocoPhillips Alaska, Inc Phillips has made application for extending annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. The well was last used for annular disposal in Oct. 2007 and a total of 28,340 bbls was injected to that point Conoco requests the volume limit be increased from 35,000 bbls to 70,000 bbls. --Surface casing was cemented to surface. No problems were reported. Approximately 130 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 42% XS of the calculated hole volume. --On the initial leak off test from July 2007 the pressure slope rises exhibi#ing 2 slopes to the determined FIT point at 18.0 EMW. 2 slopes are not uncommon in CRU. Minimal fluid was pumped into the formations. During the observation period, the pressure declined to about 16.0 EMW. The initial leak off indicates that the surface casing shoe is well cemented. -- A follow-up infectivity test down the 95/8" X 7" annulus was conducted 5-21-2010 since the well annulus has sat dormant for an extended period. The Pump in test indicts a Leak off point of 16.1 ppg and declined t o 15.6 ppg EMW after pumping..... well below the shoe breakdown of 18.0 ppg. This is somewhat higher than the orginal pump -in test leak off of 14.9 ppg EMW but is acceptable. --No problems are reported drilling the intermediate hole. The 7" casing was run and successfully cemented. Full returns were noted and the casing was reciprocated. --An original) infectivity test down 9-5/8" x 7" annulus was conducted on 7/24107. Pressure steadily increases until the break at 14.9 EMW. The pressure declined with additional pumping to 14.2 EMW. During the observation period, the pressure declined to 13.2 EMW. The lower EMW of the pump in tests indicate that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA provided a listing of all surface casing shoes within %4 mile radius of CD4-306. The nearest well (CD4-304) is 223' distant with 2 other wells at 563' and 607' distant. The expected radius of injection is 125' for 70,000 bbls. Nanuq 3 is 1040' distant at 8 o'clock from the surface shoe. An examination of the cementing information for afl wells did not reveal any problem that would preclude granting CPA's request for CD4-306. Nanuq 3 is sufficiently distant that its uncemented annulus should not be of concern. Based on examination of the submitted information, 1 recommend approval of ConocoPhillips' request for the subject well. ~`"'~_ Guy S~iiartz Sr. Petroleum Engineer May 21, 2010 G:\AOGCC\Common\tommaunder\Well Information\By Subject\Annular Disposal\100520-- CD4-306.doc Page 1 of 1 Schwartz, Guy L (DOA) From: Anderson, Nina M [Nina.Anderson@conocophillips.com] Sent: Friday, May 21, 2010 9:00 AM To: Schwartz, Guy L (DOA) Cc: Robertson, Ryan G Subject: CD4-306 Attachments: CD4-306 Annular Injection Test for Permit Extension 05-21-10.x1s Guy - Attached is the leak off test data for CD4-306. Little Red pumped the test and the night company man was present to witness and record the data. The data shows the well leaked off higher (16.1 ppg) than the original LOT test (14.9 ppg), although still below the original surface casing test of 18.0 ppg. The annular space gradient was calculated using 50 bbls diesel freeze protect and the rest freshwater. The original test was performed with a full column of mud. Please let me know if you have any further questions. Thanks, Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907) 575-3256 5/21/2010 Well Name: CD4-306 Rig: Drilling Supervisor: Browning Type Of Test: ', Annulus Leak Off Test for Disposal Adequacy ' _ __. HOIe Size: USE PICK LIST I ~ CBSIn Shoe RKB-CHF: 34.7 Ft 2727,0_ Ft-MD 2: Casing Size and Description: ' usE PICK LIST Chan es for Annular Ade uac Test Enter outer casing shoe test results in comments Casing description references outer casing string. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing OD at right. PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Doyon 19 Date: 5/21 /2010 Volume In~pu Pump used: I' Other -See Comments ~ Barrels I, ~ ~ Pumping down annulus. ! ~ Cas ~ HOIe Depth Pumping Inner casing OD: Desired PIT EMW: Estimates for Test: ~ L, = Leak-off Pressure + Mud Weight = 1090 + 7.24 0.052 x TVD 0.052 x 2377 EMW at 2727 Ft-MD (2377 Ft-TVD) = 16.1 ~soo iooo w y N W G' a 500 Pum Rate: Bbls/Strk ~ 1.00',, Bbl/min ~ :st Pressure Inte ri Test Shut-in Pumpin Shut-in lin si Bbls si Min si 0 0 ~''J~; 0.00 1040 II 41 II 0.81 110011 1.501 9701 8 1.6 1050 3.50 9 '1.8 1040 4.00 10 2 1040 4.50 15 2.5 1040 5.00 20 3 1040 5.50 0~ a- ~ i I ~ 0 1 2 3 4 5 6 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Volume VOI ~^CASING TEST tLEAK-OFF TEST o PIT Point Pum ed Bled Back Pum ed Bled s s s ~: umped w/ Little Red ervices Unit Mud weight calculated with 50 bbls diesel freeze protect behind fresh water 9401 PP9 In. pP9 psi 0.8 bbls Summary Shut-in Pres: 1020 Note to File CRU CD4-306 (PTD 2070940) May 4, 2010 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD4-306 Request ConocoPhillips Alaska, Inc. (ConocoPhillips) requests approval to increase the volume limit of waste fluids injected into the 9-5/8" x 7" annulus of well CD4-306 from 35,000 barrels to 70,000 barrels. Recommendation Approve ConocoPhillips' request. Conclusions The 9-5/8" surface casing shoe is set in this well at about 2,727' (-2,320' true vertical depth subsea, or "TVDSS"), near the base of a 420-foot thick2 claystone, shale and siltstone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of silty sandstone and sandy siltstone open to the annulus surrounding the 7" casing within this well to accept the proposed injected fluids. 3. The lower confining claystone and shale strata are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed annular disposal activities will be limited to a radius of less than 125' from the wellbore. Discussion ConocoPhillips' application was reviewed along with records from nearby wells Nanuk 1, Nanuk 2, and Nanuq 3. The discussion that follows is based on well logs and mud logs from these wells. An index map is provided in Figure 1, below. The CD4-306 development well was drilled to the Nanuq Oil Pool within the CRU. ConocoPhillips, the operator, intends to dispose of drilling wastes utilizing an open annulus within CD4-306 that extends downward from the 9-5/8" surface casing shoe, which is set at about 2,727' (-2,320' TVDSS), to the top of the second stage cement for the 7" casing string, which is estimated to lie at about 4,824' (-3;653 TVDSS).3 This annulus lies within Section 24 of T11N, R4E, Umiat Meridian (see Figure 1). The annulus is located more than 2-1/2 miles from the current external boundary of the CRU. The section of annulus in CD4-306 that will most likely accept the injected waste fluids (most likely receptor interval) is a portion of the Seabee formation that extends from about 2,818' to 3,080' ' All depths herein represent measured depths unless otherwise specified. z All thicknesses represent true vertical thicknesses unless otherwise specified. s Top of cement estimate determined by AOGCC. i CD4-306 Note to File May 4, 2010 Page 2 of 7 t~ cnz-i6L1 ~~ratatb tzoaa ,\, ~~ 2GA7.~ 1J5{d ebb l"~10 i~d] ~ 5 -~ ir'q,7 ~`~ CD4 k~ 6 ~' %R~iN,Q 17975 1\ ~ 5o zn~ ~ ~ Q-~ ,,,~ 020 i ~~"`y`~ Nanuq 3 Q s:L l nsF ~~{ '[061110 r~? Is._ .` -b.- -, __ _ _ ,. ~ 4 o t 21 _- ~..~-©~- 1, ;, • Surface cas Cement top ~~ ~ 1 Nanuk 2 x '':~ rf 75242 • -~ ~ ~~~a f,. 208 • ~ -P2 £i3 ~ tG2 27 Qi I D 57 [0.10690 75~~O,I; p+, ~~OS Pct~§s zoa~2o n ~ , ~j, --- 2o3oa.n ~io 117}f~ ~ CRU CD4-306 . fo, ; Annulus -`' ~ \ ~' `'~ Area of Review (shaded blue) -^ i Nanuk 1 - ' c„-71~ -^-O s~RU ~DJ 302 t02L'A- ~~ ~ i~-~..~ . ~' ~" t ~ 207p5G0 ':~26 2~-s" 2,055 ~;-~~ ~ CPF-4 ~.' s I l~ Most Likely Receptor Interval ...I~,, f ~ ~,. (highlighted with red rectangle) ~, z ~` ~ ~` ~.1 ~'~ ` '~ \ ~ ~ ~ '~°,~S i oa ago n605so taa77 ~^ i ~'- Sr _ ~'~- -7 61211 ~ el-zos i shoe ,:..,.,, r.~~t,.o ~ _ :+~~u-126 11?5 CS l DA-275 Figure 1. Index Map (The path of the cross-section shown on Figure 3 is highlighted with a magenta line) (about -2,375' and -2,530' TVDSS; see Figure 2, below). This 155-foot thick interval contains numerous 1- to 5-foot thick beds of sandy siltstone and silty sandstone that are separated by siltstone and mudstone. The aggregate stratigraphic thickness of the sandy siltstone and silty sandstone beds exposed to the annulus is about 30 feet. On the well log from CD4-306, the gamma ray curve suggests the presence of a thick, silty sandstone bed at the shoe of the 9-5/8'' surface casing. This apparent silty sandstone bed is an artifact caused by circulating and cementing. In offset wells, the correlative sediments to those surrounding the 9-5/8'" casing shoe consist of claystone, shale and siltstone (see Figure 3, below). The 9-5/8" surface casing shoe lies near the base of a 420-foot thick interval that is dominated by claystone, siltstone and shale. This interval is continuous throughout the area, and it will provide upper confinement for the disposed fluids. Beneath the most likely receptor interval is a 55-foot thick claystone and shale interval that is also continuous throughout the area. This interval, which lies between about 3,126' and 3,221' (-2,559' and -2,616' TVDSS), and three similar, thinner, underlying claystone and shale intervals will provide additional lower confinement for injected wastes. The index map above presents the trajectories for all wells drilled from and near the CD4 drill site. Short tick-marks have been placed along each well trajectory at 500" TVDSS intervals and they are labeled every 1000' TVDSS. The surface location of each wellbore is represented by a gray circle that is about 100 feet in diameter, and the few bottom hole locations visible on the map are represented by 300-foot diameter, gray circles. The locations and true vertical subsea depths of surface casing shoes for selected well bores are illustrated using green triangles and green text, and the calculated locations of the tops of cement for production casing strings or liners for these same wells are indicated by orange semi-circles. CD4-306 May 4, 2010 Note to File Page 3 of 7 Upper Confining Strata Most Like Receptor Intervalfo Disposed Fluids Lower Confining Strata Figure 2. CD4-306 Well Log Displaying Affected Intervals (vertical scale represents measured depth in feet) The portions of each well bore that lie between the surface casing shoe and the top of production string cement are assumed to be filled only with drilling mud, and are therefore possibly open to communication. Inspection of the Nanuk 1, Nanuk 2 and Nanuq 3 well logs indicates the base of permafrost occurs at about 1,330' TVDSS in the CD4 drill site area, which is about 1,050' above the top of the most likely receptor interval. • CD4-306 Note to File May 4, 2010 Page 4 of 7 s 2000300 501032033200 4 CONOCOPHILLIPS ALASK NANUK 2 465 FNL 864 FEL TWP: 11 N-Range:4 E-Sec 25 2010260 2070940 501032D36500 501032D55000 2747 fl ~ ~ 432 R ' , 1065 fl CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK NANUO 3 COLVILLE RIV UNIT CD4-306 2268 FSL 574 FEL 2907 FNL 167 FEL TWP. 11 N-Range:4 E-Sec. 24 TWP 11 N-Renge~4 E-Sec. 24 1960570 501032023800 , ARCO NANUK i 2627 FSL 869 FWL TWP: 11 N-Range.5 E-Sac. 19 -500 ., t '-a~M r i rs ; .. - ., - - ~ r r -500 '' - t ~ ~ ' ., ... y ~_ _ I ; t r ~ ~ -1000 - } ~ -1000 : t 1, '„, i ~~ ~ ,_ f •~ ~ ~ . -1500 ~ 1 4 { ~° w -1500 ' Upper ~ _. Confining "~ ~- Strata " ~ -zooo s _ 9-5/8 Casing Shoe -zooo ._ t 7 ~ Li1.L~l~ ` f { ~ - ; ~ Receptor{~ ~-- -2500 ~ r i ~ Illtel'\:11 7, ' ~. i -2500 ~. . ~~ f `Lower i Confining; -3000 ~ € 'Strata /' ~ ~ _~ ~ -sooo I! ( ~}~ f -3500 i } ~ ~ ': -- ~ ~„ -3500 ~' € ~ ~ >t 'L ~ I ~ ~; i ~ ? ~. } ? -4000 ~ !. ~~ ' -4000 TM,~,. I I ~--._ .. TD=9112 TD=9112 TD=10346 TD=7630 Figure 3. Structural Cross-section from Nanuk 2 to Nanuk 1 (vertical scale represents true vertical feet subsea) The shallow geologic section in the area surrounding CD4-Pad contains methane gas. Records from the Nanuk 1, Nanuk 2 and Nanuq 3 exploratory wells record initial traces of methane at 460', 70', and 1 10' TVDSS, respectively. These wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (typically 9.6 to 10.4 pounds per gallon). The shallowest occurrences of more significant amounts of methane encountered in these wells (arbitrarily picked at 20 units of gas on the mud log) were 1,890', 2,170' and 1,695" TVDSS, respectively. So, the entire proposed disposal zone likely contains some methane gas. n U CD4-306 Note to File May 4, 2010 Page 5 of 7 The shallowest oil shows observed in nearby wells Nanuk 1, Nanuk 2 and Nanuq 3 occur at 3,765', 4,710" and 3,940" TVDSS, respectively. The mud logging geologists rated these shows as being fair to good shows in quality. However, these oil shows occur more than 1,235' below the portion of the open annulus in CD4-306 that will most likely accept the additional injected waste. Supporting documentation to ConocoPhillips' annular disposal applications states: ``There are no USDW aquifers in the Colville River Unit.'" This is correct. Conclusion 3 of Area Injection Orders 27 and 28, which govern the Nanuq and Nanuq-Kuparuk Oil Pools, state that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed areas affected by these orders. CRU CD4-306 CD4-306 Annulus Surface casing shoe and area likely affected by this injection Nan 3 07 , ~ ~~ 320 r,03 322 -.;? 304 . 211 209 . ~5 2 . 2 . Surface Casing Shoe O 125-foot injection radius 0 1,000 feet Figure 4. Surface Casing Shoes of Wells that Lie Within the Area of Review (large, blue circles represent '/-mile radius around surface casing shoe and top of cement in CRU CD4-306; small, blue ellipsoid represents area likely affected by this disposal injection) The '/-mile radius area of review surrounding the proposed disposal interval in CD4-306 is highlighted on Figure 4 by two large, blue circles; one circle is centered at the location of the surface casing shoe, and the other is centered on the calculated top of cement for the production casing stril7g. In CD4-306, most likely waste receptor interval lies between -2,375' and -2,530' TVDSS, which lies immediately northwest of the red triangle on Figure 4. The surface casing shoes of fourteen wells lie within the area of review: CD4-O5, CD4-07, CD4-16, CD4-17, CD4-209, CD4-210, CD4-211, CD4-214, CD4-215, CD4-303, CD4- 304, CD4-320, CD4-322, and Nanuq 3. CD4-306 ~ ~ May 4, 2010 Note to File Page 6 of 7 Injected Fluid vs Affected Radial Distance CD3-306 Wellbore (assumes 30' aggregate injection zone thickness and 30% porosity) 300 _ ,; 2_,50 ~' w m 0 ~0 E 0 w ~0 ~a ql ~~ d V d ~~ 0 10.000 20,000 30,000 40,000 50,000 60,000 70,000 Amount of Injected Fluid (barrels) Figure 5. Radial Distance Potentially Impacted by CD4-306 Annular Disposal The chart presented in Figure 5 provides an estimate of the subsurface volume around CD4-306 that will be affected by the proposed annular disposal operations. There are about 30' of porous sandy siltstone and silty sandstone beds within the likely waste receptor interval, according to a count using the gamma ray curve from CD4-306. Neutron and density porosity well logs were run across the proposed disposal interval in CD4-306. Inspection of these well logs suggests an average porosity of about 30% for the sandy siltstone and silty sandstone within the most likely receptor interval. Based on these values and assuming uniform, piston-like displacement of in situ fluids, the annular injection of up to 70,000 total barrels of waste will directly affect the receptor beds only to a radius of about 125" from the wellbore, as indicated in the chart above. The nearest wells to CD4-306 are CD4-304 and CD4-07. The casing shoes of CD4-304 and CD4-07 are respectively located 300" and 350'away from mostly likely receptor interval in CD4-306. Disposal injection into CD4-306 will likely not affect either of these wells due to the separation distance, but if injected waste does reach either well, surface casing, cement, and confining layers will ensure injected materials remain within the disposal strata. ~K ~ ~w CD4-306 ~ ~ May 4, 2010 Note to File Page 7 of 7 Summary The limited volume of rock that will be affected by this proposed disposal injection program contains methane gas, is situated beneath more than 1,330' of permafrost, and is bounded above and below by continuous layers of claystone, shale and siltstone. The most likely receptor interval lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbon accumulations within the proposed zone of injection. It appears unlikely that injected wastes will reach nearby wells CD4-304 or CD4-07, but if they do, surface casing, cement, and confining layers will ensure injected materials remain within the disposal strata. I recom end approval of this annular disposal project. Steve Davies 7~ Senior Petroleum Geologist ,~ f ~ ~ F~~`-~. DATA SUBMITTAL COMPLIANCE REPORT 7/6/2009 Permit to Drill 2070940 Well Name/Mo. COLVILLE R!V NAN-K CD4-306 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20550-00-00 MD 10346 TVD 7253 Completion Date 7/28/2007 Compietion Status 1WINJ Current Status 1WINJ UI~ Y/ ~ REQUIRED INFORMATION ~ ~ Mud Log No Samples No Directional Survey ~es~ DATA INFORMATION Types Electric or Other Logs Run: GR/Res, SCMT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / lype meairrm[ rvumcer Name acaie meaia rvo s[art stop ~n rcecervea ~ommenrs og Perforation Blu 1 9800 10200 Case 8/27/2007 Perf Record w/Static BHP Survey 28-Ju1-2007 Log Cement Evaluation 5 Col 1 9800 10200 Case 8/27/2007 SCMT, w/Pres, Temp, GR, CCL 28-Ju1-2007 D D Asc Directional Survey 0 10346 Open 9/12/2007 i t 15497 LIS Verification 2702 10346 Open 10/3/2007 LIS Veri, GR, FET, NPHI, NCNT, RHOB, DRHO, FCNT, ROP ED C Lis ~ 15497''~Induction/Resistivity 2702 10346 Open 10/3/2007 LIS Veri, GR, FET, NPHI, NCNT, RHOB, DRHO, FCNT, ROP w/LAS ( Graphics D C 18065/See Notes 0 0 Open 5/21/2009 EWR logs in PDS, EMF, CGM gaphics ,, Induction/Resistivity 25 Col 114 10346 Open 5/21/2009 MD ROP, DGR, EWR, ~/ ALD, CTN Log Induction/Resistivity 25 Col 114 7252 Open 5/21/2009 ND DGR, EWR, ALD, CTN Well Cores/Samples Information: • ~ Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 716/2009 Permit to Drill 2070940 Well Name/No. COLVILLE RIV NAN-K CD4-306 Operator CONOCOPHIL~IPS ALASKA INC MD 10346 ND 7253 ADDITIONAL IPFORMATION Well Cored? Y ~N Chips Received? TfTT- Analysis ~% N Received? Comments: Completion Date 7/28/2007 Completion Status 1WINJ Daily History Received? Formation Tops Compliance Reviewed By: Current Status 1 WINJ ~N ~Y~,YN "t - Date: API No. 50-103-20550-00-00 UIC Y ~ • CJ MEMORANDUM TO: Jim Regg / i P.I.Supervisor~ ~~ 713~1~ FROM: Bob Noble Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 29, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-306 COLVII,LE RIV NAN-K CD4-306 Src: Inspector N(1N_f ntv~m~tv~rr s r Reviewed By: P.I. Suprv J~i'L- We11 Name: COLVILLE RN NAN-K CD4-306 Insp Num: RutRCN090729093140 Rel Insp Num: API Wel[ Number: 50-103-20550-00-00 Inspector Name: Bob Nobie Permit Number: 2o7-o9a-o r Inspection Date: ~~3/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ CD4-306 Type Inj. G TV~ 6898 r IA 9~o zoao .~ Zo2s Zozs ~ P.T.D zo~o9ao TypeTest SPT Test psi zoao ~ OA aoo sis aos soo Interval 4YRTST P~ P / Tubing 3731 3729 3726 3730 Notes: M; ~.-t~~~- p~SS~~.~ ~ 7 z4Ps; Wednesday, July 29, 2009 Page 1 of 1 ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-306 ~ May 6, 2009 AK-MW-5158770 CD4-306 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-103-20550-00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Logs 50-103-20550-00 Digital Log Images: 1 CD Rom 50-103-20550-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan.Burinda@halliburton.com ~_ ~ 20~ -C~y ~ ~~~ ' d~ [ , ~ ~ • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, AIASKA 99510-0360 ~ ~`~~ March 19, 200~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ ~ ~~ /!~ ~~.~~ ~ ~~~~~~~ ~~~~ ~ @~~~ ~~~ ~ ~~~ . ~ ~~~~~~G'~~~ ~~~ ~ ~~ ~ ~~~~~~~ ~~ ~ - ~ G~ ~- / ~~ ~-- -- -~ ~ ~ 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 18~', 2009. The atta.ched 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 iucui 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 Corrosion Initial top of Vol, of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # cement um ed cement date 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 ~na_m ~m_~ ~R ~F Nn F~~ Na ~ 49 3/18/~O(19 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 ~ CD4-211 ' 206-153 9" NA 9" NA 3.82 3/18/2009 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-a6 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 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: 207-094 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-306 2. Address: WAG ^ 4b. Well Status: Oil ^ Gas 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ~ WDSPL ^ 50-103-20550-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^ or Final ~ 307-258 9/6/2007 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 357* 357 0 totals (bbls): 2007 / 3rd 16494 100 20* 16614 14 9/10/2007 9/23/2007 CD4-07, CD4-307 2007/4th 11269 100 0 11369 14 10/1/2007 10/21/2007 CD4-304 zoos i ~ st 0 0 0 0 0 2008 / 2nd 0 0 0 0 0 2008 / 3rd 0 0 0 0 0 Total Ending Report is due on the 20th Volume 27763 200 377* 28340 2$ (bbis~: of the month followin the final month of the uarter. Ex: 9' 9 A i120 f fi t J l 20 f th d th t t pr or quar er, u y or e secon quar er, e rs 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ 12. Remarks and Approved Substances ~escription~s~: *annular flush, freeze rotect volumes and in~ectivit test I hereby certify that the foregoing is true and correct to the best of my knowledge. F Signature: i.. _. Date: ~o ~l 3~0a Printed Name: G. C. Alvord Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6120 .,. ~ ~ ~ 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: 207-094 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-306 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ~ w~sP~ ^ 50-103-20550-00 3. (Chedc one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ~ or Final ^ 307-258 9/6/2007 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 substanc~s (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): 357' 357 0 200~ i 3rd 16494 100 20` 16614 14 9/10/2007 9/23/2007 CD4-07, CD4-307 2007 / 4th 11269 100 0 11369 14 10/1/2007 10/21/2007 CD4-304 2008 / 1 st 0 0 0 0 0 2008 / 2nd 0 0 0 0 0 Total Ending vo~ume 27763 200 377* 28340 28 Report is due on the 20th (bnis>: of the month following the ~nal month of the quarter. Ex: April 20 for the first uarter Ju/ 20 f th d rt q , y or e secon qua er, 17. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for fhe Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances oescripcion~s~: *annular flush, freeze rotect volumes and in'ectivi test I hereby certify that the foregoin is true and correct to the best of my knowledge. Signature: Date: 7 l~$ r° ~ 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 r ~ ~ 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: 207-094 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-306 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^~ WDSPL ^ 50-103-20550-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ^Q or Final ^ 307-258 9/6/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbis): Number of Disposal Disposal Source Welis: cuttings, reseroe 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 Pre~ious 357* 357 0 totals (bbls): 2007 / 3rd 16494 100 20" 16614 14 9/10/2007 9/23/2007 CD4-07, CD4-307 2oo~/ath 11269 100 0 11369 14 10/1/2007 10/21/2007 CD4-304 2oos i~ st 0 0 0 0 0 2008 / 2nd Tota~ E^d~^9 ~ Report is due on the 20th vo~ume 27763 200 377* 28340 28 Ex: of the month following the final month of the quarter ~bbis~: . 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 ~escription~s>: *annular flush, freeze protect volumes and in'ectivit test I hereby certify that the foregoing is true and correct to the best of my knowledge. r ~ LC l~ ~o D ~ ~ ~ , Signature: ate: ~ -- 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. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: 207-094 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-306 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ~ WDSPL ^ 50-103-20550-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: initial Disposal ^ or Continuation 0 or Finaf ^ 307-258 9/6/2007 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 357* 357 0 totals (bbls): z007/3rd 16494 100 20* 16614 14 9/10/2007 9/23/2007 CD4-07, CD4-307 2007 / 4th 11269 100 0 11369 14 10/1/2007 10/21/2007 CD4-304 2008 / 1 st 2008 / 2nd Total Ending Report is due on the 20th vo~ume 27763 200 377* 28340 28 ~bbis~: of the month following the final month of the quarter. Ex: Apri120 for the first quarter July 20 for the second quarfer 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 ~escr~pt~on~s~: *annular flush, 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: ~ ~'~ ~~ ~3 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 ~ ~ ~ WELL LOG TRANSMITTAL To: State of Alaska October 2, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99~01-3539 RE: MWD Formation Evaluation Logs: CD4-306 AK-MW-5158770 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20550-00 ~~C- ~D~-U `~~'~ ~ p~ ~ ~ ~ ,- . ;,-.r , -- -+ ~ I 5~~~ ~- .;~ . ~ ~ b ~ ~ ~ ~ SARAH PALlN, GOVERNOR CO~~~~~~0 n ~ i~7r~ 333 W. 7thAVENUE, SUITE 100 ~Z~ t~Dy~r'r'=~~~ 7 Q<s J ANCHORAGE,ALASKA 99501-35 f PHONE (907) 279-1433 FAX (807) 276-7542 Chip Alvord Alpine Drilling Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 39 Re: Colville River Field, Nanuq-Kuparuk Oil Pool, CD4-306 Sundry Number: 307-258 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. 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 September, 2007 Encl. w~ ~'~~- ti a ~ ~ ~, n ~ ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276=1215 September 4, 2007 Alaska Oil and Gas Conservation Commission 333 West 7`~ Avenue, Suite 100 Anchorage, Alaska 99501-3539 ~ a ;~ ~ ~~:-~ ~ ~~ ~ ~ ~ ~ , ~E3~c~ct~~~l~~~ ?'~ ~;. ;;_~i ~~ a~~~ ~ , ;:3 a~ ~ ~€;,:. ~ ~~;;~~ ~,:, Re: Correction on 10-4Q3AD for CD4-16 CA4-3136 & CD4-302 Dear Sir or Madam: ConocoPhillips Alaska, Inc. recently requested that 3 wells, CD4-16, CD4-306, and CD4-302 be permitted for pumping of fluids occurring as a result of drilling fluids. An error was found in the X and Y surface casing coordinates for CD4-16 and CD4-306 and therefore the 10-403AD for each well is being re-submitted. Please note, that to help with viewing the surface casing shoes within the quarter mile radius, the wells with surface casings outside the quarter mile plot are excluded. Please find attached form 10-403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form CD4-16 2. CD4-16 Plan View of Adjacent Wells 3. List of wells on CD4 pad and the lateral distance from the surface casing shoe for CD4-16. 4. Annular Disposal Transmittal Form CD4-306 5. CD4-306 Plan View of Adjacent Wells 6. List of wells on CD4 pad and the lateral distance from the surface casing shoe for CD4-306. 7. Annular Disposal Transmittal Form CD4-302 8. CD4-302 Plan View of Adjacent Wells 9. List of wells on CD4 pad and the lateral distance from the surface casing shoe for CD4-302. If you have any questions or require further information, please contact Liz Galiunas at 265-6247; Chip Alvord can also be reached by calling 265-6120. Sincerely, Liz Galiunas Drilling Engineer cc: CD4-16 Well File CD4-302 Well File CD4-206 Well file Chip Alvord ATO-1577 Anadarko Sharon Allsup-Drake ATO-1530 ~ ~~ l.~~i~ ~`o? ~~1~ STATE OF ALASKA ~ ~~ ~- REGEIVED ~5 ALASKA OIL AND GAS CONSERVATION COMMISSION S E P 0 4 2007 ANNULAR DISPOSAL APPLICATION Alaska Oil & Gas Cons. Cammission 20 AAC 25.080 Anchorage 1. Operator 3. Permit to Drill Name: Number: 207-094 ConocoPhillips Alaska 4. API Number: 50-103-20550-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD4-306 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: Nanuq ~ CD4-208, CD4-209, CD4-210, G~4-324, CD4-321, Torok and Seabee formation, shale, siltstone and sandstone CD4-214, CQ4-213, GC?4-302, CD4 ~~~ ~ -16 b) Waste receiving zone: b) water welis 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 barcier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1650' MD /1 600' 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 2225 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbis. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- contaminated drilling mud, completion fluids, diesef, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 20-Aug-os added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and ND) ~ Cement Bond Log (if required) ^ FIT Records w/LOT Graph ~ Surf. Casing Cementing Data ~^ Other ^~ previous authorization for new qroduct cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ ~ - i- 4~'t Title: ~~~ ~~ ` Printed N Phone N b ~ C ~ ame: Chip Alvord um r~ er: 265-6120 Date: ~- Commission Use Onl Conditions of approval: C„~~~~ ~~-.~~~ ~ f ~ ~ ~ (~ L ~~~ , Q~~ LOT review and approvaL ,E.- ~ (~ °' '~ i S b t f d tQr ~ ~~~ "' c~i ~ 4 A l b re u sequen orm requ : . er: pprova num AppfoVed by: APPROVED BY COMMISSIONER THE COMMISSION Date: L, ~ ~ V Form 10-403AD Rev. 6/80~041 ~ 1 V I~ W~~~IY~'I-RUCTIONS ON REVERSE !~ IGd~L S~~ ~~ ZD~~ubmit in Duplicate SURFACE CASING SHOE SEPARATION FROM CD4-306 ~ CD4-306 x v Surface Casing Shoe ASP 4 Coordinates NAD 27: 377254.69 5958096.95 ells Nanuk 1 Nanuk 2 Details @ AOGCC'"' n n Ann. Disp. Permit # ermit Date ource well Ann. Vol. tart Date nd Date is ance from Object well* Surface csg. Shoe X Coord. Surface csg. Shoe Y Coord. Surf LOT (ppg) Surface casing TVD (ft) Annular LOT (ppg) omments Exploration P&A'd Exploration P&A'd Nan 3' 1040 376499.5 5957382.0 11.8 1781 Exploration, X-Y location calcutated at 2400' TVD, NOT the surface shoe de th Nanu 5 2143 378326.6 5956241.7 14.9 2393 15.1 Not for annular dis sal CD2-319 305-373 12/9/2005 CD4-208, CD4318, CD4-209, CD4-320 32010 17J14/2005 7/2/2006 2308 377174.7 5955790.4 18.4 2400 16.1 CD4208 306-183 5/30@006 CD4-318a, CD4320, CD4-214, CD4-321,CD4-211 61839 7/3/2006 1/4/2007 1573 378134.2 59567927 16.3 2439 14.4 volume extension to 70000 bbl, permit #306- 266 CD4378 306-181 5/26/2006 CD4-209, CD4-320 942 5131/2006 8/2/2006 2108 376138.4 5956308.2 18.2 2375 17.1 Unable to pump- SD pumpin CD4209 1022 377934.9 5957333.9 14.7 2377 17.5 Not for annular disposal Cb4 21fl 1171 377547.4 5956963.2 18.0 2386 17.3 CDd-32Q 660 3779142 5958105.0 77.1 2378 17.8 Not for annular dis osal CD4-17 1212 376416.3 5957221.0 18.1 2387 16.2 Not for annular disposal, due to proximity to Nanuq 3 CD4-321 306393 1/2/2007 31117 7/14l2007 8/20/2007 1859 375795.6 5956945.4 18.0 2385 16.3 CQ421d 1154 377040.9 5956962.8 17.3 2365 17.6 Not for annular disposal CD4~211 306392 12/29/2006 CD4302, CD4-16 31937 6/20/2007 7/11/2007 612 377358.3 5957494.0 18.1 2391 15A 2nd annular LOT, 1st ann test 18.4 CD4275 1274 376770.5 5956918.7 17.6 2392 17.50 CD4213 1523 377446.8 5956586.6 18.7 2389 21.40 Not for annular disposal. High Ann test Probabi ice lu , will retest if needed CD4-302 2114 379247.7 5957393.4 18.1 2394 17.10 C04-16 908 376571.7 5957499.3 18.1 2388 17.90 CD4-306 0 377254.7 5958097.0 18.0 2377 14.90 * Lateral distance in feet, belween surface casing shoes, in the X-Y piane `• As of August 31, 2007 ~ Note that this sheet is not the definitive record for annular disposal volumes ~ti, '~ ~ ( t \ ~ 1~.RaJ~ J ~FiE`..S ~\~~ C.~ 1 ~" ~ ~' ~.. ~ ~~~ ~ ~~.5~~ ~~. c3~~~ c~~4~~~~ v~~r1r.. Nc~.~.~,~.,y~ `~ s ~ ~-~~ ~ ~~.~ ~~ Ch~1-~ t~ ~ C~- ~~'~ . ~ i ~~~~ ~ /~o~ ~~~ i943-~ RECEIVED ' c~4-zos c~4-~osPBi _ ~ SEP 0 6 2007 ~ CD4-306 ; Alaska Oil & Gas Cons. Commission ~ Anchorage ~ 1619-1 '~~ '~, ~ ~ CD4-210 CD4-210 1295 ~ I I f ~ 972~ ,, , I i i ~ + I Nar~ 3 wGS ~I x 648~ ~ , 9 5l8" x 12114" 9 5; 8" x 12114" ~~ i~ G~~ ft~ ,~ I I I ~ ~ ~ , ~~~x 8 3/4~~ ~ ~ SIb~~ ~ ~ ~~ ~~ ~ . = CD4-320 (CD4-320PB l ) ~ 324 ~~ ~ ~ ~ 7~'~~~, ~~ CD4-322 (CD4-322) _- - __ ~ 9 Sl8° x 12114" ~ _,_ __.. _ _.. _ _. __ p-- _.__.. ~~ ~ __ -. ~X~11,~„ __ =~ ~~ 9~1~~1 , 3~1; , ~~ \ ~ __. ~ , ~, ~ _. + - ____.--- .. -i-9 78" x 121/4° - .. ; CD4-16 (CD4-16) '~ --- ~-~"_ ~~ . ~ 9/8" x 121/4" ; J _ _ --.. % Nanuq 3 (Nanuq 3) _ . __ _____ ._ /- ~ . ,~ ~ ~ I , _ / 9 5/8" ~ ~ , I~, -324 ; ~ ~- / ~ I ~ l4° - ~ ~ ~ ~ ' ~ ' 9 5l8" ~ 12 ° ~ 12114" ' 1 ' I ~ / x ~ x 12 4" ~ ~ x 5 " ~ ° ! ~ CD4-17 CD4-17 / ~ ~~ ~ ~ CD4-318 ~CD4-318 l8" ~ ~ 1/4" ~ CD4 319 CD4 319 9 518 x 12114 - ~ ' CD4-321(CD4-321) ~ ~ ' 7"x 8 3/ " , ~ ' / h ~ ~~ -648 ~ ~~ CD4-214 (CD4-214) ~ ' ~ CD4-209 CD4-209 4-208 CD4-208 ~ ~~ CD4-211(CD4-211) ~ ;~ CD4-215 (CD4-215) ~ j~ CD4-210 CD4-210 ~~ ,,~" CD4-213 CD4-213 ~" Nanu 5 anu 5 j ~ , ' , , -3238 -2915 -2591 , -2267 -1943 -1619 -1295 -972 -648 -324 0 324 648 West(-)/East(+) [ft~ ~~~~~ ~~«~ radius plot ~ 9 5/8" x 121/4" ~ -~ CD4-302 C( D4_302~ CD4-320 (CD4-320) i 972 1295 161~ ~ ~ ~~ ~~~~~~ STATE OF ALASKA ~~~ ~~ ~ L~d~ ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATi4N '~~~~~~~ ~+~ ~ ~~~ ~~~~~° ~~~~"~"~~`~~' 2o aac 25.oso r~~~ ;:.~~ `~~r~ ~ 1. Operator 3. Permit to Drill Name: Number: 7-094 ConocoPhillips Alaska 4. API Number: 0-103-20550-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD4-306 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic descri on: a) All wells within one-quarter mile: a) Interval exposed open annulus: Nanuq 5, CD4-208, CD4-209, CD4-210, CD4-320, CD4-321, i b h l d d CD4-214, CD4-213, CD4-302, CD4 -16 ~an ea san ee formation, s a e, s ltstone an stone ~ b W ste ceiving zone: b) water wells within one mile: ~S ~ I ers below the C30 marker in the Seabee formation '~ None c) onfi t: ~ e~ d r Bluff formation provides an upper barrier and marine shales and daystones of the Albian T k Formation rovide a lower barrier p oro 9. Depth to base of permafrost: ~ 10. Hydrocarbon zones above waste receiving zone: approximately 1650' MD / 1 600' TV~ None ~ 11. Previous volume disposed in annulus and date: '?~' s ated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2225 14. Estimated volume to be disposed with this request: . 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 2o-Aug;~~~ ,;~ ~ Y needed to facilitate pumping of drilling mud or drilling cuttings, new product cieanup r~, ~ fluids such as cement rinsate, and mud and brine pit rinse from mixing operations and r`~ ~ any other fluids associated with drilling a well. 17. Attachments: Well Schematic (Include MD nd TVD) ~ Cement Bond Log (if required) ^ FIT Records w/LOT Graph 0 Surf. Casing Cementing ta ^'' Other ~ previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the fore ing is true and correct to the best of my knowledge. ~ - ~~ ~ e S wC .- ~ ~ VGT*~~~ ~5r-~eV ~(~ ' ignature: - C Title: ~ / Printed ~ r ~ N ~ ~ l ~ ~ Phone r N b /~/ 7 ame: ~ ~ • o Chip Alvord um ~ er: 265-6120 Date: 0 Commission Use Only Conditions of approval: LOT review and approval: S b f i d ~ [ ~ ~U u sequent orm requ re : Approval number: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403AD Rev. 6/2004 U~~~ ~'~ ~UCTIONS ON REVERSE `%'~~e~G/`/ `, Su~ in DuplicateQ7 -7'za~~ ~.~s : ~ ~ ConocoPhillips Alaska, Inc. Post Of6ce Box 100360 ~ ~, Anc porage, Alaslca 99510-0360 ~~~~~~~~ t~~~~~~ ~ Tele hone 907-276-1215 ~ ~~ ~ ~ ~~° ~~~ August 1, 2007 `~~~;,i;~' g~ ~ ~~~? ~,a~ , fYj9 ~V~ M1.iSEa; riF~iQ~Y. ~~7Pl~~~k4'~ Alaska Oil and Gas Conservation Commission .E 333 West 7~' Avenue, Suite 100 ~'~'~~r~~` r' "'`~ Anchorage, Alaska 99501-3539 Re: Auplication for Sundry Aqproval for Annular Disposal of Drillin~ Waste on well CD4-306 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD4-306 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD4-306 approximately August 20, 2006. Please find attached form 10-403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD4 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within'/a mile radius at AOGCC: wells attached with CD4-16 sundry. 12. Copy of previous authorization (CDl and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial annular LOT (14.9 ppg) occurred at a lower equivalent mud weight than the casing shoe test (18.0 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact Liz Galiunas at 265-6247; Chip Alvord can also be reached by calling 265-6120. Sincerely, Liz Galiunas ~ Drilling E meer cc: CD4-306 Well File Chip Alvord ATO-1577 Anadarko Sharon Allsup-Drake ATO-1530 • ~ Annulus Disposal Transmittal Form - Well CD4-306 AOGCC ReQUlations, 20 AAC 25.080 (b) 1 Desi nation of the well ar wells to receive drillin wastes: CD4-302 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 information 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/1. (Ref. AOGCC Conservation Order No. 443, M 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 voluxne 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. MaJCimum 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 Maximuxn anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2225 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 rsports, 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 suminary 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 CD4-07, CD4-304, CD4-303 will be enerated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com liance would be im rudent. 16 Any additional data required by the commission to confirm N/A containxnent of drillin waste. ~ • Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) v~~o~ ~ o-~a~~os Well CD 4- 306 Assumptions Date 7/3 0/2 007 Maximum 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 wel(s on gas lift) 1,000 psi :n •;, Maximum Fluid Densitv to avoid Burst of Surface Casing " Pburst85°/ - PHydrostatic + PApplied - PFormation : 4,888 = ( 2,377 * 0.052 * MWmax ) + 1500 - ( 0.4337 * 2,377 ) N o~•' MWmax = 35.7 PPg 2,377 TVD Surface Casing String Size 9.625 in ~ ~ Weight 40 ppf a a Grade L 80 ~ ~° ~° rb~~c~ooia 5,750 PS' ~ Pburst85 % 4,888 psi v Depth of Shoe 2,377 ft FIT/LOT @ Shoe 18 ppg or 2,225 psi - FIT/LOT for Annulus 14.9 ppg o Max Surf. Pressure 1,500 psi r TOC Est. @ 4,900' MD 3,760' TVD a.5 "Tubing \7,462 TVD Maximum Fluid Densitv avoid Collapse of 2nd Casin~ Strin~ Pcollapse85 /- PHydrostatic + PApplied - PGasGradient - PHeader 4,599 = ( 3,760 * 0.052 * MW~naX ) + 1,500 - ( 0.0700 * 3,760 ) - 1,000 MWmax = 22.3 PPg 2nd Casin~ String Size 7 in Weight 26 ppf Grade L 80 rcollapse100°/ 5,410 PS~ Pcollapse8S% 4,599 PS~ Top of Cement 3,760 ft Gas Gradient ~•~~ psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax auoWab~e = Shoe TVD Depth *.052 * Shoe FIT/LOT Pmax allowable - ( 2,377 * .052 * 18 ) Pmax allowable - 2,225 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". ~ ~ ConocoPhilli S Casing Detail Well: CD4306 ~ 9 5/8" Surface Casinp Date: 7/17/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.90 FMC Gen V Hanger 2.15 36.90 Jts 3 to 70 68 Jts 9-5/8" 40# L-80 BTC Csg 2606.87 39.05 Halliburton Float Collar 1.15 2645.92 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 77.31 2647.07 Ray Oil Tools "Silver BulleY' Float Shoe 2.20 2724.38 2726.58 TD 12 1/4" Surface Hole 2737.00 12 1/4" hole MD 2,737' - 2,383' TVD 9 5/8" csg shoe MD 2,727' - 2377' TVD TOTAL BOWSPRING CENTRALIZERS - 40 1 per jt on Jt #1 -#13 (stop ring on Jt #1 & 3) and over collars on jts# 15, 17, 19, 21, 23, 25, 27, 29, 31, 33, 35, 37, 39, 41, 43, 45, 47, 49, 51, 53, 55, 57, 59, 61, 63 65, 67 75 joints in the pipe shed. 70 jts to run - Last 5 jts out Use Best-o-Life 2000 pipe dope All joints drifted - 8.781" MU torque ~ 8600 ft/Ibs Remarks: Up Wt - 185 k Dn Wt - 127 k Block Wt - 75k Supervisor. D. Lutrick / L. Hill ~ ~ ConocoPhilli s p ~ CASING TALLY PAGE: 1 of 2 WELL NUMBER: CD4-306 RIG: Doyon 19 CASING DESCRIPTION: 9 5/8", 40# L-80 BTC DATE: 07/17/07 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 38.74 26 38.72 51 38.62 76 101 126 151 176 2 38.57 2~ 39.39 52 38.88 77 102 127 152 177 3 38.60 28 39.02 53 41.12 78 103 128 153 178 4 36.27 29 36.70 54 39.29 79 104 129 154 179 5 37.11 30 38.57 55 37.36 80 105 130 155 180 6 37.72 31 34.41 56 39.31 81 106 131 i 56 181 7 38.04 32 38.62 57 37.45 82 107 132 157 182 8 38.89 33 37.38 58 39.06 83 108 133 158 183 9 37.78 34 39.38 59 37.01 84 109 134 159 184 10 38.24 35 36.80 60 38.09 85 110 135 160 185 11 38.68 36 38.42 61 38.64 86 111 136 161 186 12 38.60 37 38.61 62 37.07 87 112 137 162 187 13 38.56 38 38.28 63 38.57 88 113 138 163 188 14 38.57 39 38.66 64 36.93 89 114 139 164 189 15 38.96 40 36.92 65 38.49 90 115 140 165 190 16 38.56 41 38.55 66 38.26 91 116 141 166 191 17 38.59 42 43.08 67 38.41 92 117 142 167 192 18 38.56 43 39.53 68 37.20 93 118 143 168 193 19 36.75 44 38.98 69 38.96 94 119 144 169 194 20 38.50 45 39.23 70 39.47 95 120 145 170 195 21 39.19 46 37.60 71 37.69 96 121 146 171 196 22 38.68 47 38.92 72 37.06 97 122 147 172 197 23 38.69 48 38.69 73 36.63 98 123 148 173 198 24 36.51 49 36.35 74 38.28 99 124 149 174 199 25 39.16 50 38.66 75 38.94 100 125 150 175 200 Tot 956.52 Tot 959.47 Tot 956.79 Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 2872.78 DIRECTIONS: TOTAL JOINTS THIS PAGE = 75 FLOAT SHOE 2.2 FLOAT COLLAR 1.15 HANGER RKB 36.9 ~ ~ ~.: .~ Cement Detail Report CD4-306 ~ . ,.. Surface Casing Cement Security Level: Development~ Daily Drilling Report CD4-306 Report Number: 4 tig: DOYON 19 Report Date: 7/17/2007 ~> ,~ . . ~. .~rt~rin ~ : ;~~~ k ~::. rfle~ ~t~ . : . ., , ~.r 10188966 5,295,000.00 Welibore Well Type Field Name Original Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) CD4-306 Development NANUQ KUPARUK 7/14/2007 3.05 2,737.0 2,737.0 0.00 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 4,183.70 51,274.95 334,281.70 1,188,298.95 Last Casing String Ne~ct Casing OD (in) Next Casing Set Depth (ftKB) Surface, 2,726.6ftK6 Ops and Depth @ Morning Report 24hr Forecast Perform FIT Drill out shoe track. FIT. Drill 8 3/4" hole. Last 24hr Summary Circ --Cmt 9 5/8" csg - Test csg - ND riser - install wellhead - NU & test BOPE - MU BHA # 2- RIH General Remarks Weather Head Count 50? - NE Cc~ 12 mph - Vis 10+ mi - Clear 48.0 Don Mickey, uu:uu u~:ia ~.za ~urcrH~ l;tMtN I circc r z,izi.u z,izi.u tstaousn circuia[ion. ~cage pumps up to 6.5 bpm at 230 psi. Condition mud for cement job. 01:15 01:30 0.25 SURFAC CEMENT SFTY P 2,727.0 2,727.0 PJSM and cementing surFace csg. 01:30 03:45 2.25 SURFAC CEMENT DISP P 2,727.0 2,727.0 Cement 9 5/8" csg as follows: Pumped 30 bbls Biazon water w/ nut plug for marker - switched to Dowell - Pumped 5 bbls water - Test lines to 4000 psi - Dropped btm plug - Mixed & pumped 50 bbis MudPush @ 10.5 ppg @ 5 bpm @ 450 psi - Mixed & pumped Lead slurry (AS 3 Lite) @ 10.7 ppg @ 7.5 bpm @ 700 psi - Observed nut plug marker @ Shakers w/ 278 bbls pumped - Pumped down surge can (297 bbls total )- Switched over to tail slurry Pumped 50.38 bbls Class G w/ additives) @ 15.8 ppg @ 4 bpm @ 470 psi - Dropped top plug w/ 20 bbls water f/ Dowell - Switched to rig pumps & displaced w/179.8 bbls - 9.8 ppg mud @ 6.5 bpm @ 600 psi for first 170 bbls - slowed pump to 3.5 bpm for last 10 bbls @ 480 to 510 psi - Bumped plug w/ 1000 psi - Checked floats OK - CIP @ 03:37 hrs.- Full circulation throughout job w/ 130 bbis 10.7 ppg cmt to surface 04:00 04:45 0.75 SURFAC CASING DHEQ P 2,727.0 2,727.0 RU. Test 9 5/8" csg to 3500 psi for 30 min. 04:45 05:15 0.50 SURFAC CASING RURD P 2,727.0 2,727.0 Blow down lines. RD cement head and circulating equipment. 05:15 07:15 2.00 SURFAC CASING NUND P 2,727.0 2,727.0 LD landing jt. - Drain stack - ND surface riser & starting head - LD mouse hole 07:15 08:00 0.75 SURFAC DRILL OTHR P Install FMC 11" 5 K Unihead & test seals to 1000 psi 08:00 09:45 1.75 SURFAC WELCTL NUND P NU BOPE 09:45 13:00 3.25 SURFAC WELCTL EQRP P Install 4" solid body rams in lower gate & 3 1/2" x 6" VBR in top gate Latest BOP Test Data ~,.~ ,; ..,,.. . ... .. ,: ' ~~te , . ~`~•' 7/17/2007 I Page 1/2 Report Printed: 7/27/2007I Security Level: Development tig: DOYON 19 Report Number: 4 Report Date: 7/17/2007 IJ.VV IJ.VV V.VVJVIIIl1V VVLLI,IL UVfL r f~V(JIIGJIUVrL-/11111UIQIlVGJV[%JJVV psi - pipe rams, blind rams, choke manifold valves, choke & kill line valves, dart & floor safety valves, TD IBOP's to 250 & 5000 psi - performed accumulator closure test - test witnessed & approved by Bob Noble AOGCC 19:00 19:30 0.50 SURFAC WELCTL OTHR P Install wear busning. Blow down choke and kill lines. 19:30 00:00 4.50 SURFAC DRILL PULD P 743.0 Bring BHA equipment to rig floor. MU BHA #2. Upload MWD: Test Geospan to 3500 psi. PJSM. Install sources. MU NMFCs, jars and HWDP to 743'. 2, 727.0 ~ 9.80 ~ 41 ~ 15.0 ~ 15.000 ~ 5.0 ~ 9.0 ~ 12.000 Gementing Fluids 620A f1 CD4-306 to CD4-321 Diesel 45.0 freeze protect CD4-321 Water 245.0 Annular flush CD4-321 Water Based Mud 1354.0 f/CD4-306 toCD4-321 ff~tellb€?r~. ~ ~.:~~~ ~, .~,x~, ~. ..::.., , ,~. ~,.~. , ,,,,.. Wellbore Name Wellbore API/UW I CD4-306 501032055000 .. ,~ . "~x; '- ; on ~~. ~s :. ,, . s~ze {[n) , i - , ,4r~Te~2 (ittte) >Aci ;) Start~at~. , . : : at~ . , ,. , . °: COND1 16 0.0 114.0 6/12/2007 6/12/2007 SURFAC 12 1/4 114.0 2,737.0 7/14/2007 7/16/2007 INTRMI 8 3/4 2,737.0 10,346.0 7/18/2007 7/21/2007 GetY1~»~ , ,,,,.,., . :?;,:.. : ~~ ..... . . '~, ~ _.:.. .. Surface Casin Cement - Started 7/17/2007 Type Wellbore Cemented String Cement Evaluation Results casing Surface, 2,726.6ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q(end) (bbl/... P(final) (psi) 1 Surface Casing Cement 0.0 2,727.0 4 490.0 : ~.. ~~;~~~. .. ~~a - : ~. .,, c~~s ~,~ t~~ :: . v t~r :: ', ~~:t~sas~ ~~~ia €~~3:=: ,: ~ ~ an t~~ ~ . ~ am+;t~~~ Lead Cement G 360 297A 10.70 4.63 36.0 2,227.0 Tail Cement G 234 50.0 15.80 1.17 2,227.0 2,727.0 Daily Drilling Report CD4-306 Page 2/2 Report Printed: 7127/2007 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-306 Rig: Doyon 19 Date: 7/18/2007 Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: Lutrick / Mickey Pump used: #1 Mud Pump ~ Strokes ~ 0.1000 Bbls/Strk • 8.00 Strk/min ~ T f T t h l ~ P i d ~ ype o eS : Open o eTest LOT/FIT ump ng own annulus and DP. Casin Test Pressure In te rit Test Hole Size: 8-3/4" ~ Casin Shoe De th Hole Depth Pumpin Shut-in Pumpin Shut-i n RKB-CHF: 36.7 Ft 2727.0 Ft-MD 2377.0 Ft-TVD 2757.0 Ft-MD 2394.0 Ft-TVD Strks psi Min psi Strks psi Min psi Casinq Size and Description: USE PICK LIST ~ 0 70 0 3500 0 40 0.00 1010 Casin Test Pressure Int e rit Test 2 305 1 3500 1 55 0.25 975 Mud Weight: 9.9 ppg Mud Weight: 9.7 ppg 4 600 2 3500 2 140 0.50 950 Mud 10 min Gel: 21.0 Lb/100 Ft2 Mud 10 min Gel: 21.0 Lb/100 Ft2 6 840 3 3495 3 280 1.00 900 Test Pressure: 3500.0 psi Rotating Weight: ####### Lbs 8 1025 4 3495 4 360 1.50 8 Rotating Weight: 74000.0 Lbs Blocks/Top Drive Weight: 74000.0 Lbs 10 1205 5 3495 5 490 2.00 86 Blocks/Top Drive Weight 74000.0 Lbs Desired PIT EMW: 18.0 ppg 12 1390 6 3495 6 600 2.50 840 Estimates for Test: 0 bbls Estimates for Test: 1026 psi -0.1 bbls 14 1580 7 3495 7 680 3.00 830 ~ t ~ 16 1800 8 3495 8 760 3.50 820 EMW = Leak-off Pressure + Mud Weight = 1030 PIT 15 Second 18 2005 9 3495 9 830 4.00 815 + 9 7 0.052 x ND 0.052 x 2377 Shut-in Pressure, psi 20 2240 10 3490 10 895 4.50 805 EMW at 2727 Ft-MD (2377 Ft-ND) = 18.0 9~5 22 2490 15 3490 11 960 5.00 800 aooo Lost 20 psi during test, held 24 2720 20 3490 12 1000 5.50 795 99.4% of test pressure. I ?Fi ?975 ~5 34A5 1~ 5 1(l3~ Fi ~~ 7q~ 3500 3000 2500 ~ ~ N 2000 W ~ a isoo iooo 500 0 0 1 2 3 4 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Volume Vol ~~CASING TEST f-LEAK-OFF TEST O PIT Point PUftl ed Bled Back PUI71 ed Bled . S S . S Comments: Tested 9 5/8" csg after bumping plug on cmt. Job 78~~ Summary ~ ~ ConocoPhilli $ Casing Detail ~ 7" Casinq Well: CD4-306 Date: 7/23/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB 34.65 FMC GenV Hanger 1.52 34.65 Jts 102 to 242 141 Jts 7" 26# L-80 BTCM Csg 6012.08 36.17 Tam Port Collar 2.37 6048.25 Jts 3 to 101 99 Jts 7" 26# L-80 BTCM Csg 4197.85 6050.62 Weatherford Float Collar 1.30 10248.47 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 84.29 10249.77 Ray Oil Tools " Silver Bullet " Float Shoe 2.10 10334.06 10336.16 7" Shoe @ 10336.16 8 3/4" hole @ 10346.00 8-3/4" Hole TD ae 10,346' MD / 7253.57 TVD 7" Shoe ac 10,336.16 ' MD / 7246.71 ' TVD Total Centralizers: 59 Straight blade centralizer one per jt on jts # 1-14 Straight blade centralizer one per jt on jts.109 to 121 Straight blade cent. one per jt, on joint #'s 179,180,181 Straight blade cent.one on every other jt.# 183 to 239 255 joints in shed - 242 total jts. to run Last 13 jts. Out Use Run & Seal pipe dope Average make up torque 8000 ft/Ibs Remarks: Up Wt - 310 k Dn Wt - 170 k Block Wt - 75k Supervisor: D. Lutrick / D. Mickey ~ ConocoPhilli s p ~ CASING TALLY PAGE: 1 of 2 WELL NUMBER: CD4-306 RIG: Doyon 19 TUBING DESCRIPTION: 7", 26# L-80 BTCM DATE: 07/23/07 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 43.58 26 40.29 51 43.11 76 42.48 101 43.11 126 42.75 151 42.58 176 43.44 2 40.71 27 42.99 52 38.42 77 42.71 102 40.78 127 41.72 152 42.96 177 43.57 3 39.88 28 41.01 53 43.02 78 43.51 103 41.35 128 43.13 153 42.45 178 43.44 4 43.52 29 42.85 54 43.47 79 43.45 104 43.01 129 43.51 154 42.06 179 43.51 5 42.93 30 43.58 55 37.40 80 43.42 105 43.02 130 40.07 155 43.48 180 43.20 6 43.56 31 42.95 56 43.00 81 42.53 106 43.11 131 41.92 156 43.13 181 43.02 7 42.95 32 43.01 57 42.69 82 43.10 107 43.46 132 43.51 157 43.25 182 41.88 8 40.09 33 43.46 58 42.60 83 42.39 108 43.00 133 42.34 158 42.96 183 43.02 9 39.58 34 43.16 59 43.48 84 40.76 109 42.20 134 41.71 159 43.29 184 42.74 10 43.33 35 43.42 60 43.28 85 43.45 110 43.45 135 42.94 160 43.43 185 43.11 11 43.08 36 41.52 61 43.46 86 43.10 111 43.55 136 42.44 161 43.12 186 43.55 12 43.12 37 43.07 62 42.82 87 43.13 112 43.45 137 42.74 162 42.91 187 42.04 13 42.97 38 40.48 63 43.13 88 41.27 113 42.08 138 43.02 163 43.55 188 42.43 14 43.56 39 34.80 64 41.53 89 42.94 114 43.63 139 43.05 164 43.58 189 42.92 15 43.52 40 43.14 65 43.47 90 43.45 115 42.91 140 43.58 165 43.02 190 42.01 16 43.43 41 41.18 66 42.95 91 39.65 116 42.11 141 40.25 166 43.43 191 43.41 17 43.45 42 43.03 67 43.02 92 43.57 117 43.68 142 43.44 167 42.62 192 41.66 18 40.80 43 43.02 68 43.46 93 42.29 118 42.56 143 42.95 168 42.59 193 43.52 19 40.58 44 43.52 69 42.32 94 42.94 119 43.04 144 34.01 169 37.60 194 41.04 20 40.24 45 41.87 70 42.68 95 41.87 120 41.35 145 43.53 170 42.08 195 41.96 21 42.44 46 40.96 71 43.53 96 42.39 121 42.95 146 41.97 171 43.75 196 42.54 22 40.11 47 43.00 72 42.36 97 42.94 122 42.07 147 43.47 172 40.64 197 43.12 23 43.01 48 41.23 73 43.11 98 41.82 123 42.06 148 42.40 173 40.37 198 43.45 24 42.95 49 42.89 74 42.67 99 43.02 124 42.67 149 42.03 174 43.45 199 43.01 25 42.75 50 42.95 75 43.41 100 42.94 125 40.89 150 43.65 175 43.54 200 43.00 Tot 1056.14 Tot 1053.38 Tot 1064.39 Tot 1065.12 Tot 1065.49 Tot 1056.13 Tot 1065.84 Tot 1070.59 TOTAL LENGTH THIS PAGE = 8497.08 TOTAL JOINTS THIS PAGE _ DIRECTIONS: 200 FLOAT SHOE FLOAT COILAR HANGER RKB ~ ~ ConocoPhilli s p CASING TALLY PAGE: 2 of 2 WELL NUMBER: CD4-306 RIG: Doyon 19 TUBING DESCRIPTION: 7", 26# L-80 BTCM DATE: 07/23/07 Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 43.03 226 40.08 251 42.55 276 301 326 351 376 202 43.56 227 43.55 252 41.34 277 302 327 352 377 203 42.53 228 43.21 253 43.00 278 303 328 353 378 204 43.00 229 43.01 254 43.42 279 304 329 354 379 205 43.44 230 43.53 255 42.83 280 305 330 355 380 206 42.93 231 43.00 256 281 306 331 356 381 207 41.36 232 43.29 257 282 307 332 357 382 208 43.52 233 41.98 258 283 308 333 358 383 209 43.45 234 40.66 259 284 309 334 359 384 210 43.10 235 42.57 260 285 310 335 360 385 211 41.89 236 40.62 261 286 311 336 361 386 212 43.52 237 42.38 262 287 312 337 362 387 213 43.43 238 41.92 263 288 313 338 363 388 214 43.45 239 42.04 264 289 314 339 364 389 215 43.46 240 43.53 265 290 315 340 365 390 216 43.47 241 43.43 266 291 316 341 366 391 217 43.46 242 43.46 267 292 317 342 367 392 218 42.12 243 42.99 268 293 318 343 368 393 219 42.63 244 43.44 269 294 319 344 369 394 220 42.71 245 43.45 270 295 320 345 370 395 221 43.36 246 42.92 271 296 321 346 371 396 222 43,51 247 43.58 272 297 322 347 372 397 223 43.55 248 42.13 273 298 323 348 373 398 224 40.90 249 43.07 274 299 324 349 374 399 225 43.50 250 42.90 275 300 325 350 375 400 Tot 1074.88 Tot 1066.74 Tot 213.14 Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 2354.76 TOTAL LENGTH = 10851.84 DIRECTIONS: TOTAL JOINTS THIS PAGE = 55.00 TOTAL JOINTS = 255.00 AVERAGE JT = 42.56 Cement Detail Report CD4-306 Intermediate Casing Cement Comment Dowell pumped 20 bbls CW100, 30 bbls 10.5 ppg MudPush, dropped bottom plug, 86 bbls 15.8 ppg cement (416 sx), dropped top plug and 20 bbls water Rig displace cement with 369 bbis 9.8 ppg mud at 6 bpm. Reduced rate to 3.5 bpm last 10 bbls. Bumped plug with 750 psi circ pressure. Pressure csg to 1250 psi. OK. Check floats. OK. Full returns throughout job. Description Objective Top (ftK8) Bottom (ftK6) Full Retum? Cmnt Rtrn (... Top Plug? Btm Plug? Primary Cement Kuparuk and 8,169.0 10,336A [!i~ 0.0 Yes Yes Nanuq formations Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 4 6 750.0 1,250A ~ 10.00 No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out 70 (ftKB) Drill Out Diam eter (in) Fluid Type Fluid Description Estimated Top (ftK8) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 8,169.0 10,336.0 416 G 86.0 Yield (ft'/sack) Mix H20 Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1(psi) 1.16 5.08 15.80 Additives Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... 7op Plug? Btm Plug? Primary Cement to isolate the K-2 4,900.0 6,048.0 No Yes No Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 4 4 No No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Dowell pumped 20 bbls CW100. Tested lines to 4000 psi. Pumped 30 bbls 10.5 ppg MudPush, 43 bbls 15.8 cement (206 sx), drop closing dart, 20 bbls water followed by 42 bbis mud. Tail Cement 4,900.0 6,048.0 206 G 42.0 Yield (ft'/sack) Mix H20 Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1(psi) 1.17 15.80 Page 1/1 tig: DOYON 19 Security Level: Developmentl Daily Drilling Report C D4-306 Report Number: 9 Report Date: 7/22/2007 CD4-306 Development NANUQ KUPARUK 7/14/2007 8.05 10,346.0 10,346.0 0.00 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 2,000.00 276,486.50 480,514.00 2,697,613.50 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) intermediate, T0,336.2ftK6 Ops and Depth @ Morning Report 24hr Forecast Test 4" pipe rams RIH w! 4" DP for 2nd stage port coilarjob. POH. RIH w1 bit to float I' collar Last 24hr Summary Finish LD BHA - RU to run 7" csg - Ran 7" csg to 10,366' - Circ for cmt job - Test surface equipment. General Remarks Weather Head Count 36? - NE @ 12 mph - Vis 3/8 mi - OVC/Fog 50.0 supervism ; i T~r~, °;' :: Donnie Lutrick, Rig Supervisor Rig Supervisor Don Mickey, Rig Supervisor Rig Supervisor 00:00 00:45 0.75 INTRM1 DRILL PULD P 0.0 0.0 Finish LD BHA. 00:45 01:15 0.50 INTRM1 DRILL OTHR P 0.0 0.0 Clear floor of misc subs and equipment. 01:15 02:15 1.00 INTRM1 WELCTL EQRP P 0.0 0.0 Change upper pipe rams from 3 1/2" x 6" VBR's to 7". 02:15 02:45 0.50 INTRMI WELCTL OTHR P 0.0 0.0 Pull wear bushing. Install test plug. 02:45 03:15 0.50 INTRM1 WELCTL BOPE P 0.0 0.0 RU and test 7" pipe rams to 250 - 5000 psi. RD. 03:15 03:45 0.50 INTRMI CASING OTHR P 0.0 0.0 Install thin wear bushing for running csg. 03:45 04:15 0.50 INTRMI DRILL RURD P 0.0 0.0 RD Geospan unit. 04:15 05:45 1.50 INTRM1 CASING RURD P 0.0 0.0 RU 7" csg equipment. 05:45 06:00 0.25 INTRMI CASING SFTY P 0.0 0.0 PJSM on running 7" csg. 06:00 10:30 4.50 INTRM1 CASING RNCS P 0.0 3,392.0 Run 7" 26# L-80 BTCM as follows: Float shoe (Ray IOiI Tools silver bullet) 2 jts - Float collar - 2 jts ( firsr four connections made up w/ BakerLoc - filled pipe & checked floats) - 76 jts (80 jts total ) to 3392' PU wt. 140 SO wt 125 10:30 11:00 0.50 INTRM1 CASING CIRC P 3,392.0 3,392.0 Circ btms up +@ 3392' - stage pumps up to 5 bbls/min - FCP 290 psi 11:00 15:00 4.00 INTRMI CASING RNCS P 3,392.0 6,796.0 Continue running 7" 26# L-80 BTCM csg - to 4285' (101 jts total in hole) - Install Tam PC & BakerLoc connections - Continue running 7" csg f/ 4287' to 6796' ( 160 jts total in hole ) 15:00 16:00 1.00 INTRMI CASING CIRC P 6,796.0 6,796.0 Establish circ - Circ btms up +@ 6796' - Stage pumps up to 5 bbls/min FCP - 430 psi 16:00 18:45 2.75 INTRM1 CASING RNCS P 6,796.0 9,362.0 Continue running 7" 26# L-80 BTCM csg f/ 6796' to 9362' ( 220 jts total in hole) 18:45 20:00 1.25 INTRMI CASING CIRC P 9,362.0 9,362.0 Establish circ & circ btms up + stage pumps up to 5 bbls/min FCP - 500 psi 20:00 21:00 1.00 INTRMI CASING RNCS P 9,362.0 10,336.0 Continue running 7" 26# L-80 BTCM f/ 9362' to 10,300 ( 242 jts total ran) PU FMC fluted hanger & landing jt. Land csg in wellhead w/ FS @ 10,336' & FC @ 10,248' - TAM PC @ 6048' Latest BOP Test Data ~ Page 1/2 Report Printed: 7/27/2007I Security Level: Development Zig: DOYON 19 Daily Drilling Report CD4-306 Report Number: 9 Report Date: 7/22/2007 21:00 21:30 0.50 INTRMI CASING RURD P 10,336.0 10,336.0 LD fill up tool - Blow down TD - RU - Cmt head & lines 21:30 2330 2.00 INTRMI CEMENT CIRC P 10,336.0 10,336.0 Establish circ - Circ & condition for cmt job - Stage pump up 5.5 bbls/min - 470 psi. 23:30 23:45 0.25 INTRMI CEMENT SFTY P 10,336.0 10,336.0 PJSM on cementing 7" csg. 23:45 00:00 0.25 INTRMI CEMENT SFEQ P 10,336.0 10,336.0 Dowell pumped 5 bbis CW100. Test lines to 4000 psi. vvater Based Mud 8.31 9.81 I 10.51 freeze protect Wellbore Name Wellbore API/UWI CD4-306 501032055000 section ~;ze;(in) , ;.. Act Tflp ~fltLe} act Hfrii.{#t~..~, .. . : starl C1~te , EridN . ate . :_~. COND1 16 OA 114.0 6/12/2007 6/12/2007 SURFAC 12 1/4 114.0 2,737.0 7/14/2007 7/16/2007 INTRM1 8 3/4 2,737.0 10,346.0 7/18/2007 7/21J2007 ~• :. ~u~re Data ~° ~ ..~~~~ ~ .~: ~ ~ _~~ ~~ .' MO {ftKB} incl {°j Azm{'} 7Ut3 jflK6} ' ~S {3t~ , NS'{#1J EW (Pt~ ~i.-S {°!7{I(lt#) 10,346.00 50.06 295.66 7,253.03 6,845.05 3,087.95 -6,108.95 0.00 Page 2/2 Report Printed: 7/27/2007 Security Level: Development ;ig: DOYON 19 Daily Drilling Report CD4-306 Report Number: 10 Report Date: 7/23/2007 10188966 5,295,000.00 Wellbore Well Type Field Name Original Spud Date DFS (days) Depth StaR (ftKB) Depth End (ftK6) Depth Progress (ft) CD4-306 Development NANUQ KUPARUK 7/14/2007 9.05 10,346.0 10,346.0 0.00 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 5,677.18 282,163.68 160,044.18 2,857,657.68 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 10,336.2ftK6 Ops and Depth ~ Morning Report 24hr Forecast RIH w! clean out assembly on 4" DP RIH with clean out assembly on 4" DP. Clean out to float collar. Displace to brine. POH LD DP. Last 24hr Summary Cmt 7" csg - test csg - Set 8~ test PO - RIH and complete 2nd stage cement job through port collar at 6048'. POH. General Remarks Weather Head Count 33?-NE@16mph-Vis 10mi-OVC 48.0 Don Mickey, Rig Supervisor P 10,336.0 10,336.0 Dowell pumped 20 bbls CW100, 30 bbls 10.5 ppg MudPush, dropped bottom plug, 86 bbls 15.8 ppg cement (416 sx), dropped top plug and 20 bbls water. Rig displace cement with 369 bbls 9.8 ppg mud at 6 bpm. Reduced rate to 3.5 bpm last 10 bbls. Bumped plug with 750 psi circ pressure. Pressure csg to 1250 psi. OK. Check floats. OK. Full returns throughoutjob. 02:00 02:45 0.75 INTRM1 CASING DHEQ P 10,336.0 10,336.0 Test 7" csg to 3500 psi for 30 min. 02:45 03:45 1.00 INTRMI CEMENT RURD P 0.0 0.0 RD cement head and lines. LD LJ. RD elevators and bales. 03:45 04:45 1.00 INTRM1 CASING DHEQ P 0.0 0.0 Pull thin wear bushing. Install pack-off and test to 5000 psi. 04:45 05:45 1.00 INTRM1 WELCTL EQRP P 0.0 0.0 Change upper pipe rams from 7" to 3 1/2" X 6" VBR's. 05:45 06:30 0.75 INTRM1 WELCTL OTHR P 0.0 0.0 Set test plug w/ 4" test jt. & test VBRs to 250 & 5000 psi 06:30 07:30 1.00 INTRM1 DRILL PULD P 0.0 0.0 !D test jt - PU drilling bales & DP elevators - PU test jt & pull test plug - Set wear bushing 0730 08:00 0.50 INTRMI CEMENT PULD P 0.0 0.0 MU Baker plug launching head w/ XO's & pup jts - LD 08:00 08:30 0.50 INTRM1 CEMENT PULD P 0.0 24.0 MU Tam combo tool w/ XO 08:30 13:45 5.25 INTRMI CEMENT TRIP P 24.0 6,019.0 RIH w/ combo tool on 4" DP f/ 24' to 6019' - PU wt. 158 SO 128 13:45 14:45 1.00 INTRMI CEMENT PULD P 6,019.0 6,048.0 PU 1 single of DP & PU Baker plug launching head assembty to 6048' 14:45 15:45 1.00 INTRMI CEMENT CIRC P 6,048.0 6,048.0 Establish circ @ 3 bbls/min 450 psi - Drop ball & pump down to ball seat - pressure up to 800 psi - Open TAM PC - 15:45 16:30 0.75 INTRMI CEMENT CIRC P 6,048.0 6,048.0 Circ btms up f/ TAM PC @ 6048' - prep for 2nd stage cmt job Latest BOP Test Data ,~ ~~:<:, ?.. . ~ ,~ ~ 1~ace : . . : ; ~' ~ :.~omme€~t : n 7/17/2007 Witnessed b AOGCC Page 1/2 Report Printed: 7/27/2007 Security Level: Development Daily Drilling Report CD4-306 Report Number: 10 tig: DOYON 19 Report Date: 7/23/2007 :: ~r~t~ ~.a . ,.. . y~ - ~ . .. . , ~ .,; : ,. ~ , ~ ~ ~a~~,~,., z: ~. , . ~ <> .' , , „ ;;~~;c, 3~t ' .; Elu[ ' ' '' ~za` , ~; Time ' ;_' ' depth Start ' t3epth End " rr v\ ~ €ime ~ ittie (~trSl f?Ea~ Qp.:Code' ' ~ ~WS~1rCt#!~; ; P-PI f , : Trbl Cods TrbE CIass: : ' (~~3 {flK6} : :. L~peraiiv~ 16:30 17:30 1.00 INTRM1 CEMENT DISP P 6,048.0 6,048.0 Dowell pumped 20 bbls CW100. Tested lines to 4000 psi. Pumped 30 bbls 10.5 ppg MudPush, 43 bbls 15.8 cement (206 sx), drop closing dart, 20 bbls water followed by 42 bbls mud. 17:30 18:00 0.50 INTRMI CEMENT OTHR P 6,048.0 6,048.0 Shear plug at 2100 psi. Close Tam port collar. Test port collar to 1000 psi.. Shear ball at 3000 psi 18:00 19:00 1.00 INTRMI CEMENT CIRC P 6,048.0 6,048.0 Reverse circ 2 drill pipe volumes at 3.5 bpm at 610 psi. 19:00 19:30 0.50 INTRM1 CEMENT RURD P 6,048.0 6,048.0 RD Baker top drive swivel. 19:30 20:30 1.00 INTRM1 CEMENT TRIP P 6,048.0 5,073.0 POH on trip tank from 6048' to 5073'. 20:30 22:00 1.50 INTRMI RIGMNT SVRG P 5,073.0 5,073.0 Slip and cutting drilling line. Service top drive. 22:00 00:00 2.00 INTRMI CEMENT TRIP P 5,073.0 3,294.0 Pump dry job. POH on trip tank from 5073' to 3294'. Mud ~ k~eck C )~::' ~~~~_. ~~.; ,,. ~':.... :_- '~Y p~, i. I QBpfM,~ fEI~B) ISertS ~IYri gs~j ~s {~4~~ , Rlt ~~ .~R Ga ~1~~~ „~ihfltOfN le E?} ` Gei {10s} GQ] (IBff3 ~ft°} :{[bff {10m} lCN3tt'j ', iiet {~ {I1~f4~ Crt) tfA~} t~18? { HT itf/bhi~ j~I HF Filt J36min~ ~~ p~•~ . pee~?~rty Tem~, S~itdS Cofr: " ~ F) .; (',6~ . '', '' 9.70 37 9.0 15.000 7.0 9.0 11.000 8.4 ' Diesel 60.0 freeze protect CD4-321 Fresh Water 150.0 annular flush CD4-321 Water Based Mud 1272.0 f/ CD4-306 to CD4-321 11~e~IblsTes ' ~ y . ~ ~ <.; . ~ ~ ,~ - ;. ;~~ ~ ~~~~.;: ... , .. : Wellbore Name . Wellbore API/UW I CD4-306 501032 055000 . ~ S?chpn ., . , Size~~t) ;:. . .; .... . .r.. Aet;Tdaapp~tCKa};, ' ': a.ctatrri(~f1c8~, ..: : , ~._.; ta[t-,D,"ai~; ; ~~ ~~dI7ate ; ,. ..... . COND1 16 0.0 114.0 6/12/2007 6/12/2007 SURFAC 12 1/4 114.0 2,737.0 7/14/2007 7/16/2007 INTRMI 8 3/4 2,737.0 10,346.0 7/18/2007 7/21/2007 „ ,, ~..u` ~1~t~ ` ..as.=a..+~,~.:n.~ ~ ~ ~` °° 4 ` ~.1,'~~j~L~~.. ;'- ME) (ftK8) Ittra {~; c~. , A~a {°~ Ti~F3 {ftKS) Y5', {fl).: :'= MS {ftj EUW,~fty'F, LTl:$;~:°d9 QOCt~ 10,346.00 50.06 295.66 7,253.03 6,845.05 3,087.95 -6,108.95 0.00 ~~:rrtent ; < ' ~ ~ ~ ~ ~ ~ ' ~ ~° ~,~ " ' ~ ~ : . , .:. . ~ ,_ ° ~ . : 4 _. , , s. , ~ ~ .~~~w> Intermediate Casin Cement - Started 7/23l2007 Type Wellbore Cemented String Cement Evaluation Results casing Intermediate, 10,336.2ftKB Stg No. Description Top (ftK6) Bottom (ftKB) Q(end) (bbl/... P(final) (psi) 1 Primary 8,169.0 10,336.0 4 750.0 fiuid' ~ ~ ~.. .. : ~3ajs ". . R~mt {sadcs~ 4t (6bi) , „~sity {lbfi~€~. - ~eid {ft'Isadc~ ~~# T oA {~ ~ ,; . .; ;~"~5t 8tm {itK6)' ' Tail Cement G 416 86.0 15.80 1.16 8,169.0 10,336.0 Stg No. Description Top (ftKB) Bottom (ftKB) Q(end) (bbl/... P(final) (psi) 2 Primary 4,900.0 6,048.0 4 i . . .,..:~luid' ,.;., GE~S ,. ~,,,. .:... .. t ~~~~~; K„ ' ,;;, U {bhi} ..z: L3CrtsitY {]b/£~E~ >.;; .~eEd~~'t5,~c}r~ ~,`. .~~~7 0p ~~} ; ., i . . . ~st 62m {RK6) Tail Cement G 206 42.0 15.80 1.17 4,900.0 6,048.0 Page 2/2 Report Printed: 7/27/2007 PRESSURE INTEGRITY TEST Well Name: CD4-306 Rig: Drilling Supervisor: Lutrick / Mickey Type of Test: Annulus Leak Off Test for Disposal Adequacy Hole Size: 9-~/8" ~ Casin Shoe De t RKB-CHF: 34.7 Ft 2727.0 Ft-MD 2377.0 Casinq Size and Description: 9-5/8" 40#/Ft L-80 BT( CONOCOPHILLIPS Alaska, Inc. Doyon 19 Date: 7/24/2007 Volume Inpu -~ Pump used: Cement Unit ~~ garrels ~ ~ Pumping down annulus. ~ Cas h Hole Depth Pumpinq ~ Enter outer casfng shoe test results in comments nnud we~gnt: y.y ppg Casing description references outer casing string. Inner casing OD: 7.0 In. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing OD at right. Desired PIT EMW: 15.0 ppg Estimates for Test: 630 psi 0.4 bbls . 'L . IW = Leak-off Pressure + Mud Weight = 623 + 9 9 PIT 15 Second 0.052 x ND 0.052 x 2377 Shut-in Pressure, psi EMW at 2727 Ft-MD (2377 Ft-ND) = 14.9 451 1000 W ~ 7 N 500 W ~ a Pump Rate: Bbls/Strk ~ ' 0.80 Bbl/min ~ Shut-in Pumpin Shut-in lin psi Bbls psi Min si 0 0 56 0.00 483 1 0.5 180 0.25 451 2 1 275 0.50 437 3 1.5 367 1.00 432 4 2 451 1.50 4. 1 3.501 4231 5.00 419 5.50 419 y b~ts" casmg snoe N~ ~_ ~ ts.u ppg Summary 0 0 1 2 4 5 6 7 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes ~CASING TEST ~~LEAK-OFF TEST O PIT Point ConocoPhillips Alaska MALLIBURTON ~~~~ WELLPATH DETAILS Rig: CDJ-306 KuparuA Sand Injccror Rig: Docon 19 Rcf Damm~ Rig. CD4306 5623ft VScc[ion Ongin Ongin Staning Anglc +N/-S +E/-W From 7'VD 296.%fi° U.00 0.00 36 fi3 Quarter Mile (1320 feet) radius plot SURFACE CASING SHOE SEPARATION FROM CD4-306 CD4306 x v Surface Casin Shoe ASP 4 Coordinates NAD 27 378077.36 5957502.61 ells Nanuk 7 Nanuk 2 petai~s ~ AOGCC"" n n p~~, plsp, Permit # ermit Date ource well Ann. Vol. tart Date nd Date a ance from Object well• Surface csg. Shoe X Coord. Surface csg. Shoa Y Coord. Surf LOT (ppg) Surface casing ND (ft) Annular lOT (ppg) enta Exploretio 'd Expl ion P&A'd Nanu 3 Nanu b 1582 1285 376499.5 378326.6 5957382. 5956241. 11.8 14.9 1781 2393 15.1 ploration, X-Y location calculated at 240 ND, NOT the surface shoe de th Not for annular dis osal CD2-S78 305-373 12/9/2005 CD4208, CD4318, CD4-209, CD4320 32010 12/14/2005 7/2/2006 1936 377174.7 5955790. 18.4 2400 16.1 CD4208 CD4318 CD4209 CD4270 CD4320 306-183 306-181 5130/2006 5/26/2006 CD4318a, CD4320, CD4214, CD4321,CD4211 CD4209, CD4320 61839 942 7/3/2006 5/31/2006 1/4/2007 8/2/2006 712 2277 1 75 6 3781 .2 • 59 7. 37 .4 9 08. 37 . 57 . 377547.4 963.2 77914. 5958105. .3 18.2 14. 18.0 17.1 243 237 2377 2386 2378 14.4 17.1 17.5 17.3 17.8 volume extension to 70000 bbl, permit #3 266 Unable to pum SD pumping Not for annular dis osal Not for annular dis osal CD417 CD4321 CD4214 CD4217 CD4215 n 306-393 30fr392 1/2/2007 12/29/2006 D4302, CD416 9091 /20/2007 9 7 14 6416.3 375795. 40. 377 .3 0.5 5 72 . 5. 56962. 5957494. 5956918. 18.1 18.0 17.3 18.1 17.6 2387 2385 236 2391 2392 16.2 16.3 17.6 15.0 17.50 Not for annular disposal, due to proximity t Nanuq 3 Not for annular dis osal 2nd annular LOT, 1 st ann test 18.4 CD4213 n 1 2 37 46.8 5956586. 18.1 238 21.40 Not for annular disposal. High Ann test Probabl ice lu , will retest'rf needed CD4302 n 379247.7 5957393. 18.1 2394 17.10 CD416 n 377883.1 5957456. 18.1 2 17.9 CD4306 n 0 378077.4 5957502. 18.0 2377 14.90 • Lateral distance in feet, betw surface casing shoes, in the X-Y plana "" As of Nov. Dec. 8, 20 Note that this sheet i t the definitive record for annular disoosal volumes / ~~ ~ ~,1~,~ P~ ~ ~~ ~ ~~~"°~~~~ ~ ~~~~~ ~~ ~ i ~- Note to File CD4-306 (207-094307-258) Co{ville River Uni# (Nanuq-Kuparuk) ConocoPhil{ips Alaska, Inc Phillips has made appiication for annular dispcasal for the subject weA. This document examines #he pertinent information for the weli and recommends approval ofi ConocoPhillip~ reques#. --No unusuai events were reported while driNing the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Appro~mateiy 130 bbts of cement was circulated to surface. The net cement remaining in the surface hole was 42°!o XS of the cafculated hole volume, --On the initial leak off test, the pressure slo~ rises exhibiting 2 slopes to the determined F1T point at 18.0 EMW. 2 siopes are not uncornmon in CRU. Minimal fluid was pumped into the formations. Du~ng the observation period, the pressure deciined to abaut i6.0 EMW. The 'rnitial teak off indica#es that the surfac~ casing shoe is well r.emented. --No problems ar~ reported drilling the intermedia#e hole. The T casing was run and successfully cemented. Full rQtums were noted and the casing was reciprocated. --An injectivit~r test down 9-5l~ x T annufus was conducted. Pressure steadily increases un#i# the break at 14.9 EN~N, The pressure declined witt- additional pumping to 14.2 EMW. Du~ng the observation period, the pressure declined to 13.2 EMW, The lower EMW of the purnp in tests indicate tha~t the planned disposal should be conduct+~d at EMWs beiow that of th~ shoe integrity. --CPA provided a{isting of all surFace casing shoes within !4 mite radius of CD4-306. The nearest well is ~G1t~ distant wi#h 2 other wells a# fifip and ~1Q- distant; Nanuq 3 is ~1040~ distant at 8 o'docic from the surFace sh~. An +~xamination of the cementing information for all wells did not reveal any problem that woutd preclud~ granting CPA's request for CD4-306. Nanuq 3 is sufficiently di~tan# that its uncemented annulus should not be of concern. Based on examination of the submitted infQrrna#ion, { recammend approval ofi ConocoPhillips' request for the subject well. E~ 1 Tom Maunder, PE Sr. Petroleum Engineer September 4, 2007 G:\common~tomrnaunder\Well InformationlBy Subject~4nnular Dispasali070822--CD4-306.doc ~ • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 22, 2007 12:34 PM To: Liz Galiunas; Brian IVoel; Chip Alvord; Vern Johnson Subject: Annular Disposal Applications CD4-16, CD4-302 and CD4-306 All, I am working on these applications. One item missing is the spreadsheet tha# summarizes the weH proximity informatior~. 1'd appreciate if someone would send me the appropriate sheets. Calt or message with any questions. Tom Maunder, PE AOGCC 8/22/20p7 ~ . Note to File CRU CD4-16 (PTD 2061310) CRU CD4-302 (PTD 2070560) CRU CD4-306 (PTD 2070940) / August 15, 2007 Re: ConocoPhillips' ApplicaNon for Sundry Approval for Annular Disposal of Drilling Wastes within Wells CD4-16, CD4-302, and CD4-306 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annuli ofwells CD4-16, CD4-302, and CD4-306. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9-5/8" surface casing shoes are set in these wells between 2,319' to 2,335' true vertical depth subsea ("TVDSS"), near the base of a 35-foot thick shale and claystone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of sandstone open to the annulus of these wells to accept the proposed injected fluids. 3. The lower confining layer is sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal intervals. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed annular injection activities will be limited to a radius of less than 225' from the wellbores. Discussion CPAP s application was reviewed along with records from nearby wells Nanuk 1 and Nanuk 2. The discussion that follows is based on well logs and mud logs from these wells. An index map is provided, below. The proposed injection interval in these wells lies in the Seabee formation within Section 19, T11N, RSE, UM and in Section 24, T11N, R4E, UM, which are 2 to 3 miles from the current boundary of the CRU. The 9-5/8" surface casing shoes of the wells lie at about 2,319' to 2,335' T'VDSS, near the base of a 35- foot thick interval that is dominated by claystone and shale and is continuous throughout the area. This interval will provide upper confinement for fluids disposed in the annulus of the well. The annulus proposed for disposal of drilling wastes extends downward from the surface casing shoe to the top of cement for the 7" casing string, which is estimated to range from 3,693' to 3,717' TVDSS. The most likely portion of the open annulus that will accept injected waste is a 40 to 55-foot thick interval containing several 1- to 4-foot thick beds of silty sandstone and sandstone that lie between about 2,400' • • CD4-16, CD4-302, and CD4-306 August 15, 2007 Note to File Page 2 of 3 and 2,450' TVDSS, which is just below the surface casing shoe. The aggregate thickness of thin potential injection beds is about 9' to 1 l'. The injection beds are separated by thin shale and claystone intervals. Beneath the injection zones is a 55' thick interval of shale, claystone and tuff that is continuous throughout the area. This interval, which lies between about 2,565' and 2,660' i'VDSS, will provide lower confinement for any injected wastes. ; _ . , ~ ~ . _...., 4~ Q ~U:.uL- . ' . . . ~ L,~ ~ '...~ . "~t . . . ~` ... ` ~.. ~ To '? , ` P -_ _. _ _ `` __ `,,, ~ d 4-31 ~ ~`, ~J ~1 ~~ 'i; Nanuk 1 Index Map [n this area, the base of permafrost occurs at about 700' TVDSS in this area. The base of permafrost lies about 1,700' above the top of the proposed injection intervals. The shallow geologic section in the area surrounding CD4-Pad contains methane gas. Records from Nanuk 1 and Nanuk 2 indicate that traces of inethane were first measured between and 460' and 70' TVDSS, respectively. Both wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (typically 9.9 to 10.4 pounds per gallon). The shallowest occurrences of more significant amounts of inethane encountered in these wells (arbitrarily placed at 20 units of gas on the mudlog) were 1,890' and 2,170' TVDSS, respectively. So, the entire proposed disposal zone may contain some methane gas. Supporting documentation to ConocoPhillips' annular disposal applications states: "There are no USUW aquifers in the Colville River Unit." This is correct. Conclusion 3 of Area Injection Orders 27 and 28, which governs the Nanuq and Nanuq-Kuparuk Oil Pools, state that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. The shallowest oil shows observed in nearby wells Nanuk 1 and Nanuk 2 occur at 3,765' TVDSS and 4,710' TVDSS, respectively. The mudlogging geologists rated these shows as being fair to good shows in quality. However, these oil shows occur more than I,000' below the proposed disposal intervals. . ' • ~ CD4-l6, CD4-302, and CD4-306 Note to File August 15, 2007 Page 3 of 3 The following chart provides an estimate of the affected areas surrounding the affected wellbores. A worst-case assumption will be made. A count of sand in the most likely disposal zone between 2,400' and 2,450' TVDSS indicates that about 10' of net sand can be counted using the gamma ray curve. Inspection of the neutron and density porosity logs for correlative intervals in offset wells suggests an average sand and siltstone porosity of 12% at this depth. Based on these values, the area most strongly impacted by the proposed annular injection activities will be limited to a radius of less than 225' from the wel lbores. Injected Fluid vs Affected Radial Distance CD4-16, CD4-302, CD4-306 Wellbores (assumes 10' aggregate injection zone thickness and 12% porosity) 300 . i - _ ~ I ' ~I-T -~- m 250 m i o _ a 3 2~ f _ E o , _ m U C IJV . m ,,t p . . . . . ~~"~~/ Q i W ~~ ' W 100 ~i~ a 0 . _~_ . i~ . . . G1 • % a ~ ', ~~ 0 +' -- .. ;- --.." ~-` ' _~_--- - ._. -' -~ '~ ~ -- - -- --~-- 0 5,000 10,000 15,000 20,000 Amount of InJected Fluid (barrels) 25,000 30,000 35,000 The limited volume of rock that will be affected by this proposed disposal injection program contains methane gas, is situated beneath more than 700' of permafrost, and is bounded above and below by continuous layers of claystone and shale. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbon accumulations within the proposed zone of injection. This injection zone lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. I re mmend approval of this annular disposal praject. ~ Steve Davies Senior Petroleum Geologist ~ I~C:iANICAL ~.NTEGRITY R :~ORT _ ~UD ~:_~_ : : ~`.~1^-1;''C)~ OPE~2 ~ FZEZ.TJ :~G r~~~ =5~. - ~I~}~ ^V ~ i::_L.L NUI~E~Z ~ 1 ~~ ~ ~ ~°~_~~ ~.ti2~ C,~,~"~ ~~3 ~ ~ LL D~ I ~ TD . Y~'~'3~t ~ ?~_. ~ ~-~5 ~ 'r~ ; r ~TD . 1 ~J ~S "v1 ?~D ~ 1~L ~ ?"VI) C~si~~, `1~~ Shoe: ~C~~(;~ MD '1'~``i~ TVD; yV. ~~?~ •?'4~i ~.::,e= . 1~.1~ ~hoe : ?~ T`TD ; =^vP . ?-~ ""i~ =;~oi^~ ~~.-,;`~ Pacite~ ~"1~ '~ T'~i ; Set at __~L~ l~ :ole S~~e ~~ 1 c~-~ ana ~i I ; t~erfs ~~`~3 ~.o ~l`J~~~'~ :~Cc.~?~ =~~~ =NTEG~.TY - a a.RT # ~ rnn;;ius ?ress Test: =? ; ?5 nin ; ~0 m:in Gor~e~ts : • ~ ~~ ~ti~; ~3 hb~s '~*'CHl~N;C~~.., ~NTEGRI'I"~ - PART #2 ~ ~ -__ __ , Gement VolUmes :_ a.mt. ~iner ~R ; Cs~ ~-111o s~f ; DV ~1~.~~,. r~ C~L ~oZ to cQVer ~eris ~ ~ ~~1, ~: ~v~'~L~~~i~ ~ ~,~"l~~~~ ~C~ C . v r-+~..~ ~ ~. ~~- : ~ . . ~~ r, r^~ r-• , ~, ..~ . ... _ __ ~ _ ;e~retical '~~C Cement Bond Log Yes or Na) `~~j~~ -~1~; ~ In AOGCC File-~ CBL ~val.ustion, ~one GDOVe perfs ,_ «,~ ~~ ~i~`cCr~~c~ t~l~ Production I.og: Ty~oe ; Eval~:ation ~ON~LJS ~Dt~S : ?ar~ i I : ?ar~ f2. ~-~ //~ ,~~ j~ f ~/'' - l. ( L.l~ MEMORANDUM ~ To: Jim Regg ~~~ j/`~~ ~ P.I. Supervisor ~ F1tOM: Lou Grimaldi Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, September O5, 2007 SUB3ECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-306 COLVILLE RIV NAN-K CD4-306 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~ Comm Well Name' COLVILLE RN NAN-K CD4-306 ~j ~7~7e11 NUIribeC• 50-103-20550-00-00 Insp Num: mitLG070903044638 Permit Number: 2o7-o9a-o Rel Insp Num: Inspector Name• ~u Grimaldi Inspection Date: 9ii~2oo7 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Weli CD4-306 Type Inj. W T~ 6898 ~ 1260 ]800 1790 U90 p.T, zo~ovao TypeTest SPT Testpsi ~soo pA s6o 3so 3so sso Interval ~T^L p/F P / Tubing uso z~so 2iao z~so NOtes: Post injection Initial test. Well had 1450 on IA, bled to 1260 and observed for 15 minutes with no increase noted. Repressured to 1800 and~ witnessed good test. Well fluid packed and stable. Wednesday, September O5, 2007 Page i of I osi22io~ • ao~y v~.e ao~ -oss~ ~ ~~~~~~~~'~I~~ Schlumberger-DCS 2525 Gambetl Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth Well Job # 'ro ~ ~;;'. ~ ~.~~ ~ ' ~. ~u~ ~~ ~~ 2at>> ~l~(°7.5~~ ~!~ f;; ~;`tt~~~ ~>~?S1S. ~,i01~di~i:~ti1',~i ~nci~c+ra~~ri NO. 4380 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Log Description Date BL Prints CD CD4-306 11837479 PERF RECORD/SBHP SURVEY 07/28/07 1 CD4-306 11837479 SCMT 07/28/07 1 CD4-302 11837478 RSTI WFL 07/27/07 1 SIGNED: - ~ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. ry ~ ~ ~ a C~nt~ct~Ph~lltps August 20, 2007 Commissioner State of Alaska Alaska Oi! & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD4-306 (APD 207-094) Dear Commissioner: ~~~~1VED ~UG 2 0 2007 '~~~a~f~ ~i~ t~ ~`7~S ~iOR$. ~'iQ('Cl(1'1~3$~Qn ~nchflrage ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD4-306. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, 1~ ~- C~~ 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 ~ AU G 2 n 2~~7 ALASKA OIL AND GAS CONSERVATION COMMISSION ~,~ka Dil & Gas Cons. Gommissian WELL COMPLETION OR RECOMPLETION REPOR~ AND ;~~ige 1a. Well Status: Oil ~ Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ Q WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development ~ Exploratory ^ Service ~~ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~j ~.~, orAband.: July , 200 ~~ 2• Permit to Drill Number: 207-094/ 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: July 14, 2007 13. API Number: 50-103-20550-00 ` 4a. Location of Well (Governmental Section): Surface: 2907' FNL, 167' FEL, Sec. 24, T11 N, R4E, UM ~ 7. Date TD Reached: July 21, 2007 14. Well Name and Number: CD4-306 ~ Top of Productive Horizon: 101' FSL, 835' FEL, Sec. 14, T11 N, R4E, UM 8. KB (ft above MSl): ~'6 ~ 2 Ground (ft MSL): 37' RKB ~4'~ ~~ 15. Field/Pool(s): Colville River Field Total Depth: 178' FSL, 996' FEL, Sec. 14, T11 N, R4E, UM 9. Plug Back Depth (MD + ND): 10250' MD / 7191' ND Nanuq Kuparuk Oil Pool ` 4b. Location of Well (State Base Plane Coordinates): Surface: x- 378077.4 y- 5957502.6 ~ Zone- 4 10. Total Depth (MD + ND): , 10346' MD / 7253' ND r 16. Properiy Designation: s . ADL 380077, 380075 TPI: x- 372179 y- 5960609 Zone- 4 Total Depth: x- 372020 ' - 5960689 ' Zone- 4 ~ ~. SSSV Depth (MD + TVD): nipple @ 2125' 17. Land Use Permit: LAS2112 1 S. Directional Survey: Yes ^~ No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1360' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/ Res, SCMT 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 RECORQ pULLED 16" 62.5# H-40 37' 114' 37' 114' 24" Portland Type III 9-5/8" 40# L-80 37' 2727' 37' 2377' 12.25" 36o sx AS III Lite, 234 sx Class G 7" 26# L-80 37' 10336' 37' 7247' 8.75" 416 sx Class G, 206 sx CI G(for K2) 23. Open to production or injection? Yes ~/ No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 9915' 9794' 10113'-10124' MD 6 Spf ~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n!a 26. PRODUCTION TEST Date First Production August 8, 2007 Method of Operation (Flowing, gas lift, etc.) water injector ` 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) 27. CORE DATA Conventional Core(s) Acquired? Yes ~ No ~ Sidewall Cores Acquired? Yes ~ No ~ If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~~ccr;i~l~~7~i~~v ~ NONE ~ ~ ~~ .p~ {!ER 1H~ri ; ~ ~ Form10-407Revised2l2007 CONTINUED E~B€ ~~,n ~~~OD~ ~~~+ L~ B•2~~~'f ORIGINaL ~~~~ ~ ~,zy~~ G ~ ~ 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD ND Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost - Top SurfaCe surfBCe briefly summarizing test results. Attach separate sheets to this form, if Perrllafrost - Bottom 1386' 1360' - needed, and submit detailed test information per 20 AAC 25.071. C-30 2760' 2396' C-20 3438' 2801' K-3 5010' 3831' K-2 5395' 407T ALB 97 7996' 5747' Nanuq 8670' 6180' Top HRZ 9638' 6800' Base HRZ gg29' 6984' K-1 9987' 7021' Kuparuk D 10052' 7063' N/A ~ Kuparuk C 10114' 7103' Formation at total depth: Kuparuk C ~` 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, cement detail sheet, mechanical integrity test 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContaCt: Li2 Galiunas @ 265-6247 Printed Name Chi Alvord Title: WNS Drillinq Team Lead ~ j~~~ p~ ~ ~ 1 Signature ~ ~ Phone ~~ ~ _G ~ ~ Date ~ INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 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 and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additionai 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, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 • . ~ ~ Ct~1'"it~-COP~'11 ~ ~ 1 p-S •: ~ WelN?ew We$ ReFOrting Well Name: CD4-306 Job Type: DRILLING ORIGINAL Time Log Summary 07/14/2007i00:00 I1430 I 14.50 ~ 114 I 114 ~MIRU I MOVE I PSIT IP IMp ved from CD4-16 to CD4-306. Rig I Ri acce ted 1430 Hrs 14:30 18:30 4.00 114 114 MIRU DRILL RURD P Hook up service lines, NUsurface riser & flow lines, install mouse hole, take on s ud mud. 1830 19:30 1.00 114 114 SURFA DRILL RURD P Move 6 3/4" NMFC in derrick to drillers side 19:30 21:45 2.25 114 114 SURFA DRILL PULD P MU BHA #1 - Orient plug in 21:45 22:45 1.00 114 114 SURFA DRILL DHEQ P Pre spud safety meeting, fill hole & check for leaks, Pressure test mud line to 3500PS1, MU NMFC 22:45 00:00 1.25 114 168 SURFA DRILL DDRL P Drill 12 1/4" surface hole from 114' to 168'-MD ND-168' ART - .3 hrs ADT - .3 hrs Bit wt 7/12k 40 rpms 450 gpm - 730 psi Up wt - 95k Dn wt - 95k Rot wt - 95k TQ on/off 4k/3k 07/15/2007 00:00 12:00 12.00 168 1,287 SURFA DRILL DDRL P Drill 12 1/4" surface hole w/mud motor from 168' to 1287' - MD ND - 1270' ADT - 6.9 hrs ART - 4.27 hrs AST 2.63 hrs Bit wt 15/20 k 50 rpms 500 gpm - 1250 psi Up wt - 124 k Dn wt - 122 k Rot wt - 124 k TQ on/off 6 k/4 k 12:00 00:00 12.00 1,287 2,450 SURFA DRILL DDRL P Drill 12 1/4" surface hole w/mud motor from 1287' to 2450' - MD ND - 2203' ADT - 8.9 hrs ART - 6.47 hrs AST 2.43 hrs Bit wt 15/20 k 50 rpms 500 gpm - 1250 psi Up wt - 137 k Dn wt - 125 k Rot wt - 132 k TQ on/off 8 k/6 k 07/16/2007 00:00 05:45 5.75 2,450 2,737 SURFA DRILL DDRL P Drill 12 1/4" surface hole w/mud motor from 1287' to 2450' - MD TVD - 2203' ADT - 8.9 hrs ART - 6.47 hrs AST 2.43 hrs Bit wt 15/20 k 50 rpms 500 gpm - 1250 psi Up wt - 137 k Dn wt - 125 k Rot wt - 132 k TQ on/off 8 k/6 k i ~ ~ 07/16/2007 05:45 06:30 0.75 2,737 2,737 SURFA DRILL CIRC P Circ hole clean at 600 gpm - 60 rpms. 0630 09:45 3.25 2,737 890 SURFA DRILL WPRT P POH w/ pump from 2737' to HWDP at 890' at 550 gpm - 60 rpms. Reduced flow rate to 450 gpm at base of ermafrost. Monitor well. Static. 09:45 10:30 0.75 890 2,737 SURFA DRILL WPRT P RIH to TD at 2737'. No hole problems 10:30 12:00 1.50 2,737 2,737 SURFA DRILL CIRC P MU top drive. Break circ. Circ hole clean at 600 m- 60 r ms. 12:00 14:00 2.00 2,737 168 SURFA DRILL TRIP P Monitor well. Static. POH on trip tank from 2737' to 168'. No hole problems. Check flow at HWDP. 14:00 16:00 2.00 168 0 SURFA DRILL PULD P Std back NMFC. Download MWD. LD BHA #1. 16:00 17:45 1.75 0 0 SURFA CASINC RURD P RU 9 5/8" csg equipment. 17:45 18:00 0.25 0 0 SURFA CASIN( SFTY P PJSM on running csg. 18:00 21:00 3.00 0 1,724 SURFA CASIN( RNCS P RIH w/ 9 5/8" csg to 1724'. 21:00 21:30 0.50 1,724 1,724 SURFA CASIN CIRC P Circ one pipe volume at 4.5 bpm. 21:30 23:00 1.50 1,724 2,727 SURFA CASIN RNCS P RIH w/ 9 5/8" csg from 1724' to 2689'. MU hanger and landing jt. Land csg at 2727'. 23:00 00:00 1.00 2,727 2,727 SURFA CASIN RURD P RD fill-up tool. Blow down top drive. RU cement head. 07/17/2007 00:00 01:15 1.25 2,727 2,727 SURFA CEME~ CIRC P Establish circulation. Stage pumps up to 6.5 bpm at 230 psi. Condition mud for cement 'ob. 01:15 01:30 0.25 2,727 2,727 SURFA CEME~ SFTY P PJSM and cementing surface csg. 01:30 03:45 2.25 2,727 2,727 SURFA CEME~ DISP P Cement 9 5/8" csg as follows: Pumped 30 bbis Biazon water w/ nut plug for marker - switched to Dowell - Pumped 5 bbis water - Test lines to 4000 psi - Dropped btm plug - Mixed & pumped 50 bbls MudPush @ 10.5 ppg @ 5 bpm @ 450 psi - Mixed & pumped Lead slurry (AS 3 Lite) @ 10.7 ppg @ 7.5 bpm @ 700 psi - Observed nut plug marker @ Shakers w/ 278 bbls pumped - Pumped down surge can (297 bbls total )- Switched over to tail slurry Pumped 50.38 bbis Class G w/ additives) @ 15.8 ppg @ 4 bpm @ 470 psi - Dropped top plug w/ 20 bbls water f/ Dowell - Switched to rig pumps & displaced wl179.8 bbis - 9.8 ppg mud @ 6.5 bpm @ 600 psi for first 170 bbls - slowed pump to 3.5 bpm for last 10 bbls @ 480 to 510 psi - Bumped plug w/ 1000 psi - Checked floats OK - CIP @ 0337 hrs.- Full circulation throughout job w/ 130 bbls 10.7 ~oa cmt to surface ~ 07/17/2007 03:45 04:00 0.25 2,727 2,727 SURFA CEME~ OTHR P Check floats. OK 04:00 04:45 0.75 2,727 2,727 SURFA CASIN( DHEQ P RU. Test 9 5/8" csg to 3500 psi for 30 min. 04:45 05:15 0.50 2,727 2,727 SURFA CASIN( RURD P Blow down lines. RD cement head and circulatin e ui ment. 05:15 07:15 2.00 2,727 2,727 SURFA CASIN NUND P LD landing jt. - Drain stack - ND surface riser & starting head - LD mouse hole 07:15 08:00 0.75 SURFA DRILL OTHR P install FMC 11" 5 K Unihead & test seals to 1000 si 08:00 09:45 1.75 SURFA WELCT NUND P NU BOPE 09:45 13:00 3.25 SURFA WELCT EQRP P Install 4" solid body rams in lower gate &31/2"x6"VBRinto ate 13:00 19:00 6.00 SURFA WELCT BOPE P RU & test BOPE - Annular to 250 & 3500 psi - pipe rams, blind rams, choke manifold valves, choke & kill line valves, dart & floor safety valves, TD IBOP's to 250 & 5000 psi - performed accumulator closure test - test witnessed & approved by Bob Noble AOGCC 19:00 19:30 0.50 SURFA WELCT OTHR P Install wear busning. Blow down choke and kill lines. 19:30 00:00 4.50 743 SURFA DRILL PULD P Bring BHA equipment to rig floor. MU BHA #2. Upload MWD. Test Geospan to 3500 psi. PJSM. Install sources. MU NMFC's, ~ars and HWDP to 743'. 07/18/2007 00:00 01:15 1.25 743 2,562 SURFA DRILL TRIP P RIH with 5" and 4" DP from 743' to 2562'. Filled i ed at 1991'. 01:15 02:00 0.75 2,562 2,643 SURFA CEME~ COCF P Break circulation. Stage pumps up to 450 gpm. Break in Geopilot. Wash and ream to TOC at 2625'. Clean out cement to float collar at 2643'. 02:00 04:30 2.50 2,643 2,737 SURFA CEME~ DRLG P Drill out float collar, cement and float shoe. Clean out rathole to 2737'. 04:30 05:00 0.50 2,737 2,757 SURFA DRILL DDRL P Drill 20' new formation from 2737' to 2757'. 05:00 05:30 0.50 2,757 2,757 SURFA CEME~ CIRC P Circ hole clean. 05:30 06:15 0.75 2,757 2,657 SURFA CEME~ FIT P Pull up to 2657' - RU & perform FIT to 18.0 ppg EMW - bleed off & blow down lines 06:15 06:30 0.25 2,657 2,757 INTRM1 DRILL TRIP P RIH to 2757' 06:30 07:30 1.00 2,757 2,757 INTRM1 DRILL CIRC P Chnage well over to 9.6 ppg LSND mud 07:30 12:00 4.50 2,757 3,309 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 2757' to 3309' MD 2725' ND ADT - 3.27 hrs ECD 11.01 ppg WOB 10/15 k RPM 130 GPM 600 @ 1770 psi String wt. PU 147 SO 119 Rot 133 Toraue on/off btm. - 8,500f7,500 Wibs ~ 07/18/2007 12:00 00:00 12.00 3,309 4,550 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 3309' to 4550' MD 3534' ND ADT - 8.72 hrs ECD 11.5 ppg WOB 8/13 k RPM 120 GPM 600 @ 2620 psi String wt. PU 158 SO 128 Rot 144 Tor ue on/off btm. - 9,000/8,500 ft/Ibs 07/19/2007 00:00 12:00 12.00 4,550 5,702 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 4550' to 5702' MD 4276' ND ADT - 7.93 hrs. ECD - 10.26 to 10.80 PP9 WOB 10/20 k RPM 120 GPM 600 to 650 @ 2650 to 3400 psi String wt. PU 185 SO 134 Rot 156 Tor ue on/off btm - 10,000/9,000 ft/Ibs 12:00 00:00 12.00 5,702 7,540 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 5702' to 7540' MD 5453' TVD ADT - 9.37 hrs. ECD - 10.8 to 11.1 Pp9 WOB 18/22 k RPM 130 GPM 650 @ 3600 psi String wt. PU 212 SO 140 Rot 167 Torque onloff btm - 13,500/10,500 ft/Ibs 07/20/2007 00:00 12:00 12.00 7,540 8,802 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 7540' to 8802' MD 6264' TVD ADT- 8.39 hrs ECD - 10.64 to 10.77 PP9 WOB 15/22 k RPM 120/140 GPM 650 @ 3650 psi String wt. - PU 240 SO 147 Rot 185 Torque on/off btm. -14,000/12,500 ft/Ibs 12:00 00:00 12.00 8,802 9,987 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 8802' to 9987' MD 7021' TVD ADT- 9.21 hrs ECD - 10.8 ppg WOB 13/18 k RPM 140 GPM 550 @ 3250 psi String wt. - PU 225 SO 165 Rot 194 Tor ue on/off btm. - 12,000/9,500 ft/Ibs 07/21/2007 00:00 04:15 4.25 9,987 10,346 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 9987' to 10,346' MD 7252' ND ADT- 3.46 hrs ECD - 10.57 ppg WOB 10/18 k RPM 140 GPM 550 @ 3260 psi String wt. - PU 240 SO 165 Rot 195 Torque on/off btm. - 12,000/10,000 ft/~bs 04:15 06:45 2.50 10,346 10,273 INTRM1 DRILL CIRC P CBU 3X at 550 gpm - 3170 psi - 140 rpms.10 k torque - Std back pipe f/ 10346' to 10273' - Flow ck. Static 06:45 08:15 1.50 10,273 9,511 INTRM1 DRILL WPRT P Wiper trip f/ 10,273' to 9511' w/ pump @ 500 gpm @ 2760 psi w/ 70 rpm - 10 k tor ue - PU wt. 205 So wt. 165 08:15 08:45 0.50 9,511 10,273 INTRM1 DRILL TRIP P RtH f/ 9511' to 10,273' 07/21/2007 08:45 09:15 0.50 10,273 10,346 INTRM1 DRILL REAM P Precautionary wash & ream f/ 10,273' to 10,346' - 550 gpm @ 3250 psi w/ 140 r m 10 k tor ue 09:15 10:30 1.25 10,346 10,346 INTRM1 DRILL CIRC P Circ hole clean - 550 gpm @ 3230 psi w/ 140 psi - 10 k torque - std back i e to 10,273' - RIH to 10,346' 10:30 11:00 0.50 10,346 10,346 INTRM1 DRILL CIRC P Spot casing lube pill in drill string 120 bbis - 500 gpm @ 2930 psi w/ 110 r m- 10 k tor ue 11:00 12:15 1.25 10,346 9,415 INTRM1 DRILL TRIP P POOH f/ 10,346' to 9415' - spotting casing lube pili @ 2.5 bbls/min @ 320 si - Flow ck. Static 12:15 18:00 5.75 9,415 2,657 INTRM1 DRILL TRIP P POOH on TT f/ 9415' to 2657' ( pumped dry job @ 7034') - no tight s ots & hole took ro er fill 18:00 19:30 1.50 2,657 2,657 INTRM1 RIGMN RGRP T Monitor well on TT while working on electrical roblem in do house 19:30 21:30 2.00 2,657 199 INTRM1 DRILL TRIP P Continue POOH on TT f/ 2657' to 742' - Flow ck Static - Std back HWDP to 199' - 21:30 00:00 2.50 199 0 INTRMI DRILL PULD P LD MN flex DC's - remove Ra sources - Plug into MWD - Unable to down load (possible dead battery) - LD MWD - 07/22/2007 00:00 00:45 0.75 0 0 INTRM1 DRILL PULD P Finish LD BHA. 00:45 01:15 0.50 0 0 INTRM1 DRILL OTHR P Clear floor of misc subs and e ui ment. 01:15 02:15 1.00 0 0 INTRM1 WELCT EQRP P Change upper pipe rams from 3 1/2" x 6" VBR's to 7". 02:15 02:45 0.50 0 0 INTRM1 WELCT OTHR P Pull wear bushing. Install test plug. 02:45 03:15 0.50 0 0 INTRM1 WELC BOPE P RU and test 7" pipe rams to 250 - 5000 si. RD. 03:15 03:45 0.50 0 0 INTRMI CASINC OTHR P Install thin wear bushing for running cs . 03:45 04:15 0.50 0 0 INTRM1 DRILL RURD P RD Geospan unit. 04:15 05:45 1.50 0 0 INTRM1 CASINC RURD P RU 7" csg equipment. 05:45 06:00 0.25 0 0 INTRM1 CASINC SFTY P PJSM on running 7" csg. 06:00 10:30 4.50 0 3,392 INTRM1 CASINC RNCS P Run 7" 26# L-80 BTCM as follows: Float shoe (Ray IOiI Tools silver bullet) 2 jts - Fioat collar - 2 jts ( firsr four connections made up w/ BakerLoc - filled pipe & checked floats) - 76 jts (80 jts total ) to 3392' PU wt. 140 SO wt 125 10:30 11:00 0.50 3,392 3,392 INTRM1 CASIN( CIRC P Circ btms up +@ 3392' - stage um s u to 5 bbls/min - FCP 290 si 11:00 15:00 4.00 3,392 6,796 INTRM1 CASIN RNCS P Continue running 7" 26# L-80 BTCM csg - to 4285' (101 jts totai in hole) - Install Tam PC & BakerLoc connections - Continue running 7" csg f/ 4287' to 6796' ( 160 its total in hole ) 07/22/2007 15:00 16:00 1.00 6,796 6,796 INTRM1 CASlNC CIRC P Establish circ - Circ btms up +@ 6796' - Stage pumps up to 5 bbls/min FCP - 430 si 16:00 18:45 2.75 6,796 9,362 INTRM1 CASIN( RNCS P Continue running 7" 26# L-80 BTCM csg f/ 6796' to 9362' ( 220 jts total in hole 18:45 20:00 1.25 9,362 9,362 INTRM1 CASIN( CIRC P Establish circ & circ btms up + stage um s u to 5 bbls/min FCP - 500 si 20:00 21:00 1.00 9,362 10,336 INTRM1 CASIN RNCS P Continue running 7" 26# L-80 BTCM f/ 9362' to 10,300 ( 242 jts total ran) PU FMC fluted hanger & landing jt. Land csg in wellhead w/ FS @ 10, 336' & FC 10,248' - TAM PC 6048' 21:00 21:30 0.50 10,336 10,336 INTRM1 CASINC RURD P LD fill up tool - Blow down TD - RU - Cmt head & lines 21:30 23:30 2.00 10,336 10,336 INTRM1 CEME~ CIRC P Establish circ - Circ & condition for cmt job - Stage pump up 5.5 bbls/min - 470 si. 23:30 23:45 0.25 10,336 10,336 INTRM1 CEME~ SFTY P PJSM on cementing 7" csg. 23:45 00:00 0.25 10,336 10,336 INTRM1 CEME~ SFEQ P Dowell pumped 5 bb~s CW100. Test lines to 4000 si. 07/23/2007 00:00 02:00 2.00 10,336 10,336 INTRM1 CEME DtSP P Dowell pumped 20 bbls CW100, 30 bbls 10.5 ppg MudPush, dropped bottom plug, 86 bbls 15.8 ppg cement (416 sx), dropped top plug and 20 bbls water. Rig displace cement with 369 bbls 9.8 ppg mud at 6 bpm. Reduced rate to 3.5 bpm last 10 bbls. Bumped plug with 750 psi circ pressure. Pressure csg to 1250 psi. OK. Check floats. OK. Full returns throu hout ~ob. 02:00 02:45 0.75 10,336 10,336 INTRM1 CASIN DHEQ P Test 7" csg to 3500 psi for 30 min. 02:45 03:45 1.00 0 0 INTRM1 CEME~ RURD P RD cement head and lines. LD LJ. RD elevators and bales. 03:45 04:45 1.00 0 0 INTRM1 CASINC DHEQ P Pull thin wear bushing. Install pack-off and test to 5000 si. 04:45 05:45 1.00 0 0 INTRM1 WELCT EQRP P Change upper pipe rams from 7" to 3 1/2" X 6" VBR's. 05:45 06:30 0.75 0 0 INTRM1 WELCT OTHR P Set test plug w/ 4" test jt. & test VBRs to 250 & 5000 si 06:30 07:30 1.00 0 0 INTRM1 DRILL PULD P LD test jt - PU drilling bales & DP elevators - PU test jt & pull test plug - Set wear bushin 07:30 08:00 0.50 0 0 INTRM1 CEME~ PULD P MU Baker plug launching head w/ XO's & u 'ts - LD 08:00 08:30 0.50 0 24 INTRM1 CEME~ PULD P MU Tam combo tool w/ XO 08:30 13:45 525 24 6,019 INTRM1 CEME~ TRIP P RIH w! combo tool on 4" DP f/ 24' to 6019' - PU wt. 158 SO 128 13:45 14:45 1.00 6,019 6,048 INTRM1 CEME~ PULD P PU 1 single of DP & PU Baker plug launchin head assembl to 6048' 14:45 15:45 1.00 6,048 6,048 INTRM1 CEME~ CIRC P Establish circ @ 3 bbis/min 450 psi - Drop ball & pump down to ball seat - pressure up to 800 psi - Open TAM PC - ~ ~ 07/23/2007 15:45 16:30 0.75 6,048 6,048 INTRM1 CEME~ CIRC P Circ btms up f/ TAM PC @ 6048' - re for 2nd sta e cmt 'ob 16:30 17:30 1.00 6,048 6,048 INTRM1 CEME~ DISP P Dowell pumped 20 bbls CW100. Tested lines to 4000 psi. Pumped 30 bbls 10.5 ppg MudPush, 43 bbis 15.8 cement (206 sx), drop closing dart, 20 bbls water followed b 42 bbls mud. 17:30 18:00 0.50 6,048 6,048 INTRM1 CEME~ OTHR P Shear plug at 2100 psi. Close Tam port collar. Test port collar to 1000 si.. Shear ball at 3000 si 18:00 19:00 1.00 6,048 6,048 INTRM1 CEME~ CIRC P Reverse circ 2 dritl pipe volumes at 3.5 b m at 610 si. 19:00 19:30 0.50 6,048 6,048 INTRM1 CEME~ RURD P RD Baker top drive swivel. 19:30 20:30 1.00 6,048 5,073 INTRM1 CEME~ TRIP P POH on trip tank from 6048' to 5073'. 20:30 22:00 1.50 5,073 5,073 INTRM1 RIGMN SVRG P Slip and cutting drilling line. Service to drive. 22:00 00:00 2.00 5,073 3,294 INTRM1 CEME~ TRIP P Pump dry-job. POH on trip tank from 5073' to 3294'. 07/24/2007 00:00 01:45 1.75 3,294 0 INTRM1 CEME~ TRIP P Cont. P~OH w/ TAM Comdo tool f/ 3924' 01:45 02:30 0.75 0 0 INTRM1 CEME~ PULD P Break service breaks on Combo tool - LD tool 02:30 03:45 1.25 0 0 INTRM1 CEME~ PULD P PU Baker plug lanuching head - Break XO's & u 'ts. - LD same 03:45 04:15 0.50 0 0 INTRMI CEME OTHR P Close blind rams & test csg to 1000 si - OK - blow down lines 04:15 05:00 0.75 0 195 INTRM1 DRILL PULD P MU BHA #3 - bit, bit sub, stab, XO, HWDP & 'ars 05:00 06:30 1.50 195 1,522 INTRM1 DRILL TRIP P RIH f/ 195 to 1522' - picking up 48 jts. 4" DP f/ i e shed 06:30 08:30 2.00 1,522 5,709 INTRM1 DRILL TRIP P Continue RIH w/ DP f/ derrick f/ 1522' to 5709' 08:30 10:30 2.00 5,709 6,376 INTRM1 DRILL REAM P Precautionary wash & ream f/ 5709' to 6376' ( didn't observed any cmt going through Tam PC @ 6048' ) 4 bbls/min @ 550 psi w/ 30 rpm - torque 6000 ft/Ibs 10:30 11:00 0.50 6,376 6,376 INTRM1 DRILL OTHR P Pressure test 7" csg to 3500 psi for 10 mins. OK - blow down lines 11:00 13:00 2.00 6,376 10,090 INTRM1 DRILL TRIP P Continue RIH f/ 6376' to 10,090' 13:00 13:15 0.25 10,090 10,195 INTRM1 DRILL REAM P Wash down f/ 10,090' to 10,195' - tag up on cmt - 180 gpm @ 950 psi w/ 50 rm 13:15 14:00 0.75 10,195 10,244 INTRM1 CEME COCF P Clean out cmt f/ 10,195' to 10,244' - 180 m 920 si w/ 50 r m 14:00 15:00 1.00 10,244 10,244 INTRM1 DRILL CIRC P Circ hole clean for brine change over- 350 m 2170 si w/ 50 r m 15:00 17:30 2.50 10,244 10,244 INTRM1 DRILL CIRC P PJSM - Displace well to 9.2 ppg brine @ 294 gpm @ 1360 psi w/ 50 rpm - Clean u surface eu i ment 17:30 00:00 6.50 10,244 2,570 INTRM1 DRILL TRIP P Flow ck Static - POOH laying down 4" DP f/ 10,244' to 2750' ~ 07/25/2007 00:00 02:00 2.00 2,570 195 INTRM1 DRILL TRIP P Continue POOH laying down 4" DP f/2570' to 195' 02:00 02:45 0.75 195 0 INTRM1 DRILL PULD P LD BHA # 3- LD 1 std f/ derrick 02:45 04:00 1.25 0 0 COMPZ RPCOh OTHR P Pull wear bushing - set test plug & test top VBR w/ 4 1/2" test jt. to 250 & 5000 si - Pull test lu 04:00 04:15 0.25 0 04:15 04:30 0.25 0 04:30 14:30 10.00 0 0 COMPZ RPCOh RURD P RU to run 4 1/2" completion 0 COMPZ RPCOh SFTY P Held PJSM w/ crew on running com letion 9,915 COMPZ RPCOh RCST P Run 4 1/2" completion as follows :(Ail - tbg & pup jts 4 1/2" 12.6# L-80 IBTM)- WLEG - pup jt - 1 jt tbg - XN nipple w! RHC plug installed - 1 jt. tbg - pup jt - Baker S-3 packer w/ mili out extension - pup jt - 2 jts tbg - Camco GLM w/ dummy valve - 187 jts tbg - Camco DB nipple - 52 jts tbg (243 jts total run in hole) to 9879.31' - PU FMC 11" tbg hanger w/ M/M seals & landing jt A- Land tbg in wellhead w/ tail @ 9914.63' - XN nipple @ 9858.36' - packer @ 9793.55' - GLM @ 9686.13' - DB nipple @ 2124.54' - RILDS 14:30 15:30 1.00 9,915 9,915 COMPZ RPCOh PULD P LD landing jt A- Set TWC - MU landing jt. B- test hanger seals to 500 si for 10 mins - LD landin 't. B. 15:30 15:45 0.25 9,915 9,914 COMPZ RPCOh RURD P RD & LD tbg equipment 15:45 17:00 1.25 9,914 9,914 COMPZ WELCT NUND P LD mouse hole - NU BOPE 17:00 18:00 1.00 9,914 9,914 COMPZ RPCOti OTHR P NU tree & test to 5000 psi 18:00 18:15 0.25 9,914 9,914 COMPZ RPCOh OTHR P Pull TWC 18:15 19:15 1.00 9,914 9,914 COMPZ RPCOh OTHR P RU hard lines & floor manifold 19:15 19:30 0.25 9,914 9,914 COMPZ RPCO SFTY P PJSM on pumping inhibited brine & diesel 19:30 21:30 2.00 9,914 9,914 COMPZ RPCOti CIRC P Test lines to 2000 psi - Pumped 154 bbis 9.2 ppg inhibited brine followed by 181 bbls diesel (tbg voi + 1600' ND for freeze rotect - 21:30 00:00 2.50 9,914 9,914 COMPZ RPCO OTHR P RU lubricator & drop packer setting rod/ball - Test lines to 4000 psi - Pressure up on tbg to 3500 psi to set packer & test tbg for 30 mins. - Bleed down tbg to 1500 psi - Pressure up on 4 1/2" x 7" annulus to 3500 psi & test for 30 mins.- Bleed down annulus to 0 psi - Bleed down tbg to 700 psi - Shut in well - Flush & blow down lines. FMC Set BPV. Prep rig for move. `* RIG Released at 2400 hrs "` i i • CD4-306 Well Events Summary DATE Summary 7/27/07 FOG DELAYED FLT FROM KUPARUK. PULLED BALL & ROD AND RHC PLUG BODY FROM 9858' RKB. DRIFTED TUBING WITH 11.5' x 3.50" DUMMY GUN TO 10,218' RKB. LRS MIT'D IA 2500 PSI, GOOD. WELL READY FOR E/L. 7/28/07 RAN SCMT BOND LOG. MADE MAIN AND REPEAT PASSES FROM 10220'-EOT. HIGH QUALITY CEMENT OVER THIS INTERVAL. SHOT 11' OF 2 7/8" POWERJET E------' OMEGA LOADED 6 SPF FROM 10113-10124'. TUBING PRESSURE INCREASED FROM 20 PSI TO 470 PSI SHORTLY AFTER PERFORATING. FINAL TUBING PRESSURE 480#. 7/29/07 RAN SBHP SURVEY. RESULTS: SHUT IN TUBING PRESSURE FROM PBMS=471 PSI. SURVEY STOP AT 10188'= 2990 PSI AND 155.7 DEG F. GRADIENT STOP AT 10000'=2954 PSI AND 153.3 DEG F. • ! Halliburton Company Survey Report >. ' Comp~n~y GoCtt[rcfl~'k~i~ips ~t}3skit IriC... . ;: `. - " ; .: llate: $t13[~2(FQ7 T~p+e; ' 1+4:U5.1 ~ =: _ -: Pag~: ' 1. ~ . °T:; ~ ,F~eld ~o[vilfeRtver~tt~f ~ ' ` Co~rd-na~e~l+iE}Referc~~e:. UU~11:~E34-~,'f`~I~J~~th f: SNte htanuqGB4 Vartacal(I"V~1~Itet'~ien+~ CC74-~Q~ 562 : T ( Wel} . -"~. ~C1~=~~~r SectiQ~ ~S)_~ePerene~ W~I {~.E~pt~t,~,,~ 296 8~i~~} ~ ~ ~~~3'Vel~pati~ CD~4-3U6 - ` 5u~'ve~ CaYeulahon M±~fhd~ ' ~ '~~ , Minirnur~ Cur~Bt~rre~ , I?b. Uracle ~ 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 Sy stem: Well Centre ~ Sys Datum: Mean Sea Level Geomagne6c Model: bggm2007 Well: CD4-306 Slot Name: ~ i Alpine CD4 i Well Position: +N/-S -25.07 ft Northing: 5957502.61 ft Latitude: 70 17 32.719 N ~ +E/-W -96.95 ft Easti ng : 378077.36 ft Longitude: 150 59 13.589 W Position Uncertainty: 0.00 ft Wellpath: CD4-306 Drilled From: Well Ref. Point 501032055000 Tie-on Depth: 36.63 ft Current Datum: CD4-306: Height 56.23 ft~ Above System Datum: Mean Sea Level ~ MagneHc Data: 7/13/2007 Declinatio-r. 22.53 deg Field Strength: 57556 nT Mag Dip Angle: 80.65 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.63 0.00 0.00 296.86 Survey Program for Definitive Wellpath ~ I Date: 5/24/2007 Validated: No Version: 1 i ; Actual From To Survey Toolcode Tool Name ft ft ~ i ~ 80.00 442.00 CD4-306 gyro (80.00-442.00) CB-GYRO-SS Camera based gyro single shot 478.51 10315.89 CD4-306 (478.51-10315.89) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C ~ Survey ~'i . I~l r~~im ~ T4fD ~ys"T~'ll NfS E!W ~ `11~ap~i Ma~}~ =`~~wl : fk,•`, deg ;,deg ' .. ,, ft ik 1 ' ft . ; fk f# ft', . . " 36.63 0.00 0.00 36.63 -19.60 0.00 0.00 5957502.61 '` 378077.36 ~ TIE LINE 80.00 0.40 128.00 80.00 23.77 -0.09 0.12 5957502.51 378077.48 CB-GYRO-SS ~ 170.00 0.30 131.00 170.00 113.77 -0.44 0.54 5957502.16 378077.90 CB-GYRO-SS ii 260.00 0.55 137.00 260.00 203.77 -0.91 1.02 5957501.68 378078.36 CB-GYRO-SS I 352.00 0.60 112.00 351.99 295.76 -1.42 1.76 5957501.17 378079.10 CB-GYRO-SS I 442.00 1.15 26.00 441.98 385.75 -0.78 2.60 5957501.79 378079.94 CB-GYRO-SS i 478.51 2.34 356.50 478.48 422.25 0.29 2.71 5957502.86 378080.08 MWD+IFR-AK-CAZ-SC ', 567.92 5.12 344.13 567.69 511.46 5.95 1.51 5957508.54 378078.97 MWD+IFR-AK-CAZ-SC ' 614.19 5.24 338.76 613.77 557.54 9.91 0.18 5957512.51 378077.70 MWD+IFR-AK-CAZ-SC 657.10 5.36 345.33 656.50 600.27 13.67 -1.04 5957516.30 378076.54 MWD+IFR-AK-CAZ-SC 749.53 5.76 343.38 748.49 692.26 22.30 -3.46 5957524.96 378074.27 MWD+IFR-AK-CAZ-SC 839.63 8.55 342.97 837.88 781.65 33.03 -6.71 5957535.75 378071.18 MWD+IFR-AK-CAZ-SC 935.37 11.54 337.12 932.15 875.92 48.67 -12.52 5957551.47 378065.63 MWD+IFR-AK-CAZ-SC 1029.55 15.27 333.35 1023.75 967.52 68.44 -21.75 5957571.38 378056J2 MWD+IFR-AK-CAZ-SC I 1124.51 16.31 329.58 1115.12 1058.89 91.11 -34.11 5957594.26 378044.73 MWD+IFR-AK-CAZ-SC ~ 1219.58 18.42 323.90 1205.86 1149.63 114.76 -49.72 5957618.16 378029.51 MWD+IFR-AK-CAZ-SC 1314.70 22.38 316.26 1295.01 1238.78 140.00 -71.11 5957643.74 378008.54 MWD+IFR-AK-CAZ-SC 1409.68 25.02 310.85 1381.99 1325.76 166.21 -98.81 5957670.39 377981.26 MWD+IFR-AK-CAZ-SC ~ ~ 1505.41 25.53 308.32 1468.55 1412.32 192.25 -130.31 5957696.93 377950.19 MWD+IFR-AK-CAZ-SC i 1600.42 27.51 305.64 1553.57 1497.34 217.73 -164.21 5957722.96 377916.71 MWD+IFR-AK-CAZ-SC 1695.66 30.75 305.79 1636.75 1580.52 244.79 -201.85 5957750.62 377879.53 MWD+IFR-AK-CAZ-SC 1790.84 33.14 303.09 1717.51 1661.28 273.23 -243.39 5957779.73 377838.45 MWD+IFR-AK-CAZ-SC ; 1886.30 35.62 301.56 1796.29 1740.06 302.03 -288.95 5957809.27 377793.37 MWD+IFR-AK-CAZ-SC 1981.20 37.97 299.98 1872.28 1816.05 331.09 -337.79 5957839.11 377745.01 MWD+IFR-AK-CAZ-SC 2076.20 40.85 299.11 1945.68 1889.45 360.82 -390.26 5957869.68 377693.03 MWD+IFR-AK-CAZ-SC 2171.36 43.32 298.09 2016.29 1960.06 391.33 -446.26 5957901.09 377637.54 MWD+IFR-AK-CAZ-SC 2265.51 45.34 297.23 2083.64 2027.41 421.86 -504.53 5957932.56 377579.78 MWD+IFR-AK-CAZ-SC 2360.63 49.63 295.75 2147.91 2091.68 453.10 -567.28 5957964.81 377517.55 MWD+IFR-AK-CAZ-SC 2455.33 50.36 295.38 2208.78 2152.55 484.40 -632.72 5957997.17 377452.64 MWD+IFR-AK-CAZ-SC s • Halliburton Company Survey Report Cum}-any: ~t~F~hi~ips;4laska tnc.. ' Fl~id ~[vilie F3tv~r.,Unit w~S"~~ ~ ~~Rl1C~ ~.'~ ~. W811 CQ~-3U~ i c, -V~eflpat6s CQ4-~Q6 , ' = ', Survey ; ~ Mll' Inel Azim T~ 'fk de~ 't~eg ; ~ ,;- : ~YsT~D ft . I~te: 8M31~{It~7 ,' T"mie. 1~.t}510 % Page: ' ~ ~o-nrdinat~{NE}ITePerenee•==. ;,WetE: CCx4 3C~<,True CJo~th „~ '~0t'r1C&) ~~1~ ~~~iC#'L"i1CC ~`e~~^.~QES .~"~' °~t~OM1,~YS)-~iC1C#'G~CE U4~~{~ {Q»pQN ~~U~ ~9~i $Fill~tj Survey ~~l~~a,~ l~etkad ' Minitnu~l GFk~V~tur~ ~ , ll!b ~3rr~Gte Nl~ Et~V ' 1kIM~YpN, MapE : ~'~aul = , ',fi . ff ~~' . ', ft' ~ : . . ~ H. 2550. 56 51. 48 297 .03 - 2268.82 . 2212 .59 _.. 517 _ .05 -699 .03 ~.. 5958030. 88 377386. 86 , MWD+IFR-AK-CAZ-SC 2645. 50 52. 30 295 .31 2327. 42 2271 .19 549 .99 -766 .07 5958064. 90 377320. 37 MWD+IFR-AK-CAZ-SC ~ 2688. 36 53. 02 294 .67 2353. 41 2297 .18 564 .38 -796 .96 5958079. 80 377289. 72 MWD+IFR-AK-CAZ-SC 2727. 15 53. 56 295 .46 2376. 60 2320 .37 577 .56 -825 .13 5958093. 42 377261. 78 MWD+IFR-AK-CAZ-SC 2820. 74 52. 72 297 .39 2432. 74 2376 .51 610 .87 -892 .18 5958127. 82 377195. 28 ( MWD+IFR-AK-CAZ-SC 2916. 24 53. 54 297 .63 2490. 04 2433 .81 646 .16 -959 .94 5958164. 20 377128. 10 MWD+IFR-AK-CAZ-SC 3011. 15 53. 79 297 .42 2546. 28 2490 .05 681 .49 -1027 .74 5958200. 63 377060. 89 MWD+IFR-AK-CAZ-SC 3106. 30 53. 30 297 .01 2602. 82 2546 .59 716 .49 -1095 .80 5958236. 72 376993. 41 MWD+IFR-AK-CAZ-SC 3201. 35 53. 03 297 .99 2659. 80 2603 .57 751 .62 -1163 .28 5958272. 93 376926. 52 MWD+IFR-AK-CAZ-SC 3296. 42 53. 22 298 .30 2716. 85 2660 .62 787 .49 -1230 .34 5958309. 89 376860. 06 MWD+IFR-AK-CAZ-SC 3391. 88 53. 70 297 .52 2773. 68 2717 .45 823 .39 -1298 .11 5958346. 88 376792. 88 MWD+IFR-AK-CAZ-SC 3487. 00 52. 98 295 .73 2830. 48 2774 .25 857 .59 -1366 .32 5958382. 17 376725. 24 MWD+IFR-AK-CAZ-SC ~ 3582. 25 51. 49 295 .50 2888. 81 2832 .58 890 .14 -1434 .21 5958415. 82 376657. 89 MWD+IFR-AK-CAZ-SC i 3677. 00 50. 22 294 .54 2948. 63 2892 .40 921 .23 -1500 .80 5958447. 98 376591. 82 MWD+IFR-AK-CAZ-SC ~ 3772. 08 49. 32 293 .64 3010. 03 2953 .80 950 .86 -1567 .06 5958478. 68 376526. 06 MWD+IFR-AK-CAZ-SC I 3867. 05 48. 57 293 .94 3072. 41 , 3016 .18 979 .75 -1632 .59 5958508. 62 376461. 01 MWD+IFR-AK-CAZ-SC I j 3961. 63 48. 74 293 .44 3134. 89 3078 .66 1008 .27 -1697 .61 5958538. 20 376396. 46 MWD+IFR-AK-CAZ-SC ~ 4056. 53 47. 74 292 .84 3198. 09 3141 .86 1036 .09 -1762 70 5958567. 07 376331. 84 MWD+IFR-AK-CAZ-SC ~ 4152. 15 48. 23 293 .11 3262. 09 3205 .86 1063 .83 -1828 .11 5958595. 85 376266. 89 MWD+IFR-AK-CAZ-SC 4247. 27 48. 04 293 .32 3325. 57 3269 .34 1091 .75 -1893 .21 5958624. 83 376202. 26 MWD+IFR-AK-CAZ-SC I 4343. 39 47. 84 293 .03 3389. 97 3333 74 1119 .83 -1958 .82 5958653. 97 376137. 12 MWD+IFR-AK-CAZ-SC i 4438. 38 47. 51 294 .04 3453. 93 3397 .70 1147 .87 -2023 .21 5958683. 05 376073. 20 MWD+IFR-AK-CAZ-SC ' 4532. 75 48. 28 295 .14 3517. 20 3460 .97 1177 .01 -2086 .87 5958713. 21 376010. 03 MWD+IFR-AK-CAZ-SC i i 4627. 72 49. 43 296 .27 3579. 69 3523 .46 1208 .03 -2151 .30 5958745. 27 375946. 11 i MWD+IFR-AK-CAZ-SC I 4722. I 85 49. 05 296 .21 3641. 80 3585 .57 1239 .89 -2215 .93 5958778. 17 375882. 01 MWD+IFR-AK-CAZ-SC ~ ~ 4817. 99 48. 32 296 .58 3704. 61 3648 .38 1271 .66 -2279 .94 5958810. 97 375818. 53 MWD+IFR-AK-CAZ-SC ~ 4913. 10 48. 02 297 .05 3768. 04 3711 .81 1303 .63 -2343. 19 5958843. 96 375755. 82 t MWD+IFR-AK-CAZ-SC 5008. 15 50. 54 295 .75 3830. 04 3773 .81 1335 .64 -2407. 71 5958877. 01 375691. 82 MWD+IFR-AK-CAZ-SC 5103. 85 50. 72 296 .39 3890. 75 3834 .52 1368 .15 -2474 .17 5958910. 60 375625. 91 MWD+IFR-AK-CAZ-SC 5198. 09 50. 18 295 .41 3950. 76 3894 .53 1399 .90 -2539 .53 5958943. 39 375561. 08 MWD+IFR-AK-CAZ-SC 5293. 58 49. 86 295 .78 4012. 11 3955 .88 1431 .51 -2605 .52 5958976. 06 375495. 61 MWD+IFR-AK-CAZ-SC I 5389. 04 49. 99 295 .66 4073. 57 4017 .34 1463 .21 -2671 .33 5959008. 82 375430. 33 MWD+IFR-AK-CAZ-SC 5484. 03 49. 57 295 .10 4134. 90 4078 .67 1494 .30 -2736 .86 5959040. 97 375365. 32 MWD+IFR-AK-CAZ-SC ; 5579. 26 49. 57 295 J8 4196. 66 4140 .43 1525 .43 -2802 .32 5959073. 16 375300. 38 MWD+IFR-AK-CAZ-SC 5674 J8 49. 74 295 .90 4258. 50 4202 .27 1557 .17 -2867 .84 5959105. 95 375235. 39 MWD+IFR-AK-CAZ-SC i, 5769. 71 49. 90 295 .65 4319. 75 4263 .52 1588 .70 -2933 .16 5959138. 54 375170. 60 MWD+IFR-AK-CAZ-SC ~ 5864. 90 50. 55 295 .12 4380. 65 4324 .42 1620 .06 -2999 .25 5959170. 97 375105. 03 MWD+IFR-AK-CAZ-SC 5960. 37 50. 29 294 .79 4441. 48 4385 .25 1651 .11 -3065 .96 5959203. 09 375038. 83 MWD+IFR-AK-CAZ-SC II 6055. 81 50. 36 295 .63 4502. 41 4446 .18 1682 .40 -3132 .42 5959235. 45 374972. 89 MWD+IFR-AK-CAZ-SC ~ 6151. 10 49. 81 294 .97 4563. 56 4507 .33 1713 .63 -3198 .50 5959267. 75 374907. 34 MWD+IFR-AK-CAZ-SC 6246. 50 49. 07 293 .64 4625. 59 4569 .36 1743 .47 -3264 .55 5959298. 65 374841. 79 MWD+IFR-AK-CAZ-SC 6341. 22 49. 69 293 .54 4687. 26 4631 .03 1772 .24 -3330 .44 5959328. 48 374776. 38 MWD+IFR-AK-CAZ-SC 6437. 22 49. 70 295 .26 4749. 36 4693 .13 1802 .48 3397 .10 5959359. 80 374710. 22 MWD+IFR-AK-CAZ-SC ~ 6532. 22 49. 76 294 .86 4810. 76 4754 .53 1833 .18 -3462 .77 5959391. 56 374645. 07 MWD+IFR-AK-CAZ-SC I 6627. 38 50. 08 295 .51 4872. 03 4815 .80 1864 .17 -3528 .65 5959423. 60 374579. 70 MWD+IFR-AK-CAZ-SC i I 6722. 12 50. 08 296 .60 4932. 83 4876 .60 1896 .08 -3593 .93 5959456. 57 374514. 95 MWD+IFR-AK-CAZ-SC i 6517. 24 50. 17 295 .73 4993. 81 4937 .58 1928 .27 -3659 .45 5959489. 81 374449. 97 MWD+IFR-AK-CAZ-SC ~ I 6912. 39 50. 55 295 .01 5054. 52 4998 .29 1959 .66 -3725 .65 5959522. 27 374384. 29 MWD+IFR-AK-CAZ-SC I 7007. 65 50. 70 295 .44 5114. 95 5058 .72 1991 .05 -3792 .27 5959554. 73 374318. 20 I MWD+IFR-AK-CAZ-SC 7102. 95 50. 92 295 .53 5175. 17 5118 .94 2022 .83 -3858 .94 5959587. 59 374252. 05 MWD+IFR-AK-CAZ-SC ~ ~ 7198. 01 50. 44 295 .30 5235. 40 5179 .17 2054 .39 -3925 .36 5959620. 22 374186. 16 MWD+IFR-AK-CAZ-SC ' 7294. 10 50. 14 294 .93 5296. 80 5240 .57 2085 .76 -3992 .30 5959652. 67 374119. 75 MWD+IFR-AK-CAZ-SC • • Halliburton Company Survey Report ;~a~,pany ~Ont~tr~hillips ~tl~ska lr~c Datc. ~#t13i~0.07. , , Tirne: 14:Q51(3 Page 3 ~=F~Ld ~olwHe #3iv~r Unit Go-urdinatc~lE)3tef~re~ . ~~~ W~:11: CD4 3fl6 "fr~e Nca~tk~, ~ ~€e =. s~18~G~4 ~ ~ ~ ae ' t~ 5& ~ . C}4- ; ~~ ~ > ; We1i. ~174-~ - ~ ~~ ~ Seet~on~(~'~ ~e~ reu~c+e e { . . , '~ ~ t~ON,f~:t1p~ ~96 ~6A~~ .. 'Wel~paths Ci~4~~ ' SanFey~akulafionMeth~cl ',MinirnumCunr~ture Tlb Or,~t~e Survey 1~D~' Itt~! zi~r~ = ', 'TYD , ', ~~s T~?I7t ~ _ : N/~ =_ ~. - ~ti~V ' . _ ~ ~ MapPf^ ~ ; MapE. , ~ ; '~~il ' - . f~ ~!~ ; c dee~ ft ft ' ft ft ' ft ;=' }~ ' ,. , . . 7389.26 50.53 293. 87 5357 .54 5301. 31 2116 .02 -4059. 01 5959684. 01 374053 .54 MWD+IFR-AK-CAZ-SC 7484.30 50.28 293. 87 5418 .11 5361. 88 2145 .66 -4125. 98 5959714. 72 373987 .07 MWD+IFR-AK-CAZ-SC 7579.10 49.73 294. 00 5479 .04 5422. 81 2175 .12 -4192. 36 5959745. 26 373921 .18 MWD+IFR-AK-CAZ-SC 7673.97 49.75 296 .19 5540 .36 5484. 13 2205 .82 -4257. 91 5959777. 01 373856 .13 MWD+IFR-AK-CAZ-SC 7768.91 49.86 297 .56 5601 .63 5545 .40 2238 .61 -4322. 60 5959810. 84 373792 .00 MWD+IFR-AK-CAZ-SC 7863.93 50.42 297. 92 5662 .53 5606. 30 2272 .56 -4387. 15 5959845. 83 373728 .00 MWD+IFR-AK-CAZ-SC 7959.20 49.57 296 .66 5723 .78 5667 .55 2306 .02 -4452. 00 5959880. 33 373663 .71 MWD+IFR-AK-CAZ-SC 8055.04 50.23 296 .37 5785 .51 5729 28 2338 .74 -4517. 60 5959914. 12 373598 .66 MWD+IFR-AK-CAZ-SC 8150.97 50.59 295 .69 5846 .64 5790 .41 2371 .19 -4584. 03 5959947. 63 373532 .77 MWD+iFR-AK-CAZ-SC 8245.56 50.26 295 .93 5906 .91 5850 .68 2402 .93 -4649. 66 5959980. 43 373467 .67 MWD+IFR-AK-CAZ-SC I 8340.75 49.90 295 .11 5967 .99 5911 .76 2434 .38 -4715. 54 5960012. 94 373402 .31 MWD+IFR-AK-CAZ-SC i 8435.86 49.67 294 .78 6029 .40 5973 .17 2465 .01 -4781. 40 5960044. 64 373336 .97 MWD+IFR-AK-CAZ-SC ~ 8531.44 49.85 294. 97 6091 .14 6034 .91 2495 .70 -4847 .59 5960076. 39 373271 .29 MWD+IFR-AK-CAZ-SC ; I 8626.76 49.91 294. 04 6152 .57 6096. 34 2525 .94 -4913. 91 5960107. 70 373205 .47 MWD+IFR-AK-CAZ-SC I 8721.97 50.86 295. 95 6213 .28 6157. 05 2556 .93 -4980. 38 5960139. 76 373139 .52 MWD+IFR-AK-CAZ-SC 8817.58 50.56 294. 38 6273 .83 6217. 60 2588 .40 -5047. 35 5960172. 31 373073 .07 MWD+IFR-AK-CAZ-SC 8912.60 49.80 293. 91 6334 .67 6278. 44 2618 .25 -5113. 94 5960203. 23 373006 .98 MWD+IFR-AK-CAZ-SC 9007.63 49.09 293. 83 6396 .46 6340. 23 2647 .47 -5179. 97 5960233. 52 372941 .44 MWD+IFR-AK-CAZ-SC 9102.92 49.53 294. 30 6458 .59 6402. 36 2676 .93 -5245. 94 5960264. 04 372875 .96 MWD+IFR-AK-CAZ-SC 9197.93 50.29 295. 29 6519 .77 6463. 54 2707 .42 -5311. 92 5960295. 59 372810 .49 MWD+IFR-AK-CAZ-SC 9292.87 49.60 295 .81 6580 .87 6524 .64 2738 .76 -5377. 48 5960327. 99 372745 .45 MWD+IFR-AK-CAZ-SC 9388.00 49.61 296 .26 6642 .52 6586 .29 2770 .56 -5442. 58 5960360. 84 372680 .88 MWD+IFR-AK-CAZ-SC I 9482.13 51.04 296 .61 6702 .61 6646 .38 2802 .81 -5507. 45 5960394. 14 372616 .54 MWD+IFR-AK-CAZ-SC i 9578.94 51.75 297 .10 6763 .02 6706 .79 2836 .99 -5574. 95 5960429. 40 372549 .62 MWD+IFR-AK-CAZ-SC ~ I i 9674.98 50.91 295 .21 6823 .03 6766 .80 2870 .04 -5642. 24 5960463. 54 372482 .87 ! MWD+IFR-AK-CAZ-SC ! ; 9770.31 50.93 294 .88 6883 .12 6826 .89 2901 .37 -5709. 29 5960495. 95 372416 .35 MWD+IFR-AK-CAZ-SC ~ j 9865.65 50.36 294 .50 6943 .58 6887 .35 2932 .17 -5776. 27 5960527. 82 372349 .89 MWD+IFR-AK-CAZ-SC 9960.90 49.77 293 .84 7004 .72 6948 .49 2962 .07 -5842. 90 5960558. 80 372283 .75 MWD+IFR-AK-CAZ-SC ! 10056.16 50.25 294. 60 7065 .94 7009 .71 2992 .01 -5909. 46 5960589. 82 372217 .70 MWD+IFR-AK-CAZ-SC , 10149.17 49J6 296. 18 7125 .73 7069. 50 3022 .56 -5973. 83 5960621. 40 372153 .83 MWD+IFR-AK-CAZ-SC ~ 10246.28 49.50 295. 74 7188 .63 7132. 40 3054 .95 -6040. 35 5960654. 86 372087 .85 MWD+IFR-AK-CAZ-SC 10315.89 50.06 295. 66 7233 .57 7177. 34 3078 .00 -6088. 24 5960678. 68 372040 .34 MWO+IFR-AK-CAZ-SC ', 10346.00 ~ 50.06 295. 66 7252 .90 / 7196. 67 3087 .99 -6109. 05 5960689 A2 ' 372019 J0 ~ PROJECTED to TD ~ Fluid Type Estimated Top Free Water (%,) ` Cement Summary CD4-306 '.3 ~ ~ ~ 1. ~l' u ' 2 `s- ~~ ~ ~~ ~~ / ~ 1 ~ ,_, Fluid Description ~ y- .s ,n~. Amount (sacks) r~k:~ Class ,~"+4 ~. ,.. . , n, , Volume Pumped (bbl) Estimated Bottom (ftK6) Fercent Excess Pumped (%) Yield (ft'/sack) Mix H20 Ratio (gai/sack) Density (Iblgai) Plastic Viscosity (cp) Thickening Time (hrs) 7st Compressive Strength (psi) _. K, . €- F._ ~ ~ ~_ ~~ ~.~ •..K ,, 4 \ , _.. ..r.. .~.E ~ .., - . ~' ... . ~ , ~ ,~, ~" .. ~,...~ 4 . ~,. .A~ , ~ ~ `~ .rs~C.,:. M' ~ ~`~ ;~~''F - ~{t '~S j' ~ ! 4 ,~. ~ f'~. ~ -- ~..~~ .,.~, .: „ -.a ~ ~$' ~ ~ ~ ... . £~ -.:k ~r :• ... . ~. .m,;. . • . ,,. . _ __ , ~_„ , . :::~;. ,. ~' E~~ ~ :::: ~. _. - < :: . , ~~.+;; ..:'-``~« __. `a..?! .,. -. . . ~ ,..... °. :?~. , ~ ~;`~ .:. Cementing End Date Weilbore 7/17/2007 7/17/2007 Evaluation Method Cement Evaluation Results Retums to SurFace Comment Cement 9 5/8" csg as follows: Pumped 30 bbis Biazon water w/ nut plug for marker - switched to Dowell - Pumped 5 bbls wafer - Test lines to 4000 psi - Dropped btm plug - Mixed & pumped 50 bbls MudPush @ 10.5 ppg @ 5 bpm @ 450 psi - Mixed & pumped Lead slurry (AS 3 Lite) @ 10.7 ppg @ 7.5 bpm @ 700 psi - Observed nut plug marker @ Shakers w/ 278 bbls pumped - Pumped down surge can (297 bbls total )- Switched over to tail slurry Pumped 50.38 bbls Class G w/ additives) @ 15.8 ppg @ 4 bpm @ 470 psi - Dropped top plug w/ 20 bbls water f/ Dowell - Switched to rig pumps & displaced w/179.8 bbls - 9.8 ppg mud @ 6.5 bpm @ 644 psi for first 170 bbls - slowed pump to 3.5 bpm for last 10 bbis @ 480 to 510 psi - Bumped plug w/ 1027 psi - Checked floats OK - CIP @ 03:37 hrs.- Full circulation throughoutjob w/ 130 bbis 10.7 ppg cmt to surface / '...e~ . ,: . F. ,`~\:~:E ; . .`e\ t~" C' ~ .~~f E \~ ~ ~. ~~_ ~S' ~: ~ ia \~' ~~c 7~~ ~B ~ "~ s.... <. ...€ ra:::.. .s' ~. 2 :.. . _~ ~.~d ..:.:,,,.,., ~ : ~. .. .~._ . . _ ; Top (ftK6) Bottom (ftKB) Full Retum? Cmnt Rtrn (bbl) Top Plug? ~ ~ Bottom Piug?~ 0.0 2,727.0 Yes 130.0 No Yes Initial Pump Rate (bbl/min) Final Pump Rate (bbl/min) Average Pump Rate (bbl/min) Final Pump Pressure (psi) Plug Bump Pressure (psi) 8 4 8 490A 1,027.0 Pipe Reciprocated? - Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? Pipe RBM (rpm) Yes 10.00 1 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) ~ Drill Out Date ~ , ~, .. ; ~ ~E3f~ ~1, e.L ~ . • .:•, ~ ~ .....~ :•.~ ~ *~,~~,. ; :.~_~~ ~i \ ~" .:. ..., . ., ~ ~~ ~ _ ,,. .:~9 ;~... ^`'~~ ~~:?~~ ~ ~ t . t~ ~ : Z ~~u ~ ,.:-: ... . ;^~..•~.....~,, . .~E. . : . ,.,.:~ , ~;..,,.,,,,..,~: .... „ ..... ~ ~ : ~~~~ :~, ,~;• Fluid Type (Fluid Description Amount (sacks) Ctass Volume Pumped (bbl) Lead Cement I 360 G 297.0 Estimated Top (kKB) Estimated Bottom (ftKB) Percent Excess Pumped (%) Yield (ft /sack) Mix H20 Ratio (gallsack) 36A 2,227.0 133A 4:63 2175 Free Water (%) 'Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) 1st Compressive Strength (psi) 10.70 4.50 - t: ~ _ ~ : ~ ~i~~~..,,.., ~ .. ~.u• ...,, ,,. . , ~ ~ E ~~~~ ~,. . ~a:, . .... ~ ~ 4:,', ~ ..a. „v k ~ ....::: .......... 4~ ..~x.a~ ,e _ ~ , ~ . ;.. .' ~` ....r~„~.. , , . ~~ ' . 3"tc~ ~ :;. ~.. . < . ~ ..y. Fluid Type Fluid Description Amount (sacks) Class Volume Pumped (bbl) Tail Cement 234 G 50A Estimated Top (ftKBj Estimated Bottom (ftKB) Percent Excess Pumped (%) Yield (fY/sack) Mix H20 Ratio (gal/sack) 2,227.0 2,727.0 50.0 1.17 5.10 Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) 1st Compressive Strength (psi) 15.80 5.00 Cementing Start Date Cementing End Date Welibore 7/23/2007 7/23/2007 Evaluation Method Cement Evaluation Results Comment Dowell pumped 20 bbis CW100, 30 bbls 10.5 ppg MudPush, dropped bottom plug, 86 bbls 15.8 ppg cement (416 sx), dropped top plug and 20 bbls water Rig displace cement with 369 bbls 9.8 qpg mud at 6 bpm. Reduced rate to 3.5 bom last 10 bbls. Bum~ed nlua with 750 osi circ nressure Pressure csa to ~ ~ 16-Aug-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD4-306 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 36.63' MD Window / Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 10,346.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Atten@HALLiBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 ~ ~ n ~~ A / Date ld~~~o~-~ ~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) p~o~/ O '" I Message ~ ~ Davies, Stephen F (DOA) From: Galiunas, Elizabeth C [Elizabeth.C.Galiunas@conocophillips.com] Sent: Friday, July 27, 2007 10:29 AM To: Davies, Stephen F (DOA) Subject: CD4-306 XY coordinates Steve, Here are the surveyed surface XYs for Cd4-306. Your corrections on the 401 are correct. X: 378077.4 Y: 5957502.6 Sorry for the confusion. Liz Galiunas Drilling Engineer Alpine Drilling Team ~ce: (907~265-6247 Cell: (907)-441-4871 Page 1 of 1 7/27/2007 ~ ~ ~ o ~ a ~ Q SARAH PALIN, GOVERNOR ~S~ 0~ ~i`D G~-7 333 W. 7thAVENUE, SUITE 100 CO~y'+1G-R~~-lejOx ~OrQII<+L+IO~ ANCHORAGE,ALASKA 99501-3539 i~ ~~~ PHONE (907) 279-1433 FAX (907) 276J542 C. Alvord WNS Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Nanuq-Kuparuk Oil Pool, CD4-306 ConocoPhillips Alaska, Inc. Permit No: 207-094 Surface Location: 2907' FNL, 167' FEL, SEC. 24, T11N, R4E Bottomhole Location: 5119' FNL, 951' FEL, SEC. 14, T11N, R4E Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service 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 ins~ (pager). DATED this ~ay of July, 200'7 cc: Department of Fish & Gaxne, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ ~ ~`1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION « ~E~.e~l~~~ ~U~Q~2~~~ PERMIT TO DRILL 20 AAC 25.005 Alaska Oi~ & Gas Gnns, C°mmission A....Mnr9n0__ 1 a. Type of Work: Drill Q v Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ~ Development Oil ~ Stratigraphic Test ^ Service ~^ ~` Development Gas ~ Multiple Zone^ Single Zone ~ 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ~ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 ' 11. Well Name and Number: CD4-306 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 10280' ~ ND: 7212' ' 12. Field/Pool(S): Colville River Field 4a. Location of Well (Govemmental Section): Surface: 2907 FNL, 167 FEL, Sea 24 , T 11 N R 4 E 7. Property Designation: ~ ADL 380075, 380077 ~ Nanuq Kuparuk Oil Pool - Top of Productive Horizon: 5170 FNL, 842 FEL, Sec. 14 , T 11 N R 4 E 8. Land Use Permit: LAS2112 13. Approximate Spud ate: ~ ' 7! l2007 ~~, ~'3%'~ Total Depth: 5119 FNI, 951 FEL, Sec. 14 , T 11 N R 4 E 9. Acres in Property: 5759 14. Distance to Nearest Property: 11,567' FNL of Nanuq PA 4b. Location of Well (State Base Plane Coordinates): 3~8o~~.y S957S'o2.~ SurfaCe: x- 378 . y- •>75 r . Zone- 4 10. KB Elevation ~Height above GL): 37' RKB feet 15. Distance to Nearest ~, Well within Pool: CD4-319 2165' at 10,075' MD 16. Deviated welis: Kickoff depth: 450 ~ ft. Maximum Hole Angle: 50° ' deg 17. Maximum Anticipated Pressures in psig (see 2o aAC 25.035) Downhole: 3263 psig ~ Surface: 2542 psig ' 18. Casing Program if ti S Setting Depth Quantity of Cement Size ica ons peC Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including sfage data} 24" 16" 62.5# H-40 Weldsd 77 37 37 114 114' pre-instalied 12.25" 9-518" 40# L-&0 BTC 2724 37 37 2761 ~ 2400 ~ 463 sx AS Lite, 230 sx 15.8 G 8.75" 7" 26# L-80 BTCM 10243 37 37 10280 7212 398 sx Glass G, 183 Sx ciass G for K2 4.5" 12.6# L-80 IBT 9223 32 32 9255 6556 tubing 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Tofal Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Cond uctor/Structu ral Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch~ Drilling ProgramQ Time v. Depth Plot ~ Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed RepoR ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContaCt L. Galiunas Printed Name C. Alvord ~ Title WNS Drilling Team Lead Signature ,~ s~~ -~ / Phone Z~~_ `ct~s Date 7/~ `~ ~ ~-y''--- /'"/[ L. Gali n Commission Use Only Permit to Drill Number: ~?~ ~ ~ API Number: 50- ~d3 ~ ~5~~ ~V~ Permit Approval Date: ' • ~`a, • ~ ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed met ne, gas hydrates, or gas contained in shales: ~ ~~'~° C~~y`~ ~'~~~(, ~j Samples req'd: Yes ^ No Mud log req'd: Ye0 N~ Other: ~o~ ``~``~~~~~,~~~ H2S measures: Yes ~ No Dire " al svy req'd: es ~ No ^ 5 "`' ~ A~c~ a-'1, ~D'iv~c~c wa~~~ ~ AA~.3-S .O~S 1~.~ ~> V~'~Zr...u~ aQE o ti~ cacw ~~ DATE: %~~~ ~~ / P OVED BY THE COMMISSION , COMMISSIONER Form 10-401 Revised 12/2005 ~~~3-?\ _ ~D,Submit~~up,'+r~j~ TZ ~ % ~ ~ ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 2, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD4-306 Dear Sir or Madam: ~ ~~3C'1C~COP`~"11 ~ ~ I 5 ~ ~~1.~ G: ~ ~~, ~z~ ~ . ~.~~ JIJL ~ ~~ ~f~'~ ~ ~iaska ~lil & Gas t ~~ :. ~ ,=~f~~,~~; Anchas~~~ ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injector well from the Nanuq CD4 drilling pad. The intended spud date for this weal is 7/20/2007. It is intended that Doyon Rig 19 be used to drill the welL - i CD4-306 will be a low angle slant well, penetrating the Kuparuk C sand. After setting 7" intermediate casing the well will be completed and perForated as a WAG injector well supporting Kuparuk production wells. At the end of the rig program, the well will be perforated then flowed back to mitigate formation damage. The well will then be closed in awaiting completion of facilities connection which will allow the well to begin injection. It is expected that the K2 (Qannik) sand will be considered a significant hydrocarbon bearing zone. It is planned to pump lead cement, then open a stage tool and pump a second cement job to isolate the K2 f with 500' of cement above and below the interval. This will leave a mud gap between the two stages. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) be granted. There have been 13 surface holes drilled at CD4 and there has not been a significant show of shallow gas or gas hydrates. ~ - 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 APPLlCATlON 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. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 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. ~ 3. Diagram of diverter set up. , ~ ~ If you have any questions or require further information, please contact Liz Galiunas at 265- 6247 or Chip Alvord at 265-6120. Sincerely, Liz Galiun Drilling Engineer Attachments cc: CD4-306 Well File / Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1577 Vern Johnson ATO 1702 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation ~ ~ CD4-306 Drilling Hazards Summary (to be posted in Rig Floor poghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casinq Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuousl durin interval. Well Collision Low G ro sin le shots, travelin c linder dia rams Gas Hydrates Low , Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures ~ Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight _ Surface Formations ' >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densi cement slurries 8-3/4" Hole / 7" Casinq Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' ND increase mud wei ht. 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, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure ~ mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low ; H2S drills, detection systems, alarms, standard well , control ractices, mud scaven ers ~~~G~~lAL ~ Fiord : CD4-306 Procedure ~ 1. Move on Doyon 19. 2. Drill 12-%4' hole to the surface casing point as per the directional plan. (Directional/MWD). 3. Run and cement 9-5/8" surface casing. 4. Install and test BOPE to 5000 psi. 5. Pressure test casing to 3500 psi. 6. Drill out 20' of new hole. Perform leak off test. 7. Pick up and run in hole with 8-3/4" drilling BHA. 8. Drill 8-3/4" hole to intermediate casing point in the reservoir sand. (LWD Program: GR/RES/PWD) 9. Run and cement 7" casing as 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 casing annulus and casing. 10. Run 4-%, 12.6#, L-80 tubing with DB profile, packer, GLM with shear out valve, XN profile and wireline entry guide. Land hanger. 11. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 12. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 13. Circulate tubing to diesel and install freeze protection in the annulus. 14. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 15. Set BPV and secure well. Move rig off. Post rig well work will include pulling the ball and rod assembly, GLV change out, running cement evaluation logs below the tubing tail, perforating the Kuparuk interval and setting an injection valve. ~'~~~t~~~ ~ ~ Well Proximitv Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD4-208 is the nearest existing well to the CD4-306 plan with 41' well to well separation at 650' MD. - Drillinq Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting and low reservoir pressure within the Kuparuk reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation. Annular Pumpinq Operations: Incidental fluids developed from drilling operations on well CD4-306 will be injected into a permitted annulus on CD4 pad or the class 2 disposal well on CD1 pad. The CD4-306 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The significant hydrocarbon zones are the Nanuq, Kuparuk, and the / Qannik reservoir. There will be 500' of cement fill above the top of the Nanuq and Qannik reservoirs. ~ Upon completion of CD4-306 form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure =(12.0 ppg) *(0.052) *(Surf. Shoe TVD) + 1,500 psi _ (12.0 ppg) * (0.052) " (2400') + 1,500 psi = 2998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 -1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 40 L-80 3 BTC 9,090 psi 1,717 psi 5,750 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ~ ~ ~ ~~ ~~~ ~ ~ DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing oint - 12 '/4" Intermediate hole to 7" casing point - 8~/" Density 8.8 - 9.6 ppg ~ 9.6 - 9.8 ppg , PV 10 - 25 YP 20 - 60 15 - 25 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 minute gels <18 API Filtrate NC -10 cc / 30 min 4- 12 cc/30 min (drilling) HPHT Fluid Loss at 160 PH 8.5-9.0 9.0-10.0 KCL Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. / Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. ~ ~ ~ ~~ ~~~ ~ ~ CD4-306 Nanuq Kuparuk Injector Completion 16" Insulated Conductor to ~114' 4-'/Z' 12.6 ppf L-80 IBT Mod. Tubing 3.81" DB Landing Nipple TOC +/- 4903' MD 3770' TVD Stage cementing tool +/- 5919' MD / 4421' TVD 9-5/8" 40 ppf L-80 BTCM Surface Casing 2760' MD / 2400' TVD K2/Qannik sand +/- 5403' MD / 4091' TVD ~dated 07-11-07 ECG WP07 Upper Completion: 1) Tubing Hanger 2) 4-1/2", 12.6#/ft, IBT-Mod Tubing 3) Camco DB nipple 3.81" 4) 4-1/2", 12.6#/ft, IBT-Mod Tubing 5) Camco KBG-2 GLM with shear valve 6) 4-1/2", 12.6#/ft, IBT-Mod Tubing (2) 7) Baker S3 packer with millout extension 8) 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) 9) HES "XN" (3.725") 10) 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) 11) Wireline entry guide - Packer set at 300' MD above Kuparuk. - WLEG at around 200' above Kuparuk Top of intermediate cement 500' above top of Nanuq 8169' MD / 5861' ND +/- 15' perforations Nanuq 8669' MD / 6181' ND Kuparuk C 10122' MD / 7111' ND Top MD ND 32' 32' 2150' 2000' 9722' 6855' 9822' 6918' 9872' 6950' 9922' 6982' 7" 26 ppf L-80 BTC Mod Production Casing @ +/-50° 10280' MD, 7212' TVD ~ 16" Insulated Conductor to ~114' 4-'/2' 12.6 ppf L-80 IBT Mod. Tubing 3.81" DB Landing Nipple 9-5/8" 40 ppf L-80 BTCM Surface Casing 2760' MD / 2400' TVD ~ ~ecl ( ~~ ~. ~ 1 ~~ ~J ~~ TOC +/- 4903' MD 3770' TVD Stage cementing tool +/- 5919' MD / 4421' TVD K2/Qannik sand +/- 5403' MD / 4091' ND Top of in rmediate cement 500' ove top of Nanuq 81 ' MD / 5861' TVD ~ WP07 / ~ A I ~v ~ Upper ompletion: 1) ubing Hanger 2) 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DB nipple 3.81" 4) 4-1/2", 12.6#/ft, IBT-Mod Tubing 5) Camco KBG-2 GLM with shear valve 6) 4-1/2", 12.6#/ft, IBT-Mod Tubing 7) Baker S3 packer with Millout extension 8) 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) 9) HES "XN" (3.725") 10) 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) 11) Wireline entry guide - Packer set at 250' MD above Kuparuk. - WLEG at around 150' above Kuparuk +/- 15' perforations Nanuq 8669' MD / 6181' TVD Kuparuk C 9405' MD / 6933' TVD Top MD TVD 32' 32' 2150' 2000' 9055' 6428' 9155' 6492' 9205' 6556' 9255' 6588' 7" 26 ppf L-80 BTC Mod Production Casing @ +/-50° 10280' MD, 7212' TVD ORIGI~AL ~ ~ CD4-306 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 si ASP Drilling si 16 914 / 114 10_9 52 53 9 5/8 2761 / 2400 14.5 1086 1571 7" / TD 10280 / 7212 16.0 3263 2542 • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 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 Drilling below conductor casing (16") ASP =[(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1]x114=53psi OR ASP = FPP - (0.1 x D) = 1086 -(0.1 x 2400') = 846 psi Drilling below surface casing (9 5/8") ASP =[(FG x 0.052) - 0.1 ] D _(('l4.5 x 0.052) - 0.1] x 2400 = 1571 psi OR ASP = FPP - (0.1 x D) = 3263 -(0.1 x 7212') = 2542 psi / ~ 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3263 -(0.1 x 7212') = 2542 psi o~~~~~A~ ~ Cementing Pro~ram: C~ 9 5/8" Surface Casin~ run to 2761' MD / 2400' TVD. " Cement from 2761' MD to 2261' (500' of fill) with Class G+ Adds @ 15.8 PPG, and from 2261' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1386' MD). Lead sluriy: (2261'-1386') X 0.3132 ft3/ft X 1.5 (50% excess) = 411.1 ft3 below permafrost 1386' X 0.3132 ft3/ft X 4(300% excess) = 1736.3 ft3 above permafrost Total volume = 41 l.l + 1736.3 = 2147.4 ft3 => 463 Sx @ 4.63 ft3/sk System: 463 Sx ArcticSet Lite 3@ 10.7 PPG yielding 4.63 ft3/sk, Class G+ 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 5001 accelerator, 50% D124 extender and 9% BWOW1 D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 2349 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G+ 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casin~ run to 10280' MD / 7212' TVD Cement from 10280' MD to +/-8169' MD (minimum 500' MD above top of Nanuq reservoir) with Class G+ adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (10,280' -8169) X 0.1503 ft3/ft X 1.4 (40% excess) = 444.2 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 444.2 + 17.2 = 462 ft3 => 398 Sx @ 1.16 ft3/sk System: 398 Sx Class G+ 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk Second Sta~e: Cement from ports in a TAM port collar set 500' below the K2 interval to +/- 500' above the K2 interval with Class G+ additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (5919'-4903') X 0.1503 ft3/ft X 1.4 (40% excess) = 213.8 ft3 annular vol. Total Volume = 213.8 ft3 => 183 Sk @ 1.17 ft3/sk System: 183 Sx Class G+ 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk ' By Weight Of mix Water, all other additives are BWOCement ~ o000 oooo~o~ ~ V10~ON V~I~ F-'N~l~r.......... 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O I. ,,., ~,. ~.. N .. ...... . .... ,, ~, . ~ a C a ~ 400 , > H I ~...,, ....., ..... ~.. i -200~ \h~oo ~ ' ' ~~. ~~,.. .. ,'p . ~,. ~ ... .. ~ I _ I o I o°°,~~~ _ I ~ ~~__, Vertical Section at 296.86° [2000tUin] I . I o° I - 'D4-306 07 ° .. o° .. b~ ~~ ', . .. ~' . o° h° i o° o,° , o° a . __ ^~ O ~~o .. .. . . .. ..... . . /~ ... .. ` \ ~ O~ -bUUU -4UUU -1UUU U West(-)/East(+) [2000ft/in] ~ PLAN DBTAILS CD4-306wp07 Version 4 5/24/2007 Start Point MD Inc Azi TVD +N/-S +E/-W 36.30 0.00 0.00 36.30 0.00 0.00 HALLIBURTDN C~~Ca~MIII ~ __ _ __ -- ---- - - ~ Sperry O~Iiling Services Alaska REFERENCE INFORMATION ~ Co-ordinate (NB) Reference: Well Centre: Plan: CD4-306, True North ~-~ Vertical (TVD) Reference: CD4-306wp07 55.90 Section(VS) Reference: Slot- (O.OON,O.OOE) Measured Depth Reference: CD4-306wp07 55.90 Ca-culation Method: Minimum Curvature ~ ~ ConocoPhillips Alaska, Inc. CPAI Plan Report Company: ConocoPhillips Alaska InC. Date: 6/21/2007 Time: 14:13:16 Page: 1 FSeld: Colville River Unit Caordinate(NE) Reference: Well: Plan: GD4-306, True North Site: Alpine CD4 Vertical (T'VD) Reference: CD4-306wp07 55.9 - WeIL• Plan: CD4-306 Section (VS) Reference: We11 (O.OON,O.OOE,296:86Azi) Wellpat6: Plan: CD4-306 Survey Calcnlation Method: Minimum Gurvature ' Db: Oracle Pl~n: CD4-306wp07 Date Composed: 5/24/2007 Version: 4 Principal: Yes Tied-to: From Well Ref. Point 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; bggm2006 Site: Alpine CD4 Site Position: Northing: 5957526.10 ft Latitude: 70 17 32.966 N From: Map Easfing: 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: Plan: CD4-306 Slot Name: ~« ~ ~ Alpine CD4 ''~'"~ s ~ Well Position: +N/-S -25.07 ft Northing: 5957502:61 ft• Latitude: 70 17 32719 N 2, Z~- r Z,(~`~. ~ +E/-W -96.95 ft Easting: 378077.36 ft- Longitude: 150 59 13.589 W ~~~~~~ / ~ PosiNon Uncertainty: 0.00 ft Wellpath: Plan: CD4-306 Drilled From: Well Ref. Point ~,,Z, ~.,~ Kuparuk Sand Injector Tie-on Depth: 36.30 ft Current Datum: CD4-306wp07 Height 55.90 ft` Above System Datum: Mean Sea Level Magnetic Data: 5/24/2007 Declination: 22.77 deg Field Strength: 57563 nT Mag Dip Angle: 80.68 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 296.86 Survey Program for Definitive Wellpath Date: 5/24/2007 Validated: No Version: 0 Actual From To Survey Toolcode Tool Name ft ft Plan Section Information NID Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft tlegM,00ft deg/100ft deg 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 0.00 0.00 1000.00 13.75 340.00 994.74 61.72 -22.46 2.50 2.50 0.00 340.00 2375.24 50.21 295.46 2153.16 459.78 -579.74 3.00 2.65 -3.24 -54.82 10130.40 50.21 295.46 7115.81 3021.40 -5960.51 0.00 0.00 0.00 0.00 10130.53 50.21 295.46 7115.90 3021.45 -5960.60 3.50 -3.26 1.65 158.73 CD4-306wp07 T1 10280.53 50.21 295.46 7211.90 3071.00 -6064.67 0.00 0.00 0.00 0.00 ~~~~I~~L ~ ~ ConocoPhillips Alaska, Inc. CPAI Plan Report Company:' ConocoPhillips qlaska lnc. Date: 6/21/2007 Time: 14:13:16 Page: 2 Field: ' Colvilie River Unit Caordinate(NE) Reference: Well: Plan: CD4=~06, True North ! Site: Alpine CD4 Vertical ('i'VD) Reference: CD4-306wp07 55,9 Well: Plan: CD4-306 Section (VS) Reference: Well (O.OON,O.OOE,~96.86~4zi) Wellpathc Plan: CD4-306 Snrvey Catcnlation Method: Minimum Curvature - Dbc OrBGe Survey NID Incl Azim TVD 5ys TVD N/S EiW ft deg deg ft ft` ft ft 36.30 0.00 0.00 36.30 -19.60 0.00 0.00 100.00 0.00 0.00 100.00 44.10 0.00 0.00 200.00 0.00 0.00 200.00 144.10 0.00 0.00 300.00 0.00 0.00 300.00 244.10 0.00 0.00 400.00 0.00 0.00 400.00 344.10 0.00 0.00 450.00 0.00 0.00 450.OQ 394.10 0.00 0.00 500.00 1.25 340.00 500.00 444.10 0.51 -0.19 600.00 3.75 340.00 599.89 543.99 4.61 -1.68 700.00 6.25 340.00 699.50 643.60 12.80 -4.66 800.00 8.75 340.00 798.64 742.74 25.06 -9.12 900.00 11.25 340.00 897.11 841.21 41.38 -15.06 1000.00 13.75 340.00 994.74 938.84 61.72 -22.46 1100.00 15.67 330.89 1091.47 1035.57 84.69 -33.10 1200.00 17.88 323.84 118722 1131.32 108.88 -48.73 1300.00 20.29 318.36 1281.72 1225.82 134.24 -69.31 1400.00 22.83 314.03 1374.72 1318.82 160.69 -94.79 1500.00 25.47 310.53 1465.97 1410.07 188.15 -125.09 1600.00 28.18 307.66 155520 1499.30 216.56 -160.13 1700.00 30.93 305.26 1642.18 1586.28 245.83 -199.82 1800.00 33.73 303.22 1726.67 1670.77 275.88 -244.04 1900.00 36.55 301.46 1808.44 1752.54 306.64 -292.68 2000.00 39.40 299.92 1887.26 1831.36 338.02 -345.60 2100.00 42.26 298.55 1962.92 1907.02 369.93 -402.65 2200.00 45.14 297.33 2035.21 1979.31 402.28 -463.69 2300.00 48.03 296.23 2103.92 2048.02 434.99 -528.54 2375.24 50.21 295.46 2153.16 2097.26 459.78 -579.74 2400.00 50.21 295.46 2169.01 2113.11 467.96 -596.92 2500.00 50.21 295.46 2233.00 2177.10 500.99 -666.31 2600.00 50.21 295.46 2296.99 2241.09 534.02 -735.69 2700.00 50.21 295.46 2360.98 2305.08 567.05 -805.07 2760.98 5021 295.46 2400.00 2344.10 587.19 -847.38 2785.98 50.21 295.46 2416.00 2360.10 595.45 -864.73 2800.00 50.21 295.46 2424.97 2369.07 600.08 -874.46 2900.00 50.21 295.46 2488.96 2433.06 633.11 -943.84 3000.00 50.21 295.46 2552.96 2497.06 666.15 -1013.22 3100.00 50.21 295.46 2616.95 2561.05 699.18 -1082.61 3200.00 50.21 295.46 2680.94 2625.04 732.21 -1151.99 3300.00 50.21 295.46 2744.93 2689.03 765.24 -1221.37 3332.93 50.21 295.46 2766.00 2710.10 776.11 -1244.22 3400.00 50.21 295.46 2808.92 2753.02 798.27 -1290.75 3500.00 50.21 295.46 2872.91 2817.01 831.30 -1360.14 3600.00 50.21 295.46 2936.91 2881.01 864.33 -1429.52 3700.00 50.21 295.46 3000.90 2945.00 897.36 -1498.90 3800.00 50.21 295.46 3064.89 3008.99 930.40 -1568.29 3900.00 50.21 295.46 3128.88 3072.98 963.43 -1637.67 4000.00 50.21 295.46 3192.87 3136.97 996.46 -1707.05 4100.00 50.21 295.46 3256.86 3200.96 1029.49 -1776.44 4200.00 50.21 295.46 3320.86 3264.96 1062.52 -1845.82 4300.00 50.21 295.46 3384.85 3328.95 1095.55 -1915.20 4400.00 50.21 295.46 3448.84 3392.94 1128.58 -1984.58 4500.00 50.21 295.46 3512.83 3456.93 1161.61 -2053.97 4600.00 50.21 295.46 3576.82 3520.92 1194.65 -2123.35 4700.00 50.21 295.46 3640.81 3584.91 1227.68 -2192.73 MapN M~pE ALS ft if deg/100ft 5957502.61 ~ 378077.36 ~ 0.00 5957502.61 378077:36 0.00 5957502.61 378077.36 0.00 5957502.61 378077.36 0.00 5957502.61 378077.36 0.00 5957502.61 378077.36 0.00 5957503.13 378077.18 2.50 5957507.25 378075.76 2.50 5957515.48 378072.91 2.50 5957527.82 378068.65 2.50 5957544.23 378062.97 2.50 5957564.68 378055.90 2.50 5957587.82 378045.64 3.00 5957612.26 378030.41 3.00 5957637.94 378010.24 3.00 5957664.80 377985.20 3.00 5957692.75 377955.35 3.00 5957721.72 377920.78 3.00 5957751.63 377881.57 3.00 5957782.39 377837.85 3.00 5957813.93 377789.72 3.00 5957846.16 377737.32 3.00 5957878.99 377680.79 3.00 5957912.32 377620.29 3.00 5957946.08 377555.98 3.00 5957971.69 377505.20 3.00 5957980.15 377488.15 0.00 5958014.30 377419.32 0.00 5958048.45 377350.49 0.00 5958082.60 377281.66 0.00 5958103.42 377239.68 0.00 5958111.96 377222.47 0.00 5958116.75 377212.82 0.00 5958150.89 377143.99 0.00 5958185.04 377075.16 0.00 5958219.19 377006.33 0.00 5958253.34 376937.49 0.00 5958287.49 376868.66 0.00 5958298.74 376846.00 0.00 5958321.64 376799.83 0.00 5958355.79 376731.00 0.00 5958389.94 376662.16 0.00 5958424.09 376593.33 0.00 5958458.24 376524.50 0.00 5958492.39 376455.67 0.00 5958526.54 376386.83 0.00 5958560.69 376318.00 0.00 5958594.84 376249.17 0.00 5958628.99 376180.34 0.00 5958663.14 376111.50 0.00 5958697.28 376042.67 0.00 5958731.43 375973.84 0.00 5958765.58 375905.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 KOP; 2.5 DLS 0.00 0.00 0.00 0.00 0.00 0.00 305.18 313.99 320.74 325.92 329.95 333.14 335.71 337.79 339.52 340.96 342.18 343.21 344.09 344.85 Sail; 50° for 7755' 0.00 0.00 0.00 0.00 0.00 9 5/8" x 12 1/4" 0.00 C-30 0.00 0.00 0.00 0.00 0.00 0.00 0.00 C-20 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ~.~~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ConocoPhillips Alaska, Inc. CPAI Plan Report Company: ConocoPhillips Alaska inC. Date: 6/21/2~07 Ti~ea 14:13:16 P~ge: 3 Field: Colville River Unit Caordinate(NE) Re ference: WeII: Plan: CD4-306; True North Site: Aipine CD4 Vertical (TVD) Reference: C D4-306wp07 55.9 WeIL• Plan: CD4-306 SecHon (VS} Reference: We0 (O.OON,O.OOE,296.86Azi) Wellpath: Plan: CD4-306 Sarvey Calculstion Method: Minimum Curvature bba Oracle Survey NID Incl Azim TVD Sys TVD lri/S E/W MapN MapE DLS TFO ` Comment ft tleg deg ft ft ft ft ft ft deg/100ft deg' 4800. 00 50 .21 295.46 3704 .81 3648 .91 1260. 71 -2262.12 5958799 .73 375836 .17 0.00 0.00 4900. 00 50 .21 295.46 3768 .80 3712 .90 1293. 74 -2331.50 5958833 .88 375767 .34 0.00 0.00 5000. 00 50 .21 295.46 3832 .79 3776 .89 1326. 77 -2400.88 5958868 .03 375698 .51 0.00 0.00 5012. 83 50 .21 295.46 3841 .00 3785 .10 1331. 01 -2409.79 5958872 .41 375689 .68 0.00 0.00 K-3 5100. 00 50 .21 295.46 3896 .78 3840 .88 1359. 80 -2470.27 5958902 .18 375629 .68 0.00 0.00 5200. 00 50 .21 295.46 3960 .77 3904 .87 1392. 83 -2539.65 5958936 .33 375560 .84 0.00 0.00 5300. 00 50 .21 295.46 4024 .76 3968 .86 1425. 86 -2609.03 5958970 .48 375492 .01 0.00 0.00 5341. 00 50 .21 295.46 4051 .00 3995 .10 1439. 41 -2637.48 5958984 .48 375463 .79 0.00 0.00 Basal K-3 5400. 00 50 .21 295.46 4088 .76 4032 .86 1458. 90 -2678.41 5959004 .63 375423 .18 0.00 0.00 5403. 51 50 .21 295.46 4091 .00 4035 .10 1460. 05 -2680.85 5959005 .83 375420 .77 0.00 0.00 K-2 5500. 00 50 .21 295.46 4152 .75 4096 .85 1491. 93 -2747.80 5959038 .78 375354 .35 0.00 0.00 5551. 96 50 .21 295.46 4186 .00 4130 .10 1509. 09 -2783.85 5959056 .52 375318 .58 0.00 0.00 Base K-2 5600. 00 50 .21 295.46 4216 .74 4160 .84 1524. 96 -2817.18 5959072 .93 375285 .51 0.00 0.00 5700. 00 50 .21 295.46 4280 .73 4224 .83 1557. 99 -2886.56 5959107 .08 375216 .68 0.00 0.00 5800. 00 50 .21 295.46 4344 .72 4288 .82 1591. 02 -2955.95 5959141 .23 375147 .85 0.00 0.00 5900. 00 50. 21 295.46 4408 .71 4352 .81 1624. 05 -3025.33 5959175. 38 375079 .02 0.00 0.00 6000. 00 50. 21 295.46 4472 .71 4416 .81 1657. 08 -3094.71 5959209. 53 375010 .19 0.00 0.00 6100. 00 50 .21 295.46 4536 .70 4480 .80 1690. 11 -3164.10 5959243. 67 374941 .35 0.00 0.00 6200. 00 50 .21 295.46 4600 .69 4544 .79 1723. 15 -3233.48 5959277. 82 374872 .52 0.00 0.00 6300. 00 50 .21 295.46 4664 .68 4608 .78 1756. 18 -3302.86 5959311. 97 374803 .69 0.00 0.00 6400. 00 50 .21 295.46 4728 .67 4672 .77 1789 21 -3372.25 5959346. 12 374734 .86 0.00 0.00 6500. 00 50 .21 295.46 4792 .66 4736 .76 1822. 24 -3441.63 5959380. 27 374666 .02 0.00 0.00 6600. 00 50 .21 295.46 4856 .66 4800 .76 1855. 27 -3511.01 5959414. 42 374597 .19 0.00 0.00 6700. 00 50 .21 295.46 4920 .65 4864 .75 1888. 30 -3580.39 5959448 .57 374528 .36 0.00 0.00 6800. 00 50 .21 295.46 4984 .64 4928 .74 1921. 33 -3649.78 5959482 .72 374459 .53 0.00 0.00 6900. 00 50 .21 295.46 5048 .63 4992 .73 1954. 36 -3719.16 5959596. 87 374390 .69 0.00 0.00 7000. 00 50 .21 295.46 5112 .62 5056 .72 1987. 40 -3788.54 5959551. 02 374321 .86 0.00 0.00 7100. 00 50 .21 295.46 5176 .61 5120 .71 2020. 43 -3857.93 5959585. 17 374253 .03 0.00 0.00 7200. 00 50 .21 295.46 5240 .61 5184 .71 2053. 46 -3927.31 5959619. 32 374184 .20 0.00 0.00 7300. 00 50 .21 295.46 5304 .60 5248 .70 2086. 49 -3996.69 5959653. 47 374115 .36 0.00 0.00 7400. 00 50 .21 295.46 5368 .59 5312 .69 2119. 52 -4066.08 5959687. 62 374046 .53 0.00 0.00 7500. 00 50 .21 295.46 5432 .58 5376 .68 2152. 55 -4135.46 5959721. 77 373977 .70 0.00 0.00 7600. 00 50 .21 295.46 5496 .57 5440 .67 2185. 58 -4204.84 5959755. 92 373908 .87 0.00 0.00 7700. 00 50 .21 295.46 5560 .56 5504 .66 2218. 61 -4274.22 5959790. 07 373840 .03 0.00 0.00 7800. 00 50 .21 295.46 5624 .56 5568 .66 2251. 65 -4343.61 5959824. 21 373771 .20 0.00 0.00 7900. 00 50. 21 295.46 5688 .55 5632 .65 2284. 68 -4412.99 5959858. 36 373702 .37 0.00 Q.00 8000. 00 50. 21 295.46 5752 .54 5696 .64 2317. 71 -4482.37 5959892. 51 373633 .54 0.00 0.00 8005. 41 50. 21 295.46 5756 .00 5700 .10 2319. 49 -4486.13 5959894. 36 373629 .81 0.00 0.00 Albian 97 8100. 00 50 .21 295.46 5816 .53 5760 .63 2350. 74 -4551.76 5959926. 66 373564 .70 0.00 0.00 8200. 00 50 .21 295.46 5880 .52 5824 .62 2383. 77 -4621.14 5959960. 81 373495 .87 0.00 0.00 8300. 00 50 21 295.46 5944 .51 5888 .61 2416. 80 -4690.52 5959994. 96 373427 .04 0.00 0.00 8400. 00 50 .21 295.46 6008 .51 5952 .61 2449. 83 -4759.91 5960029. 11 373358 .21 0.00 0.00 8500. 00 50 .21 295.46 6072 .50 6016 .60 2482. 86 -4829.29 5960063. 26 373289 .37 0.00 0.00 8600. 00 50 .21 295.46 6136 .49 6080 .59 2515. 90 -4898.67 5960097. 41 373220 .54 0.00 0.00 8669. 56 50 .21 295.46 6181 .00 6125 .10 2538. 87 -4946.93 5960121. 16 373172 .66 0.00 0.00 Albian 96 (Nanuq) 8700. 00 50. 21 295.46 6200 .48 6144 .58 2548. 93 -4968.05 5960131. 56 373151 .71 0.00 0.00 8800. 00 50. 21 295.46 6264 .47 6208 .57 2581. 96 -5037.44 5960165. 71 373082 .88 0.00 0.00 8900. 00 50 .21 295.46 6328 .46 6272 .56 2614. 99 -5106.82 5960199. 86 373014 .04 0.00 0.00 9000. 00 50 .21 295.46 6392 .45 6336 .55 2648. 02 -5176.20 5960234. 01 372945 .21 0.00 0.00 9100. 00 50 .21 295.46 6456 .45 6400 .55 2681. 05 -5245.59 5960268. 16 372876 .38 0.00 0.00 9200. 00 50 .21 295.46 6520 .44 6464 .54 2714. 08 -5314.97 5960302. 31 372807 .55 0.00 0.00 9300. 00 50 .21 295.46 6584 .43 6528 .53 2747. 11 -5384.35 5960336. 46 372738 .71 0.00 0.00 O~I~IN~L ~ ConocoPhillips CPAI Plan ~ Alaska, Inc. Report Company: ConocoPhillips Alaska ~nc. Date: 6/21/2007 Time: 14:13:16 Page: 4 Field: Colville River Unit Caord inate(NEj Refere nce: Well: Plan: CD4-306, True North Site: Alpine CD4 Vertical (T'VD) Reference: CD4-306wp07 55.9 WetL• Plan: CD4-306 Section (VS) Reference: Wef1 (0.40N,O.OOE,296.86Azi} Wellpath: Plan: CD4-306 Survey CaFrnlation Method: Minimum Curvature Db: Oracle Survey NID Incl Azim TVD Sys TVD NIS ElVV MapN MapE DLS TFO Comment ft deg deg ft ft ft ft- ff ft deg/100tt deg 9400.00 50.21 295.46 6648.42 6592.52 2780.15 -5453.74 5960370.60 372669.88 0.00 0.00 9500.00 50.21 295.46 6712.41 6656.51 2813.18 -5523.12 5960404.75 372601.05 0.00 0.00 9600.00 50.21 295.46 6776.40 6720.50 2846.21 -5592.50 5960438.90 372532.22 0.00 0.00 9677.50 50.21 295.46 6826.00 6770.10 2871.81 -5646.28 5960465.37 372478.87 0.00 0.00 Top HRZ 9700.00 50.21 295.46 6840.40 6784.50 2879.24 -5661.88 5960473.05 372463.38 0.00 0.00 9800.00 50.21 295.46 6904.39 6848.49 2912.27 -5731.27 5960507.20 372394.55 0.00 0.00 9900.00 50.21 295.46 6968.38 6912.48 2945.30 -5800.65 5960541.35 372325.72 0.00 0.00 9911.91 50.21 295.46 6976.00 6920.10 2949.23 -5808.91 5960545.42 372317.52 0.00 0.00 Base HRZ 9997.86 50.21 295.46 7031.00 6975.10 2977.62 -5868.55 5960574.77 372258.36 0.00 0.00 K-1 10000.00 50.21 295.46 7032.37 6976.47 2978.33 -5870.03 5960575.50 372256.89 0.00 0.00 Build; 3 DLS 10075.99 50.21 295.46 7081.00 7025.10 3003.43 -5922.76 5960601.45 372204.58 0.00 0.00 Kuparuk D 10100.00 50.21 295.46 7096.36 7040.46 3011.36 -5939.42 5960609.65 372188.05 0.00 0.00 10122.87 50.21 295.46 7111.00 7055.10 3018.92 -5955.29 5960617.46 372172.31 0.00 0.00 Kuparuk C 10130.40 50.21 295.46 7115.81 7059.91 3021.40 -5960.51 5960620.03 372167.13 0.00 0.00 10200.00 50.21 295.46 7160.36 7104.46 3044.40 -6008.80 5960643.80 372119.23 0.01 158.73 - 10280.53 50.21 295.46 7211.90 ~ 7156.00 3071.00 -6064.67 5960671.30 372063.80 0.00 180.00 7"x 8 3/4" Targets Map Map <--- Latitude ---> <__ Longifude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg Min 3ec Deg Min Sec Dip. Dir. ft ft ft ft ft CD4-306wp07 T1 7115.90 3021.45 -5960.60 5960620.08 372167.04 70 18 2.412 N 151 2 7.364 W -Plan hit target Annotation NID TVD ' ft ft 450.00 450.00 KOP; 2.5 DLS 10000.00 7032.37 Build; 3 DLS 2375.24 2153.16 Sail; 50° for 7755' 10280.53 7211.90 TD; 10280' MD, 7212 ND Casing Points MD TVD Diameter Hole Size Name ft ft ' in in 2760.98 2400.00 9.625 12.250 9 5/8" x 12 1/4" 10280.53 7211.90 7.000 8.750 7"x 8 3/4" Formafions NID TVD FormaHous Lithology Dip Angle Dip Direction ft ft deg deg 2785.98 2416.00 C-30 0.00 0.00 3332.93 2766.00 C-20 0.00 0.00 5012.83 3841.00 K-3 0.00 0.00 5341.00 4051.00 Basal K-3 0.00 0.00 5403.51 4091.00 K-2 0.00 0.00 5551,96 4186.00 Base K-2 0.00 0.00 8005,41 5756.00 Albian 97 0.00 0.00 8669.56 6181.00 Albian 96 (Nanuq) 0.00 0.00 9677.50 6826.00 Top HRZ 0.00 0.00 9911.91 6976.00 Base HRZ 0.00 0.00 9997.86 7031.00 K-1 0.00 0.00 10075.99 7081.00 Kuparuk D 0.00 0.00 10122.87 7111.00 Kuparuk C 0.00 0.00 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ConocoPhillips Alaska, Inc. Anticollision Report Company: ConOCOPhiliips Alaska inc. D~te: 6/21/2007 Time: 14:16:06 Page: 1 Field: Colville River Unit Reference Site: Alpine CD4 Co-ordinate(NE) Reference: Well: Plan: CD4-306, True North Reference Well: Plan: CD4-306 Vertical (TVD) Reference: CD4-3061nrp07 55.9 Reference Wellpath: Plan: CD4-306 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: CD4-306wp07 & NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 36.30 to 10280.53 ft Scan Method: Trav Cylinder No rth Maximum Radius: 1224.42 ft Error 5urface: Ellipse + Casing Casing Poiuts MD TVD Diameter Hole Size Name ft ft in in 2760.98 2400.00 9.625 12.250 9 5/8" x 12 1/4" 10280.53 7211.90 7.000 8.750 7"x 8 3/4" Plan: CD4-306wp07 Date Composed: 5/24/2007 Version: 4 Principal: Yes Tied-to: From Well Ref. Point Summary <-------------------- Of#set Wellpath -----------------> ' Reference Offset Ctr-Ctr No-Go AFiowable Site Well Wellpath NID MD Distance Area Deviation Warning ft ft ft ft ft Alpine CD2 CD2-37 CD2-37 V17 9899.80 1 6675.00 731.01 250.12 480.88 Pass: Major Risk Alpine CD2 CD2-60 CD2-60 V9 Out of range Alpine CD4 CD4-17 CD4-17 V13 299.79 300.00 221.10 6.25 214.85 Pass: Major Risk Alpine CD4 CD4-208 CD4-208 V7 650.37 650.00 41.08 11.03 30.05 Pass: Major Risk Alpine CD4 CD4-208 CD4-208P61 V6 650.37 650.00 41.08 10.92 30.16 Pass: Major Risk Alpine CD4 CD4-209 CD4-209 V4 624.04 625.00 66.55 11.31 55.24 Pass: Major Risk Alpine CD4 CD4-210 CD4-210 V3 693.78 675.00 79.73 11.79 67.94 Pass: Major Risk Alpine CD4 CD4-211 CD4-211 V2 977.52 975.00 88.95 18.50 70.45 Pass: Major Risk Alpine CD4 CD4-213 CD4-213 V4 424.14 425.00 139.30 8.23 131.07 Pass: Major Risk Alpine CD4 CD4-214 CD4-214 V3 298.97 300.00 161.29 6.08 155.21 Pass: Major Risk Alpine CD4 CD4-215 CD4-215 V4 349.33 350.00 183.33 7.38 175.95 Pass: Major Risk Alpine CD4 CD4-318 CD4-318 V6 350.98 350.00 241.93 7.40 234.53 Pass: Major Risk Alpine CD4 CD4-318 CD4-318A V5 349.94 350.00 241.91 7.38 234.53 Pass: Major Risk Alpine CD4 CD4-318 CD4-318PB1 V3 350.98 350.00 241.93 7.40 234.53 Pass: Major Risk Alpine CD4 CD4-320 CD4-320 V7 1822.25 9800.00 46.28 29.14 17.14 Pass: Major Risk Alpine CD4 CD4-320 CD4-320PB1 V4 1822.25 1800.00 46.28 29.14 17.14 Pass: Major Risk Alpine CD4 Nanuq 5 Nanuq 5 V1 627.71 625.00 112.53 10.79 101.75 Pass: Major Risk Alpine CD4 Nanuq 5 Plan: CD4-212 VO Plan: 627.71 625.00 112.53 10.77 101.76 Pass: Major Risk Alpine CD4 Plan: CD4-16 Plan: CD4-16 V1 Plan: 375.09 375.00 200.47 7.91 192.56 Pass: Major Risk Alpine CD4 Plan: CD4-203 Plan: CD4-203 V1 Plan: 450.79 450.00 60.62 9.32 51.30 Pass: Major Risk Alpine CD4 Plan: CD4-204 Plan: CD4-204 V1 Plan: 350.79 350.00 40.67 7.33 33.34 Pass: Major Risk Alpine CD4 Plan: CD4-205 Plan: CD4-205 V1 Plan: 600.46 600.00 21.17 12.75 8.42 Pass: Major Risk Alpine CD4 Plan: CD4-207 Plan: CD4-207 V3 Plan: 674.47 675.00 21.16 14.35 6.81 Pass: Major Risk Alpine CD4 Plan: CD4-207 Prelim: CD4-07 VO Plan 624.73 625.00 20.37 13.27 7.10 Pass: Major Risk Alpine CD4 Plan: CD4-223 Plan: CD4-223 VO Plan: 960.81 950.00 321.97 20.01 301.97 Pass: Major Risk Alpine CD4 Slot 1 open for futu Slot 1 open for future 36.90 0.00 100.14 No Offset Stations Alpine CD4 TDed: CD4-302 Plan: CD4-302 V1 Plan: 450.00 450.00 80.49 9.48 71.01 Pass: Major Risk Alpine CD4 TDed: CD4-302 TDed: CD4-302 V8 374.99 375.00 82.40 7.64 74.76 Pass: Major Risk Site: Alpine C D2 Well: CD2-37 Rule Assigned: Major Risk Wellpath: CD2-37 V17 Inter-Site Error: 0.00 ft Reference Offset Semi-Major A.xis Ctr-Ctr No-Go; Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casiug/H~istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft r ft ft 10272.65 7206.85 16100.00 7369.98 47.08 42.21 40.02 104.56 861.98 267.90 594.08 Pass 10256.49 7196.51 16125.00 7370.24 46.99 42.32 41.14 105.68 852.84 268.25 584.59 Pass 10240.28 7186.14 16150.00 7370.44 46.91 42.42 42.28 106.82 844.07 268.52 575.56 Pass 10224.05 7175.75 16175.00 7370.59 46.82 42.52 43.44 107.98 835.62 268.68 566.94 Pass 10207.79 7165.35 16200.00 7370.67 46.73 42.62 44.62 109.16 827.43 268.77 558.67 Pass 10191.53 7154.94 16225.00 7370.69 46.65 42.72 45.83 110.37 819.53 268.79 550.74 Pass 1017525 7144.52 16250.00 7370.65 46.58 42.82 47.05 111.59 811.92 268.75 543.17 Pass 10158.94 7134.08 16275.00 7370.55 46.52 42.91 48.29 112.83 804.66 268.61 536.05 Pass 10142.57 7123.61 16300.00 7370.38 46.45 43.01 49.55 114.09 797.78 268.37 529.42 Pass 10126.11 7113.07 16325.00 7370.15 46.37 43.11 50.82 115.36 791.30 268.01 523.29 Pass ~GRAM QR~GIf~AL • ~ ConocoPhillips Alaska, Inc. Anticollision Report Campany: GonocoPhillips Alaska InC. Date: 6/21/2007 Time: 14:16 :06 Page: 33 Field: Colville Rive r Unit Reference Si4e: Alpine'GD4 Co-ordinate(NE) Refe rence: Well: Pia n: CD4-3~, True North Reference WeIL• Plan: G D4-3E36 Vertital (TVD) Reference: CD4-306wp07 55.9 Reference Wellpath: Plan; C D4-306 Db; Oracle Site: Alpine CD4 We1L• CD4-320 Rule Assigned: Major Risk Wellpath: CD4-320 V7 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr NaGo Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/H~i§fance Area Deviation ' Warning ft ft ft ft ft ft deg deg in ft ft' R 1574. 18 1532. 36 1525. 00 1474. 90 2.43 1.74 280. 11 331 .76 9.625 143.41 26 .13 117.29 Pass 1597. 89 1553. 34 1550. 00 1498. 05 2.47 1.74 281. 82 334 .10 9.625 132.34 26 .35 105.99 Pass 1621. 47 1574. 07 1575. 00 1521. 26 2.52 1.75 283. 77 336 .66 9.625 121.37 26 .56 94.81 Pass 1644. 91 1594. 56 1600. 00 1544. 54 2.56 1.75 286. 05 339 .51 9.625 110.53 26 .76 83.77 Pass 1668. 14 1614. 73 1625. 00 1567. 81 2.61 1.76 288. 83 342 .84 9.625 99.76 26 .92 72.84 Pass 1691. 07 1634. 51 1650. 00 1591. 04 2.66 1.76 292. 38 346 .92 9.625 89.09 27 .05 62.04 Pass 1713. 70 1653. 91 1675. 00 1614. 24 2.71 1.77 297. 01 352 .05 9.625 78.67 27 .15 51.53 Pass 1736. 04 1672. 94 1700. 00 1637. 39 2.76 1.78 303. 17 358 .69 9.625 68.77 27 .22 41.55 Pass 1758. 07 1691. 57 1725. 00 1660. 49 2.82 1.80 311. 50 7 .46 9.625 59.78 27 .35 32.43 Pass 1779. 78 1709. 81 1750 .00 1683. 56 2.87 1.82 322. 73 19 .12 9.625 52.37 27 .60 24.78 Pass 1801. 18 1727. 66 1775. 00 1706. 58 2.92 1.84 337. 22 34 .03 9.625 47.53 28 .15 19.38 Pass 1822. 25 1745. 11 1800. 00 1729. 57 2.98 1.86 354. 02 51 .21 9.625 46.28 29 .14 17.14 Pass 1842. 95 1762. 14 1825. 00 1752. 61 3.04 1.88 10. 75 68 .32 9.625 48.92 30 .28 18.65 Pass 1863. 26 1778. 73 1850. 00 1775. 71 3.10 1.90 25. 19 83 .12 9.625 55.12 31 .24 23.88 Pass 1883. 17 1794. 88 1875. 00 1798. 88 3.16 1.92 36. 57 94 .83 9.625 64.08 31 .93 32.16 Pass 1902. 69 1810. 60 1900. 00 1822. 09 3.22 1.94 45. 19 103 .78 9.625 75.04 32 .40 42.64 Pass 1921. 91 1825. 97 1925. 00 1845. 29 3.28 1.96 51. 61 110 .51 9.625 87.42 32 .76 54.66 Pass 1940. 82 1840. 98 1950. 00 1868. 49 3.34 1.98 56. 46 115 .65 9.625 100.79 33 .05 67.74 Pass 1959. 43 1855. 66 1975. 00 1891. 69 3.41 2.00 60. 19 119 .68 9.625 114.89 33 .31 81.58 Pass 1977. 77 1870. 01 2000. 00 1914. 85 3.47 2.01 63. 11 122 .87 9.625 129.55 33 .56 95.99 Pass 1995. 88 1884. 07 2025. 00 1937. 96 3.53 2.03 65. 39 125 .41 9.625 144.65 33 .81 110.84 Pass 2013. 75 1897. 86 2050 .00 1961. 00 3.59 2.05 67. 18 127 .46 9.625 160.10 34 .07 126.03 Pass 2031. 40 1911. 37 2075 .00 1983. 97 3.66 2.06 68. 62 129 .14 9.625 175.83 34 .33 141.50 Pass 2048. 81 1924. 60 2100 .00 2006. 89 3.72 2.08 69. 78 130 .55 9.625 191.80 34 .58 157.22 Pass 2066. 00 1937. 56 2125. 00 2029. 77 3.79 2.09 70. 75 131 .75 9.625 207.99 34 .83 173.16 Pass 2082. 95 1950. 25 2150. 00 2052. 60 3.85 2.10 71. 56 132 .78 9.625 224.36 35 .08 189.28 Pass 2099. 68 1962. 68 2175. 00 2075. 39 3.91 2.11 72. 24 133 .68 9.625 240.92 35 .33 205.58 Pass 2116. 14 1974. 82 2200. 00 2098. 15 3.98 2.13 72. 83 134 .48 9.625 257.68 35 .61 222.06 Pass 2132. 31 1986. 66 2225. 00 2120. 88 4.04 2.15 73. 35 135 .20 9.625 274.66 35 .88 238.78 Pass 2148. 20 1998. 19 2250. 00 2143. 58 4.11 2.17 73. 80 135 .86 9.625 291.87 36 .15 255.72 Pass 2163. 81 2009. 44 2275. 00 2166. 25 4.17 2.19 74. 21 136 .45 9.625 309.27 36 .40 272.87 Pass 2179. 21 2020. 46 2300. 00 2188. 93 4.24 2.20 74. 57 137 .00 9.625 326.79 36 .64 290.14 Pass 2194. 42 2031. 27 2325. 00 2211. 61 4.30 2.20 74. 91 137 .51 9.625 344.40 36 .88 307.52 Pass 2209. 45 2041. 85 2350. 00 2234. 31 4.36 2.21 75. 22 137 .99 9.625 362.10 37 .11 324.98 Pass 2224. 28 2052. 23 2375. 00 2257. 00 4.43 2.22 75. 50 138 .45 9.625 379.90 37 .35 342.55 Pass 2238. 88 2062. 36 2400. 00 2279. 68 4.49 2.23 75. 75 138 .86 9.625 397.84 37 .58 360.26 Pass 2253. 25 2072. 26 2425. 00 2302. 33 4.55 2.24 75. 98 139 .25 9.625 415.94 37 .81 378.13 Pass 2267. 39 2081. 92 2450. 00 2324. 96 4.62 2.25 76. 19 139 .61 9.625 434.18 38 .04 396.15 Pass 2281. 30 2091. 36 2475. 00 2347. 56 4.68 2.27 76. 37 139 .95 7.000 452.57 38 .17 414.40 Pass 2294. 99 2100. 57 2500. 00 2370. 15 4.74 2.29 76. 55 140 .27 7.000 471.10 38 .43 432.67 Pass 2308. 45 2109. 56 2525. 00 2392. 72 4.80 2.31 76. 70 140 .57 7.000 489.76 38 .68 451:08 Pass 2321. 70 2118. 35 2550. 00 2415. 28 4.86 2.33 76. 85 140 .85 7.000 508.54 38 .93 469.62 Pass 2334. 75 2126. 94 2575. 00 2437. 82 4.92 2.35 76. 98 141 .12 7.000 527.45 39 .18 488.27 Pass 2347. 60 2135. 33 2600. 00 2460. 35 4.98 2.38 77. 11 141 .37 7.000 546.46 39 .42 507.04 Pass 2360. 26 2143. 53 2625. 00 2482. 88 5.04 2.38 77. 22 141 .62 7.000 565.58 39 .63 525.95 Pass 2372. 73 2151. 55 2650. 00 2505. 43 5.10 2.39 77. 34 141 .86 7.000 584.79 39 .82 544.97 Pass 2387. 85 2161. 23 2675. 00 2527. 99 5.17 2.40 77. 49 142 .03 7.000 604.08 40 .10 563.98 Pass 2403. 67 2171. 35 2700 .00 2550. 57 5.25 2.42 77. 64 142 .18 7.000 623.37 40 .39 582.98 Pass 2419. 50 2181. 48 2725 .00 2573. 20 5.32 2.42 77. 79 142 .33 7.000 642.65 40 .66 601.99 Pass 2435. 35 2191. 62 2750 .00 2595. 88 5.40 2.43 77. 94 142 .48 7.000 661.91 40 .93 620.98 Pass ~ii~~'~~~ sooo i I i _ i i I i i I I I 6000 CD 2-60 CD2-60P B 1 N anu 5 Plan: CD4-212 4000 I , ~ _ ' , ,--, ,~ CD4-306w 07 ', o CD2-37 CD2-37 I N ~. 2000 ' + , ' 2-60 CD2-60 ' , ° ,-. , CD4-319 CD4-319 , , , CD4-3 20 CD4-320P B 1 ~ 0 Nanu 3 an u 3, v' CD4-318A , TDed: CD4-302 TDed: CD4-302 -2000 , _I _ , ' , ' CD4-321 CD4-321 , , , , -4000 , ' - ;D4-318 CD4-318PB 1 , I , I ' -6000 ' CD4-318 C D4-318A CD4-3 Nanu 5 anu 5 rnn~ ~~n ~r I^ ~~~~` -12000 -10 000 -8000 -60 00 -40 00 -2000 0 20 00 4000 West(-)/East( +) [2000ft/in] ~ Md W! ~ s~. ie~aw~ Commenis: O ~ V ~ z ~ ~ t OQ N ~ O ~ > ~ ~ E ~ T ConocoPhiOip~ Na~ka Inc. CoMle Itlvn UnX CD~-d06wp0) NN/R IL l]!0)).M it Y: 595)502l1 11 Gitl Cancllen: MaOneXC GcPnaNen: dp: ~WM9P~ Orlglnal VS Plane: Vlew VS Plone: POOL: CD4-306wp07 Plan: 7020' to 7065' TVDss CD2-37: 7020' to 7065' TVDss CD2-60: 7020' to 7065' TVDss CD417: 7020' to 7065' TVDss CD4319: 7020' to 7103.36' TVDss -0.91 ° lebHe: XN/R 33.)) ° RfENO: XN/A ° R%Ne: XN/1 100 11 Syd~m (fVD) MNnnc~: Mean seo ~evd 296.86 • r<..~~xw: aa~:coa-3on Z9G.E6 ° MK~ M~IpM: 55.9o II u~n srmm: .,~~e i vPs S~cNOn(VS~IN~nn«: Plan View ~ ~ - ~ ~ - _ ~ - - - ~~ m n~ m m m m m~ c~ .~ n m ~ 59761 - __ _._ _. _ - _ _ _~_ ~_ __ . _ _ _ _ ____. , ~ ,.___ . .. - __ .. _ ' __ __ __ __ __ '_ - _.'_ 59J51 597 . . 4i 59731 I 5972~ , - 5 7 -? 11 9 sv~a 5969i 59 8i 6 - 5967i 59 i - ~ ~ -- 66 5965i .-_ i . . _._ . _ i 59 , ~ 64 59 3 6 ~ 5962~ 5 961~ 5 ~ 960 5959~ 595& 5957~ 5 5 9 6 5959 595M 5953~ 5952~ 5951 i 595P 'o + t z° 00 00 W W W 00 00 00 . W W W W W ~ 90 W W W 00 00 00 00 ~ W W ~ W W • 4000 5000 6000 7000 8000 °o °o °o ° °o S S °o °o S S S g $ $ S °o g S S °o °o °o °o °o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 (7 N ~ (V (7 V h ~O I~ OD P O (V M V h ~O ~0 P O ~ ~ ~ Vertical Sedion along "View VS Plane~ ^ ^ ^ ~ ~ ^ ^ `~ ~ Combo Preview Page 1 of 1(CD4-306wp07 Toolbox.xls) 6/21/2007 4:39 PM Closest in POOL ClosestApproac h: Reference Well: CD4-306wp07 Plan Offset Well: CD4 -31S Coords. - Coords. - ASP ASP 3-D ctr-ctr :arizc?taI S~3I~s-> Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS Distance. ',~,r~::4 "''K Depth Angle TRUEAzi. ND E{+)/W(-) (296.86°) Comments Depth Angle TRUEAzi. TVD E(+)/W(-) (296.86°) Comments POOL Min Distance POOL Min Distance (2164.93 ft) in POOL (2164.93 ft) in POOL (7020 - 7065 ND. ~ (7020 - 7065 TVDss) to CD4306wp07 P to CD4-319 (7020 - (7020 - 7103.36 2164.93 -296',.~2 10075 50.21 295.4 7024.857 5960595 372201.6 6639.951 7103.36 TVDss) 18683 91.27 354.3 7076.177 5958437 372366.8 5487.682 11/Dss) Closest Approac h: Reference Well: CD4-306wp07 Plan Offset Well: Nanuq 3 Coords. - Coords. - ASP ASP tr-ctr ; r r.~~_;7tal Subs<~, : Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS nce. ; ~is. ~ ~~:~ ~iffe~<^ce Depth Angle TRUE Azi. TVD E+)/W(-) (296.86°) Comments Depth Angle TRUE Azi. ND E(+)/W(-) (296.86°) Comments POOL Min Distance POOL Min Distance (3410.73 ft) in POOL (3410.73 ft) in POOL (7020 - 7065 NDss) (7020 - 7065 NDss) to Nanuq 3(7020 - to CD4-306wp07 Plan 10.73 34 ."' :' 42 ~; :? 1 C'; 10075 50.21 295.4 7024.857 5960595 372201.6 6639.951 7065 NDss) 8539 22.2 271.56 7066.87 5957352 373256.1 3879.28 (7020 - 7065 NDss) Closest Approac h: Reference Well: CD4-306wp07 Plan Offset Well: CD2-37 Coords. - Coords. - ASP ASP 3-D ctr-etr ?~c~zo <~? ~. Meas. Incl. Subsea N(+~/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS Distance. ;. +anc; a~':c:, Depth Angle TRUE Azi. ND E(+)/W(-) (296.86°) Comments Depth Angle TRUE Azi. ND E(+)/W(-) (296.86°) Comments POOL Min Distance POOL Min Distance (3418.01 ft) in POOL (3418.01 ft) in POOL (7020 - 7065 NDss) (7020 - 7065 NDss) to CD2-37 (7020 - to CD4-306wp07 Plan 3418.01 >4 `; 9.76 +64 10136 50.21 295.4 7063.895 5960616 372159.6 6686.808 7065 NDss) 13215 65.57 173.63 7073.66 5963958 371443.4 -4643.12 (7020 - 7065 NDss) CD4-306wp07 POOLSummary.xis 6/21/2007 4:43 PM . • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanicai Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim Regg@admin.state.ak,us; Tom_Maunder@admin.state.ak.us OPERATOR: ConocoPhitlips FIELD 1 UNIT / PAD: Alpine / Nanuq / CD4 DATE: 07/25/07 OPERATOR REP: Mickey / Woods AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well CD4-306 Type Inj. W TVD 6,897' Tubing 1,500 1,750 1,750 1,750 Intervai I P.T.D. 207-094 Type test P Test psi 3500 Casing 3,557 3,508 3,478 P/F P Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type tnj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA Well Type Inj. TVD Tubing Intervat P.T.D. Type test Test psi Casing P/F Notes: OA TYPEINJCodes D = Drilling Waist G = Gas I = Industrial Waistewater N = Not Injecting W = Water TYPE 7EST Codes M = Annulus Monitoring P = Siandard Pressure Test R= Internal Radioadive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year CyGe V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT RepoR Form BFL 9/1/OS MIT CD4-306 Message Davies, Stephen F (DOA) ~ Page 1 of 1 • From: Galiunas, Elizabeth C [Elizabeth.C.Galiunas~conocophillips.com] Sent: Thursday, July 12, 2007 11:Q6 AM To: Davies, Stephen F(DOA); Maunder, Thomas E(DOA) Cc: Wiess, JORDAN F Su6ject: CD4-306 Attachments: CD4-306_GS~G_Jun07.pdf; Visio-CD4-306 Injector Schemafic 5-5-07.pdf Steve and Tom, Here is the attached map of the Kuparuk C sand on CD4. .~iti ~`nct(ttf~ is the updated complefion schematic. t have coRect the depth of the Kuparuk C sand. The predicted EMW for the Kuparuk C is 7.2 ppg or virgin pressure of 8.7 ppg. Let me know any other questions you may have. The rig should be moving to CD4-306 on Friday night and spudding this Saturday. Liz Galiunas Drilling Engineer Alpine Drilling Team ~ce: (907~265-6247 Cell: (9Q7)-441-4871 7/12/2007 • ~ ~ • ~'R~1~IS1~.~~'~'A~. L,E~'Z'Et~ ~'HECK.I.IST ~EC,~. ~v:e.titE [ ~i~ [~ ~ ~ - .30~ P'I'D# ZI~ 7 - ~~ Cf Devetopment ~ Serv~ce Exploratory• Stratigraphic Test ~Yon-Conventiona! WeU Circle 4ppropriate Letter J Paragraphs to be Includ~d ia TransmitEal Letter ~ CHECK w~r ; aPPLtES ,=-- ~ ; HUU-U ~I5 (OPTIONS) MliLTi LATERA ; (IF (ast rWO a~~tu i AP[ number ; between 60-69) ~ P20T f{OLE I i[n accordance with 20 A.4C 25.OU5 (~, at! record.;, data and (o~s ; acquired for the pilot hote must b i e ctear(y diffecentiated in both ; wetl name ( ~ PI~ and API c~urttbe~ ~~~" ' ~ ~ -_, from records, data artd logs , acquired for weti ~ SPACING ; EXCEPTION The permit is approved subject to futl compliacice witlt 2p AqC ' ~ 25.0». Approvat to pecfoca:te aad aroduce ! iaject is contingent ~ I upon issua f i nce o ~ a conservatioa order approving a spacing j l exception. ' assames the ' ~[iabiiity of any protest to the spacing exception that may occur. j ; DRY DRCH I SA!~IPLE ~ ~`alI dn' ditch sample sets submitted to the-Eommission must be in ~ ~ ; no greater than 30 sampte intervals from beiow the pecrrzafrost or ; + f ~ rom where samples are first caught and I0' samp(e iRtervals j ! through target zones. ~ i i~!i Converttional ~ j Please note the fotlowing specia! condition oP thi; ~ production or production tesiing of coat bed methane is not a! owed ~ ; ~ ~ for (riame of well) unti! after (CornAacev Iv_ame} has designed and ! ~~mplemented a water wel! testing program to provide baseline data ; on water quality and clt ~ quan y, Com an Name must contact the ! Commission to obtain advance approval of such water well t i ! - est ng ~ pragrarrt. , T'EXT FOR APPROVqL LETTE(t L ~ The permit i; Por a new well6ore segment of exi~ting ~ wet! in ~ PeRnit Yo. - are , APt No. ~0- _ _ ~ Production shoccid continue to be reported as a functioa of the ,~ ~ original API number stated above. 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Well f-iistory File APPE~IDIX Information of detailed nature that is not pa~ticula~ly germane to the Weli Permitting Process but is part of the history file. To improve the readability of the Well History file and to sim.plify finding information, information of this nature is accumulaled at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. , ~ cd4-306.tapx sperry-sun ~rillin9 services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Sep 28 09:56:54 2007 Reel Header Service name .............LISTPE ~ate . ...................07/09/28 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing ~ ~ibrary. scientific Technical services Tape Header Service name .............LISTPE Date . ...................07/09/28 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 MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: scientific Technical services CD4-306 501032055000 ConocoPhillips Alaska Inc. Sperry Drilling Services 28-SEP-07 MWD RUN 2 w-0005158770 D. RICHARDSO D. LUTRICK # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD vz. c 20~- -~ ~ ~I 24 11N 4E 2907 167 56.23 19.60 Page 1 ~ ~ sy~ ~- 15T STRING 2ND STRING 3RD STRING PRODUCTION # REMARKS: • OPEN HOLE BIT SIZE (IN) 8.750 STRING cd4-306.tapx CASING DRILLERS SIZE (IN) DEPTH (FT) 9.625 2727.0 • 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. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), GEOPILOT ROTARY-STEERABLE BHA (GP), AND ACOUSTIC CALIPER (ACAL). AT-BIT GAMMA (ABG) DATA FROM 10311'MD TO 10341.5' MD WERE MERGED WITH DGR MWD DATA. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), COMPENSATED THERMAL 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 1,2 REPRESENT WELL CD4-306 WITH API#: 50-103-20550-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10346'MD/7253'ND. 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. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT Page 2 i i cd4-306.tapx BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.75~~ BIT) MUD WEIGHT: 9.65 - 9.85 PPG MUD SALINITY: 200 - 650 PPM CHLORIDES FORMATION WATER SALINITY: 23000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/28 Maximum Physical rtecord..65535 File Type. ............LO Previous File Name.......ST5LI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD ~epth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2702.5 10341.5 FET 2710.0 10303.5 NPHI 2710.0 10258.0 NCNT 2710.0 10258.0 PEF 2710.0 10271.0 RPS 2710.0 10303.5 RHOB 2710.0 10271.0 RPD 2710.0 10303.5 RPx 2710.0 10303.5 DRHO 2710.0 10271.0 FCNT 2710.0 10258.0 RPM 2710.0 10303.5 ROP 2737.5 10346.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 2 2702.5 10346.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 ~ogging ~irection .................~own Page 3 . • cd4-306.tapx optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. . .. .. ..... ~atum specification slock sub-type...0 Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2702.5 10346 6524.25 15288 2702.5 10346 FCNT MWD CNTS 588.63 2725.65 1130.91 15097 2710 10258 NCNT MWD CNTS 113508 178740 142579 15097 2710 10258 RHOB MwD G/CM 0.903 3.152 2.40862 15123 2710 10271 DRHO MWD G/CM -3.137 0.284 0.0517419 15123 2710 10271 RPD MwD OHMM 0.39 2000 10.0055 15188 2710 10303.5 RPM MWD OHMM 0.41 2000 6.0855 15188 2710 10303.5 RPS MwD OHMM 0.32 2000 6.00274 15188 2710 10303.5 RPx Mw~ OHMM 0.66 1879.2 5.77876 15188 2710 10303.5 FET MwD HOUR 0.14 49.92 0.576244 15188 2710 10303.5 GR MwD API 49.07 439.72 112.946 15279 2702.5 10341.5 PEF MwD BARN 1.73 13.9 3.03452 15123 2710 10271 ROP MwD FT/H 3.49 380.98 181.345 15218 2737.5 10346 NPHI Mw~ Pu-5 15.66 60.33 33.6035 15097 2710 10258 First Reading For Entire File..........2702.5 ~ast Reading For Entire File...........10346 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/28 Maximum Physical Record..65535 File Ty e ................LO Next Fi~e Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Page 4 i i cd4-306.tapx Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/28 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: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2702.5 10341.5 RPM 2710.0 10303.5 PEF 2710.0 10271.0 FET 2710.0 10303.5 RPx 2710.0 10303.5 NPHI 2710.0 10258.0 RPS 2710.0 10303.5 RPD 2710.0 10303.5 FCNT 2710.0 10258.0 DRHO 2710.0 10271.0 RHOB 2710.0 10271.0 NCNT 2710.0 10258.0 ROP 2737.5 10346.0 $ # LOG HEADER DATA DATE LOGGED: 21-JUL-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10346.0 TOP LOG INTERVAL (FT): 2737.0 BOTTOM LOG INTERVAL (FT): 10346.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 47.5 MAXIMUM ANGLE: 53.8 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 076571 EWR4 ELECTROMAG. RESIS. 4 157645 CTN COMP THERMAL NEUTRON 174114 ALD Azimuthal Litho-Dens 224807 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): $.750 DRILLER'S CASING DEPTH (FT): 2727.0 # BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (5): 37.0 MUD PH: 10.0 Page 5 ~ • cd4-306.tapx MUD CHLORIDES (PPM): 400 FLUID LOSS (C3): $.2 RESISTIVITY (OHMM) AT TEMP ERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 6.000 70.0 MUD AT MAX CIRCULATING TERMPERATURE : 3.060 143.6 MUD FILTRATE AT MT: 8.000 70.0 MUD CAKE AT MT: 3.500 70.0 # 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 Log~ing Direction ............ .....Down opt~cal log depth units...... .....Feet ~ata rteference Point ......... .....undefined Frame Spacing....... ....... .....60 .lIN Max frames per record ........ .....undefined ,4bsent value ................. .....-999 Depth Units. . .. .. ..... ~atum specification Block sub -type...0 Name service order units size N sam ttep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD020 CNTS 4 1 68 4 2 NCNT MWD020 CNTS 4 1 68 8 3 RHOB MWD020 G/CM 4 1 68 12 4 DRHO MWD020 G/CM 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 RPM MwD020 OHMM 4 1 68 24 7 RPS MWD020 OHMM 4 1 68 28 8 RPX MWD020 OHMM 4 1 68 32 9 FET MWD020 HOUR 4 1 68 36 10 GR MWD020 API 4 1 68 40 11 PEF MWD020 BARN 4 1 68 44 12 ROP MWD020 FT/H 4 1 68 48 13 NPHI MWD020 PU-5 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2702.5 10346 6524.25 15288 2702.5 10346 FCNT MWD020 CNTS 588.63 2725.65 1130.91 15097 2710 10258 NCNT MWD020 CNTS 113508 178740 142579 15097 2710 10258 RHOS MWD020 G/tM 0.903 3.152 2.40862 15123 2710 10271 DRHO MWD020 G/CM -3.137 0.284 0 .0517419 15123 2710 10271 RPD MWD020 OHMM 0.39 2000 10.0055 15188 2710 10303.5 RPM MWD020 OHMM 0.41 2000 6.0855 15188 2710 10303.5 RPS MWD020 OHMM 0.32 2000 6.00274 15188 2710 10303.5 RPx MWD020 OHMM 0.66 1879.2 5.77876 15188 2710 10303.5 FET MwD020 HOUR 0.14 49.92 0.576244 15188 2710 10303.5 GR MWD020 API 49.07 439.72 112.946 15279 2702.5 10341.5 PEF MwD020 BARN 1.73 13.9 3.03452 15123 2710 10271 Page 6 . ~ ~ cd4-306.tapx ROP Mw~020 FT/H 3.49 380.98 181.345 15218 2737.5 10346 NPHI Mw~020 Pu-S 15.66 60.33 33.6035 15097 2710 10258 First Reading For Entire File..........2702.5 ~ast Reading For Entire F~le...........10346 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/28 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 PhySiCdl EOF Tape Trailer Service name .............LISTPE ~ate . ...................07/09/28 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE ~ate . ...................07/09/28 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comment5 .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File scientific Technical services scientific Technical services Page 7
