The URL can be used to link to this page

Home My WebLink About200-215 ! Ima~roject Well History File Coverage ~ XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) D Co~or items: [] Diskettes, No. D Maps: L-J Grayscale items: [] Other, No/Type D Other items scannable by large scanner [] Poor Quality Originals: [] Other: OVERSIZED (Non-Scannable) NOTES: [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~WINDY _ Sca~ining Preparation ~ x 30 = '~2. O BY: BEVERLY ROBIN VINCENT SHERY~~)WINDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~.'__.. YES NO B'f': BEVERL~NCENT SHERYL MARIA WINDY bATE~/-/~-~%/'~""-- Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREP~RE FOUND: _.,/') YES ........ NO (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN I~AL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /si General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned wpd . . Conoc~Phillips Alaska ., .:..J P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 scANNED APR 1 () 2007 ~ÐO- 'J..I5 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 31,2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 318/2007 CD1-40 199-044 4" na 4" na 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-106 8" na 8" na 3.7 2/16/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 16.9 2/16/2007 e ~,fÆ FRANK H. MURKOWSKI, GOVERNOR AI¡ASIiA. OIL AlWD GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jack Walker Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 (;;J{.:.... ". ~:. \!\,;'.Iít.~. \'F!U \:l~I~~"\~ ,,~~~ r. ~. () cJ Re: Colville River Field, Nanuq-Nanuq Oil Pool, CDl-229 Sundry Number: 306-115 ~1Ç ~Oo-r Dear Mr. Walker: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has b~en requested. Sincerely, DATED thi¿(day of March, 2006 Encl. tNJ/iý&¡, /)~ '?/3~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION e ,t., I~, RECEIVED MAR 2 4 2006 APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Alaska Oil & Gas Cons. Comrnissio. Anchorage 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKBO' 200-215 6. API Number: 11. Total depth MD (ft): 16118' Casing CONDUCTOR SURF CASING PROD CASING LINER Total Depth TVD (ft): 6165' Length 9. Well Name and Number: CD1-229 10. Field/Pool(s): ((>. Nanuq - ~ ~-..) . f;:f.)::?)v'\~ .~ \ PRESENT WELL CONDITION SUMMARY TVD Plugs (measured): 8. Property Designation: 114' 3260' 11282' 4848' 16" 7" 114' 3260' 11282' 15958' 9-5/8" 3-1/2" Perforation Slotted liner Packers and SSSV Type: pkr= BAKER ZXP PACKER W/6' TIEBACK EXTENSION SSSV= SSSV Signature Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ~ Location Clearance 0 Other: \V\ \\ ~...,) So\- bt. C:.c~~~~' _.~ <::::;.~,~'\ ~ \~\~<-.\;\ ~¡\ APPROVED BY 3...3/ -of; COMMISSIONER . THE COMMISSION Date: R8DMS BFL APR '\'5 2006 Æ> " a{.t>(. ~ J#,6submit in Duplicate Subsequent Form Required: Approved by: e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 CD1-229 Summary Proposal March 23, 2006 A seawater injection test is proposed for CD1-229 to help optimize the Nanuq development drilling program. Core testing indicated water-based drilling fluid may yield inadequate injectivity, and mineral oil-based drilling fluid was used for the first Nanuq injector. A field test is proposed to determine injectivity of the Nanuq CD1-229 well with a production hole that was drilled with water-based drilling fluid. Results of the seawater injection test will be used / to re-evaluate the use of oil-based drilling fluid in the Nanuq injectors. Form 10-403 Revised 7/2005 Submit in Duplicate e e MECHANICAL INTEGRITY REPORT' " .)007;>t ç OPER & FIELD C?y À'\.:- C:~0 N~"..;)\,,-~"~'v. w-ž:LL NUMBER c.. \J \- dd ~ ::?UD DÞ.!:::: ?~IG 2EL'::;'..5:~: C¿si~6: "1\\ _~~e~: s~ Shoe: _;]o:,-::;g: ')(l) Packe:!:' 1\\GOMD :-:01 e S':"z e <6\ J :;;>. anå TD: \<.o\\<6.MD. Shoe: \ \"d\S) till ~r'/ t,.LL DATi-.. TVD¡ ?.BTD: MD TVD TVD¡ DV: ~Þ\ MD ·TVTI Tift j :CP: HD ::~rD MD T\I1) j Set ê. C \ \ \ ð \ Per £ .5 \ C} % ::> to S'<1 S- ~ '. ~\Q ~<Lð·\·\~.r :-::E:C?.Þ...NIG·-I, INTEGRITY - PART II .;;¡; iY/V üt-~ (i) ) éD'.;> .j, '1, ee~ J'£lfeHÞ~~Ief...l.. INTEGRITY - PAl<.T 12 3'\~\'\~ /' cJ t Cemenc Volumes:' Þ..mt. Line.r \...J.b.." esg \!ðo <:}~ 3 ;; ~ CüiC -"01 Co cove:!:' perfs \ 5 ~\s <;'0.3.Ç~"Ò.<i:..II'.\.'~ C'..t)\,.)é ,r Z;1. ~ 5b()\ a·\;. """"\o-( Q: 'SO(o 'io.. S j % " if, Theoretical TOC ~ <:. -SOle '{.. ':, \1Jc. ';>¡, \C)OOO / ¿ r-Ó] ~ 2 .Jf:r fJ (0 9 ~ Cement Bond Log (Yes or No) ~O ; ln ADGCC File ..:-t.'.l1 ~ \..-1 .J ~ (1 ~ t~i 0 i t ~:::;; & Proåuc.tion Log: Iype J{jE]i jQ ,. Annulus Press Test: ~p ; 15 min ; 30 min CO"'li¡en ts ; ~ N ~ -s:.Þ. \€.<.~~ ~ð~\<N:. ro'"'f ~~c:., :::.. ~ ~ DV eBL !::valuation, zone ¿Dove perfs c..c.c:..\.'("-,- ~~t\¿c.k\Lr \ ~'c..\ <"'\~/'tt..'ò~ :)0 \) \-(è. ~ ~~.,.. .ç -..)\ \ c..\. ,c..0 \u-\., D"",- ~ '-\-c<...,\-6\ \ ~\~>'ð~ c~ù"- ~{~~<t., :~~ € ¡Evaluation CONÇLUSIONS: ? ar t: t 1 : ? ar:: : 2 : \-'\ I:" \ '> "Q\9\)a.\>\(c: . !iÌ-~ y~,~ RE: CDl-229 e e Tom, A bond log was not run on CDl-229 because it was designed as a production test well. The assessment of the CDl-229 7" production casing cementing operation is good overall. Calculated top of cement was 10252' md, the 7" casing shoe is at 11283' md. The casing was reciprocated for first hour while conditioning mud, then stuck 7' off bottom. Full returns were recorded while circulating and cementing. On 1/22/01 pumped 37 bbl 15.8 ppg class G. Plug was bumped to 1200 psi, 500 psi over displacement pressure. The casing shoe was pressure tested to 3500 psi before drilling out. At the Nanuq zone top, the two closest wells to the CDl-229 casing shoe are CDl-46 and CDl-18. CDl-46 is 1944 ft from CDl-229 at the Nanuq top (Albian 96 marker), and CDl-18 is 2839 ft. The cement jobs for CDl-46 & CDl-18 are summarized below. CDl-46 (inj) on 2/23/04 - pumped 62 bbls (15.8ppg class G). Top Nanuq at 9564'md. Design TOC at 9400' md. Good returns during placement (reciprocated pipe up to last 30bbls), bumped plug and floats held. Cement bond log on 4/7/04 - TOC at 9230' md. Drilled out 7" shoe 4/19/04, 12,5 ppg FIT. '~ CDl-18 (prod) on 12/1/04 - pumped 51 bbls lead (11 ppg LiteCrete) and 24 ~I~ bbls tail (15.8 ppg class G). Top Nanuq at 9533' md. Design TOC at ,>~J+~j? 9057' md. Good returns during placement, bumped plug and floats held. ~ .~ 12.5 ppg FIT after drillout. No bond log. T' )~ "S('tIP '-'Å~~-\ \£\ \ >' ~,,",'" ~~'V'(j~\C),^ 'I'\. Ç\~Æ~~h~u , (..Y~1; -..\~~ \\.'\ ~¥~ .-\ "" '\ ~" Jack -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] S en t: F r i day, March 2 4 "~'''''''-'2''Ö06''''-4'-~'31'''-pi~1--'-----''-'''''-'''-' ..--....-.......................................--...-..---..-...- To: Walker, Jack A Subject: CDl-229 Hi Jack, Just started looking at the sundry request to convert. Do you know if a bond log was ever run on this well. I briefly looked at the summary report we have and I cannot see that one was run. Not surprising since the well was drilled as a production well. I'd appreciate you looking into what you can find. I also request that you all provide an assessment of the 7" cementing operation and have the drilling or directional people do a 1/4 mile radius "scan" using the top of Nanuq or 7" casing shoe as the center point to identify any penetrations in the area. This would also include pilot holes. I don't think there is anything within 1/4 mile, but that does need to be verified. Call or message with questions. Have a good weekend. Also, please note 10f2 3/28/2006 10:49 AM RE: CDl-229 e tit our office will be closed on Monday for Seward's Day. Tom Maunder, PE AOGCC 20f2 3/28/2006 10:49 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic D Service D Development [1] Exploratory D 4b. Well Status: Oil [1] Gas D WAG D GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: 200-215 CD1-229/NQ1 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: 6. Permit to Drill Number: 7. Well Name: 8. API Number: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation D or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 50-103-20358-00 9. Field: 304-383 (h)(3) Other Commission approved substances (include descriptions in block 12) 10/22/2004 Volume (bbls): Number of days disposal occu rred Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: <'- b iJJ\)D AMNEO JPtN 1 f. Sç~'\3 - Previous totals (bbls): 409* 409 0 7887 0 0 0 0 0 0 100 1 10/30/2004 10/30/2004 CD1-11 7787 2004 14th o o o 20051 1st o o o 2005 1 2nd o o o 2005 1 3rd Total Ending Volume (bbls): Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 8296 1 7787 100 409 Pressure vs. Time D Step Rate Test D 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): * Freeze protect volumes and injectivity test I hereby certify that the foregoing is true and correct to the best of my knowledge. ~\~ vlz..-/06 Signature: Date: (907) 265-6830 Randy Thomas Kuparuk Drilling Team Leader Printed Name: Title: Phone Number: Form 10423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL * Freeze protect volumes and injectivity test I hereby certify that the foregoing is true and correct to the best of my knowledge. ~_...~ 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2004 14th 7787 20051 1st 0 2005/2nd 0 2005 1 3rd 0 Total Ending Volume 7787 (bbls): 100 o o o 100 11. Attach: Disposal Performance Data: Other (Explain) 0 12. Remarks and Approved Substances Description(s): Pressure vs. Time 0 Signature: Printed Name: Randy Thomas Form 10-423 Rev. 2/2004 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 5a. Sundry number: 5b. Sundry approval date: 304-383 (h)(3) Other Commission approved substances (include descriptions in block 12) 10/22/2004 Volume (bbls): Number of days disposal occurred 409* 409 0 7887 0 0 0 0 0 0 409 8296 Step Rate Test 0 Date: Title: Kuparuk Drilling Team Leader o o o 1 6. Permit to Drill Number: 7. Well Name: 8. API Number: 200-215 CD1-229/NQ1 50-103-20358-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: SC!~~~NE[: NOV () 2 2005 1 10/30/2004 1 0/30/2004 CD1-11 _. Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. \b(ZC ~j Phone Number: (907) 265-6830 QRnMS BFL OCT 2 1 2005 INSTRUCTIONS ON REVERSE !>tt"'nl Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2004 14th 7787 100 20051 1st o o 2005/2nd o o 2005 1 3rd Total Ending Volume (bbls): 7787 100 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Pressure vs. Time D 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAG D GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: 304-383 (h)(3) Other Commission approved substances (include descriptions in block 12) 10/22/2004 Volume (bbls): Number of days disposal occu rred 6. Permit to Drill Number: 7. Well Name: 8. API Number: 200-215 CD1-229/NQ1 50-103-20358-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: - 409* 409 0 7887 1 10/30/2004 10/30/2004 CD1-11 0 0 0 0 0 0 409 8296 Step Rate Test D * Freeze protect volumes and injectivity test I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~~~ \ b:..." Printed Name: Randy Thomas Form 10-423 Rev. 2/2004 SCANNEC .11)' 0 £) ?O-~ U l L 4 (<I ... UJ Date: Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE '-' 1 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. I) 1'( ,-fO j- Phone Number: (907) 265-6830 Submit in Duplicate .~. +~._-- , ,,,..". ~ .... ~ ... . o.~ "çlll\ ,'\ " (. ,'I. \ MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: 5b. Sundry approval date: 6. Permit to Drill Number: 7. Well Name: 8. API Number: 200-215 CD1-229/NQ1 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: 50-103-20358-00 9. Field: 304-383 (h)(3) Other Commission approved substances (include descriptions in block 12) 10/22/2004 Volume (bbls): Number of days disposal occurred Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~ Previous totals (bbls): 2005 1 1 st o o 409* 409 0 7887 1 10/30/2004 10/30/2004 CD1-11 0 0 0 2004 14th 7787 100 2005 1 2nd 2005 1 3rd ---- Total Ending Volume (bbls): 100 8296 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. FI 0 n·- ~ .~o L. loci 1. ð \...k, 7787 409 1 11. Attach: Disposal Performance Data: Other (Explain) 0 12. Remarks and Approved Substances Description(s): Pressure vs. Time 0 Step Rate Test 0 fî rF' ~...", r-<,p..' Nt NE~.: 1.1 V k' ,. , f" i., .. ~v ·C.-~ * Freeze protect volumes and injectivity test I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ Signature: Date: 'r {'-ê..(Ð·S Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 212004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate Schlumberger Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth Well Job # Log Description Date BL 2œ-2J5 CD1-229 10942798 INJECTION TEST 11/23/04 1 21;3-- {77 CD2-27 10922509 TEMPERATURE LOG 12/10/04 1 ~-I'iO CD1-11 10922523 SCMT 01/07/05 tf CD1-20 10942823 SCMT 01/07/05 20 ,.2!lo /, í <, 1005 . W~ SCANNED II.PR 1 Ii c DATE: 1/19/05 NO. 3310 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine .-./ Color Prints CD 1 1 --- /f~~ Please sign and return e copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2004 / 4th 7787 100 2005/1st 2005 / 2nd 2005 / 3rd Total Ending Volume (bbls): 7787 100 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 5a. Sundry number: 5b. Sundry approval date: 304-383 (h)(3) Other Commission approved substances (include descriptions in block 12) 10/22/2004 Volume (bbls): Number of days disposal occu rred 409* 409 0 7887 409 8296 Step Rate Test 0 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Other (Explain) 0 12. Remarks and Approved Substances Description(s): * Freeze protect volumes and injectivity test I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: \ ~~ \~ Date: Printed Name: Randy Thomas Form 10-423 Rev. 2/2004 Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 200-215 CD1-229/NQ1 8. API Number: 50-103-20358-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ",-,J 1 0/30/2004 10/30/2004 CD1-11 .~ 1 Report is due on the 20th of the month following the final month of the quarler. Ex: April 20 for the first quarler, July 20 for the second quarler, October 20 for the third quarler, and January 20 for the fourlh ~t;1ANN;:D JAN 1 4: 2DC5 l (., /0'>- Phone Number: (907) 265-6830 Submit in Duplicate 1. Operations Performed: STATE OF ALASKA RE EIVE ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 0 2004 REPORT OF SUNDRY WELL OPERATIONS, .."' ..... ... .. C' . . . 0 0 t'J~S~t) OJ; :1.¡~f¡S ~#~Xì:~C~Th'TIt~sitm Abandon Repair Well Plug Perforations 0 Stimulate 0 O~eJß'1 . . ,J Samples I\n",;!mmg Alter Casing 0 Pull Tubing D Perforate New Pool 0 Waiver 0 Time Extension Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development - 0 Exploratory 0 200-215/ 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 50-103-20358-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' CD1-229 ) 8. Property Designation: ADL 25559 / ALK 372097 11. Present Well Condition Summary: 10. Field/Pool(s): Colville River Field / Alpine Oil Pool Total Depth measured 16118' 6165' feet feet Effective Depth measured feet feet Plugs (measured) Junk (measured) true vertical true vertical Casing Structural CONDUCTOR SURF CASING PROD CASING LINER Length Size MD TVD Burst Collapse 7" 114' 3260' 11282' 15958' 114' 2385' 6183' 6173' 114' 3260' 11282' 4848' 16" 9-5/8" 3-1/2" Perforation depth: Measured depth: slotted liner from 11309'.15923' true vertical depth: 6185'.6174' SCANNED NOV 0 5 2004 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 11121' MD. Packers & SSSV (type & measured depth) pkr= BAKER ZXP PACKER W/6' TIEBACK EXTENSION pkr= 11100' SSSV= 1906' 12. Stimulation or cement squeeze summary: Intervals treated (measured) n/a Treatment descriptions including volumes used and final pressure: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X Oil.Bbl SI SI Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinq Pressure Tubinq Pressure 13. 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: oil0 GasD WAG 0 GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WDSPLD Contact Jack Walker @ 265-6268 Printed Name Jack Walker Title Staff Production Engineer Signature Ò ~UJ~ ~ Phone 2-" q- -G 2(, 5 ~~:',ljbv~.,du.~t.263-4612 Form 10-404 Re,"sed 0412004 0 R \ G \ N A L RBDMS BFL NOV - 3 2004 Submit Original Only ) CD1-229 Well Events Summary ) Date Summary 10/08/04 PERFORMED SBHPS. 10/10/04 FLOWED BACK NANUQ WELL TO ALPINE FACILITIES FOR SURFACE SAMPLES 10/19/04 PREP UNIT AND LUBRICATOR FOR BHS JOBD [Standby] 10/20/04 RAN SCHLUMBERGER SAMPLING TOOL TO 11,1431 RKB. TWO BHS'S WERE TAKEN IN TANDEM AND APPEAR TO BE GOOD SAMPLES. 10/24/04 SET BPV IN NANUQ WELL AND BLED TO ZERO ABOVE HANGER (1850 PSI TUBING PRESSURE) - BLIND INSTALLED IN FLOWLINE - WELL SECUREDD [WH Maintenance] ) ) ALPINE CD1-229 çØ"ø~ø,~hill~P..~lâ$KÎ,...lnç~ TUBING (0-11121, 00:3.500, 10:2.992) SEAL (11122-11123, 00:3,970) NIP (11180-11181, 00:3.500) NIP (11465-11466, 00:3.500) NIP (12662-12663, 00:3.500) NIP (13412-13413, 00:3.500) NIP (14499-14500, 00:3.500) d U: ..~ ff! " , rJ~'~ ~ ¡ t. ~ ¡ J Ii ;U~ i;.ï~' " .~. ¡: ~, '.; if: ~~ 1;- I' .~. ! ~ I t Ii ." - ; :,,', , .:~".,' ¡ I l . r'! i .,' ¡ ¡ I~ ~ll\il I . II f~ I I I 1 ~ ~ f Ii I ,,! I, ~ ! ¡, . - -. .- - -. .- -- - -I 1- - -. .- - - 1- - -. .- . I -' J -,1'1- I =::::. .:'= J: :';... '.;., .. CD1-229 API: 501032035800 SSSV Type: TRDP Well Type: PROD Orig 2/3/2001 Completion: Last W/O: Ref Log Date: TO: 16118 ftKB Max Hole Angle: 93 deg @ 16118 Angle @ TS: deg @ Angle @ TD: 93 deg @ 16118 Annular Fluid: Reference Log: Last Tag: Last Tag Date: Rev Reason: Format Update Last Update: 11/24/2003 Casing String - ALL Description CONDUCTOR SURF CASING PROD CASING LINER Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD 11309 - 11433 6185 - 6192 11531 -12631 6191 - 6189 12760 - 12914 6194 - 6197 13042 - 13380 6201 - 6208 13478 - 13724 6210 - 6218 13819 - 14467 6221 - 6213 14629 - 15270 6208 - 6194 15397 - 15796 6191 - 6179 15892 - 15923 6176 - 6174 Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Mfr 1 5334 3385 CAMCO KBMM-2 CAMCO 2 9040 5210 CAMCO KBMM-2 CAMCO 3 10626 5978 CAMCO KBMM-2 CAMCO Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 1906 1710 SSSV 10705 6015 NIP 11100 6158 PKR 11122 6163 PBR 11122 6163 SEAL 11180 6175 NIP 11465 6192 NIP 12662 6190 NIP 13412 6208 NIP 14499 6212 NIP 15956 6173 SHOE General Notes Date Note 2/21/2001 NOTE: This well has also been known as 'CD1-NQ1'. No TVD data displayed yet due to no Survey data loaded yet; also no Zonal data yet. Size 16.000 9.625 7.000 3.500 Bottom 114 3260 11282 15958 TVD 114 2385 6183 6173 Wt 62.58 40.00 26.00 9.30 Grade Thread H-40 WELDED L-80 BTC-MOD L-80 BTCM L-80 SLHT Top 0 0 0 11110 Bottom 11121 TVD 6163 I Grade I L-80 Thread 8rd Mod Wt 9.30 Zone Status Ft SPF 124 99 11 00 99 154 99 338 99 246 99 648 99 641 99 399 99 ,,31 99 Comment SLOTTED LINER 4 JTS SLOTTED LINER 36 JT SLOTTED LINER 5 JTS SLOTTED LINER 11 JT SLOTTED LINER 8 JTS SLOTTED LINER 21 JT SLOTTED LINER 21 JT SLOTTED LINER 13 JT SLOTTED LINER 1 JT Date 1/30/2001 1/30/2001 1/30/2001 1/30/2001 1/30/2001 1/30/2001 1/30/2001 1/30/2001 1/30/2001 Type GLV GLV OV Date Run 1.0 BK-5 0.188 1809 2/8/2001 1.0 BK-5 0.250 1948 2/8/2001 1.0 BK 0.250 0 2/8/2001 Vlv Cmnt ID 2.813 2.812 5.250 4.000 3.000 2.813 2,813 2.813 2.813 2.813 0.000 Description HES FMX TR-SSSV, WITH .25 x 0.049" 316L S/S CONTROL LINE HES 'X' NIPPLE BAKER ZXP PACKER W/6' TIEBACK EXTENSION BAKER 80-40 POLISHED SEAL BORE RECEPTICLE GBH-22 '80-40' LOCATOR SEAL ASSEMBLY HES 'X' NIPPLE #1 HES 'X' NIPPLE #2 HES 'X' NIPPLE #3 HES 'X' NIPPLE #4 HES 'X' NIPPLE #5 GUIDE SHOE ConocoPhillips Alaska STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 152004 ANNULAR DISPOSAL APPLICATION ~ 20 MC 25.080 Alaska Oil & Gas Cems. Comm'L 3. Permit to Drill No: 200-215 RECEIVE 1. Operator Name: Þ:G{~r\ ¡Cí1/~....,~ -~~ 4. API Number: 50- 103-20358-00 2. Address: 700 G Street, Anchorage, Alaska, 99501 5. Well Name: CD1-229/NQ1 6. Field: Alpine 7. Publicly recorded wells / 8. Stratigraphic description: a) Interval exposed to open annulus: Torok and Seabee formation. Shale, siltstone and sandstone a) All wells within one- quarter mile: /' J J J 801-26, CD1-27, CD1-37, CD1-38, CD1-39, CD1- ""40, CD1-4~on file: Note CD1 ~ and CD1-46 were recently submitted) b) Waste receiving zone: Sand layers in the Colville group C-30 in the Seabee formation b) water wells within one mile: NONE c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier (Ref. AOGCC Conservation Order No. 443, March 15, 1999) 9. Depth to base of permafrost: Est. 1744' MD/1600' TVD 10. Hydrocarbon zones above waste receiving zone: NONE 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: 409 bbl Densities range from diesel to 12#/gal. 1945 psi 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35000 bbl 16. Estimated start date: Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, ccement rinsate, 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. 12/1/2004 17. Attachments: Well Schematic (Include MD and TVD) [] Cement Bond Log (if required) 0 FIT Records wI LOT Graph D Surf. Casing Cementing Data [] Other 0 18. I he~eby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~(()( Title: Alpine Drilling Team Leader Printed Name: Chip Alvord Phone Number: 907-265-6120 Commission Use Only Conditions of approval: O"<t~\-\.~"~ '\~. c,.~t..C~ \'-.)1 èJ:J ~~<:"J5,æT review and approval: AD ~ ~\t.~\--to,,<? ~ 'fClf'\.W SUbSeqUent. ~orm. . ".. -.) . Approval re~Ulred: 0 ~ Õ'~, number: APprcC: . by: , Date: (p ( (1/( -' t- m~ 'Ot...\- ð-\ :mOL{ ( 30<-/- 3&- 3 BY ORDER OF THE ~~.. .10"1 Date: 1" ", COMMISSIONER COMMISSION .RßJìf}1;' ~ ~ORIGINAL Form 10-403AD Re".9/2003 INSTRUCTIONS ON REVERSE SC.ANNED OCT:: '1 ~IT4 in Duplicate ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 ConocóP'hillips October 12, 2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drillin2 Waste on well CDl-229/CDl- NOl Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CDl-229/CDl-NQl be permitted for annular pumping of fluids occurring as a result of drilling opé1rations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CDl-229/CD1-NQl approximately December 1st, 2004. 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 CD 1 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within % mile radius, not already on file at AOGCC: Note CDl-26 and CDl-46 are within 1320' but were included in the most recent applications for CD1-08 and CDl-46. Further details regarding wells on CD 1 pad within lÄ mile radius should be on file at the AOGCC. The initial annular LOT (14.3 ppg) and occurred at a lower equivalent mud weight than the casing shoe test (15.6 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 Vern Johnson or Zane Kuenzler at 265-6081 and 265-1308, respectively. Alternatively, Chip Alvord can also be reached by calling 265- 6120. Sincerely, ~q lo(r..jo't Z£e ~~;lkr Drilling Engineer cc: CDl-229/CD1-NQ1 Well File Chip Alvord A TO-1700 Bill Esco Anadarko Sharon Allsup~Drake ATOd530 ORIGINAL Annular Disposal Transmittal Form 1. Designation of the well or wells to receive drilling CDI-229/CDI-NQl wastes. 2. The depth to the base of freshwater aquifers and permafrost, if present. 3. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. 4. A list of all publicly recorded wells within one- quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. There are no USDW aquifers in the Colville River Unit. Estimated base of Permafrost = 1600' TVD (RKB ) The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier. Calculated water salinities of the Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/I. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) See attached map indicating wells within 1/4 mile. There are no water wells within 1 mile. 5. Identify the types and maximum volume of waste to Types of waste may be drilling mud, drilling cuttings, be disposed of and the estimated density of the waste reserve pit fluids, cement-contaminated drilling mud, slurry. completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/ gal. Maximum volume to be pumped is 35,000 bbls. 6. Description of any waste sought to be determined as Cement rinsate drilling waste under h (3) of this section 7. An estimate Qf maximum anticipated pressure at the Maximum anticipated pressure at casing shoe during outer casing shoe during annular disposal operation disposal operations is 1945 psi. See attached and calculations showing how this value was calculation page. determined. 8. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation. See attached cementing reports, LOT/FIT reports, and casing reports. 9. Details that show the inner and outer casing strings See attached casing summary sheet and calculation have sufficient strength in collapse and burst to page. withstand andcipated pressure of disposal operations. 10. Any additional data required by the Commission to NA confirm containment of drilling wastes. OCT 2 7 2004 Pressure Calculations for Annular Disposal Well CDl-229/NQ1 Date 10/4/2004 C)t) .5 00 ~ U Q Q Q r.: 2,398 TVD Assumptions Maximum injection pressure of Maximum density of the injection fluid is Pore pressure at the 9 5/8" casing shoe is Gas Gradient is Header Pressure 1,500 12 0.4525 0.11 2,000 psi ppg psi/ft psi/ft psi '" c= el) '" ~ C\Ð Maximum Fluid Density to Burst Surface Casing Pburst85% = PHydrostatic + P Applied - PFormation MW max 2,992 = ( 2,398 * 0.052 * MWmax. ) + 1500 - (0.4525 * 2,398) 20.7 ppg Surface Casing String Size Weight Grade PburstlOO% Pburst85% Depth of Shoe FIT/LOT @ Shoe FIT/LOT for Annulus Max Surf. Pressure 9.625 in 36 ppf J 55 3,520 psi 2,992 psi 2,398 ft 15.6 ppg 14.3 ppg 1,500 psi or 1,945 psi Maximum Fluid Density to Collapse 2nd Casing String P collapse85% = PHydrostatic + P Applied - P GasGradient - PHeader MW max 4,599 =( 5,776* 0.052 'I< MWmax. )+ 1,500 -( 0.1100 * 5,776)- 2,000 Maximum Allowable Pressure at Surface Casing Shoe TOC Est. @ 10,252' MD 5,776' TVD TVD P max allowab1e = Shoe TVD Depth * .052 * Shoe FIT /LOT P max allowable = P max allowable = ( 2,398 * .052 * 15.6 ) 1,945 psi 19.1 ppg 2nd Casing String Size Weight Grade P collapse 100% P collapse85% Top of Cement Gas Gradient Max Surf. Pressu Header Press 7 26 L 80 5,410 4,599 5,776 0.11 1,500 2,000 in ppf psi psi ft psi/ft psi psi Casing Detail 95/8" Surface Casinq œPHILLlPS Alaska, Inc. œ. A Subsidiary of PHILLIPS PETROLEUM COMPANY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Well: CD1-NQ1 Date: 1/812001 LENGTH Jts 3 to 78 Doyon 19 RKB to LOS FMC Gen V Hanger 9-5/8" 40# L-80 BTC Csg Davis Lynch Float Collar 9-5/8" 40# L-80 BTC Csg Davis Lynch Float Shoe 36.80 2.36 3137.87 1.50 79.44 1.72 76 Jts Jts 1 to 2 2 Jts TO 12 1/4" Surface Hole 3270.00 RUN TOTAL 44 BOWSPRING CENTRALlZERS- 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #2) #14,16,18,20,22,24,26,28,30,32,34,36,38, 40, 42, 44, 46, 48, 50, 52,54,56,58,60,62,64,66 68,70,72,74,76 7 Jts left out #79. #85 Use Best-a-Life 2000 pipe dope Remarks: Up Wt -170 k On Wt -135 k Block Wt - 70 Supervisor: Don Mickey SCANNED OCT 2 7 2004 DEPTH TOPS 36.80 39.16 3177.03 3178.53 3257.97 3259.69 Phillips Alaska Drilling I Well Name: CD1. NQ1 Rig Name: Doyon 19 Casing Size 9 518" Hole Diameter: 121/4 Angle \hru KRU: 60 Report Date: 01/1012001 AFC No.: ASDOO3 Cementing Details Report Number: 5 I Field: Alpine I Shoe Depth: 3260 LC Depth: 3177 State type used, intervals covered and spacing 44 bow spring' 1 each on first 12 jt., then one on every other It. to 121' Weight: 9.6 Gels before: 35,60,74 PV(prior cond): 18 PV(after cond): 24 Total Volume Circulated: 660 bbls YP(prlor cond): 37 % washout: YP(after cond): 12 Weight: 8.3 ppg Weight: 10.5 ppg Yield: 4.44 Yield: 1.17 Str. WI. Up: 170 K Str. WI. Down: 135 K Str. WI. in mud: CP: Date:01/09l2oo1 Time: 1 530 hrs. Remarks:Full returns through lob w/150 bbls cmt returns to surface - Lost prime on mud pump while displacing. recalculated stks. when prime was regalned- didn't bump plug. tagged top of cmt @ 3168' . top of FC@ 3177' Calculated top of cement: Surface I Cement Company: Dowell Gels after: 5,9,13 Type: Water Type: ARCO B45 Type: AS'" Mix wtr temp: 70 Volume: 40 bbls Volume: 50 bbls No. of Sacks: 591 Weight: 10.7 ppg Additives: Class G wl3O% D053, 0.6% 0046, 1.5% 0079, 1.5% SOO1, 50% D124 & 9% BWOW DO« Type: I Mix wtr temp: I No. of Sacks: I Weight: G 70 231 15.8 ppg Additives: 0.2% 0046,0.3% D065, 1% SOO1 . Rate(before tail at shoe): 5.5 bblslm Reciprocation length: 25' Theoretical Displacement: 240.8 bbls I Rig Contractor: DOYON Rate(tail around shoe): 5.5 bblslm Reciprocation speed: Actual Displacement 240.8 Bumped plug: No Floats held: Yes I Approved By: Don Mickey Co noco Phi llips ',AIa.sk8,. Inc. Daily'. "riUiog Repørt Page 1 of 1 ¡JOB NUMBER \ EVENT CODE \24 HRS PROG CD1-229 ODR SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. DON MICKEY Doyon Drilling Inc 19 NANUQ CURRENT STATUS ACCIDENTS LAST 24 HRS.? P/U 5" DP F/PIPE SHED TMD I TVD I DFS 3,270.0 2,390.0 AUTH MD I DAILY T AN~ DAILY INT WIO MUD 0 DATE OF LAST SAFETY MEETING DAILY TOTAL 296,998 I REPT NO. I DATE 4 1 19/2001 ICUM. TANGO CUM INT ANG WI MUD 0 CUM COST WI MUD 505,855 WELL NAME 24 HR FORECAST TEST CSG - LOT - DRILL 8112 HOLE I JAR HRS OF SERVICE I BHA HRS SINCE INSP INC AZIM I LAST CASING (in) @ LITHOLOGY LAST SURVEY: DATE TMD .F:RQM ,Te;> HØVÄ$ CÓDE, TRÖÜBLÈSUB 00:00 01 :30 1.50 DRILL P TRIP 01 :30 03:30 2.00 DRILL P PULD 03:30 04:00 0.50 DRILL P OTHR 04:00 05:00 1.00 CASE P RURD 05:00 11 :00 6.00 CASE P RUNC 11 :00 13:00 2.00 CEMENT P CIRC 13:00 15:30 2.50 CEMENT P PUMP 15:30 16:30 1.00 CEMENT P PULD 16:30 17:30 1.00 CASE P RURD 17:30 22:30 5.00 WELCTL P NUND 22:30 23:00 0.50 WELCTL P BOPE 23:00 00:00 1.00 WELCTL P BOPE I LEAKOFF I NEXT CASING (in) @ (ft) LAST BOP PRES TEST 1/6/2001 AFE AUTH. ASD003 (ft) , øp:EÂÄWíêNS$\J.'NlM~R¥ . , ' , , ' " ' "',' , Þ.~ASE ",' ," '. " ". ' 'Ø~$CRIPTtON SURFAC Pull out to run 9 5/8" csg - hole in good condition SURFAC Handle BHA - std back HWDP, 1 std. DC - UD UBHO, stabs, MWD,Pony DC, motor & bit SURFAC Clean up rig floor SURFAC Rig up to run 9 5/8" csg SURFAC PJSM - Ran 78 jts. 95/8" 40# L-80 csg w/FC & FS - P/U landing jt. & land wi shoe @ 3260' MD - 2385' TVD SURFAC Circ & condition hole & mud for cmt job - UD fill up tool - M/U cmt head & lines - Continue circ SURFAC PJSM - cmt. 9-5/8 csg - 40 bbls Viscosified water - test lines to 2500 psi - drop btm plug- 50 bbls Arco spacer @ 10.5 ppg - mix & pump 591 Sxs (467 bbls) lead slurry @ 10.7 ppg - 48 bbls tail slurry @ 15.8 ppg - Observe red nut plug marker @ 450 bbls lead - drop top plug w/ 20 bbls water f/ Dowell - switch to rig pumps - displace w/224 bbls mud - didn't bump plug - floats held - CIP @ 1530 hrs SURFAC UD cmt head & landing jt - flush 20" hydril with water SURFAC UD csg equip. SURFAC PJSM - N/D 20" diverter - install FMC Unihead - N/U BOP stack - flow line, turnbuckles SURFAC Install test equip.- PJSM testing BOPE SURFAC Test BOPE - test hydril250 psi low & 2500 psi hi - choke valves 250 psi low & 3500 psi hi ASING:7"@ ,EST COST TO DATE:714000 Printed: 10/6/2004 10:45:52 AM SCANNED OCT 2 7 2004 Well Name: CASING TEST and FORMATION INTEGRITY TEST 1/10/2001 Supervisor: D. Mickey CD1-NQ 1 Date: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/8" 40# l-80 BTC CSG Reason(s) for test: Casing Setting Depth: 3,260' TMD Hole Depth: 3,288' TMD 2,385' TVD 2,398' TVD Mud Weight: 9.6 ppg Length of Open Hole Section: 28' EMW= Leak-off Press. + Mud Weight = 750 psi + 9.6 ppg 0.052 x TVD 0.052 x 2,385' EMW for open hole section = 15.6 ppg Used cement unit Rig pump used NO #2 3,000 psi 2,900 psi 2.800 psi 2.700 psi 2,600 psi 2,500 psi - 2.400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1 ,900 psi W 1,800 psi a:: 1 ,700 psi ::J 1,600 psi ~ 1,500 psi W 1 .400 psi a:: 1 ,300 psi a. 1,200 psi 1,100 psi 1'~::d- 800 psi - 700 psi " ,!" 600 psi 500 psi 400 psi ' - 300 psi 200 psi I 1og::. . I 0 10 Pump output = 0.0997 bps Fluid Pumped = 1.8 bbls Fluid Bled Back = 0.9 bbls II , 111111111 11111111 ~..LIIIIII 111111111 I /.... ...¡~~. .. ... / \TIME LINE I ONE MINUTE TICís ~ LEAK-OFF TEST ~CASING TEST -~-- LOT SHUT IN TIME -.- CASING TEST SHUT IN TIME -+-TIME LINE It \ S'.O E.~\.0 Á't!M\Cb,c'" 20 30 STROKES 40 50 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above p1kUl¿1d~ LEAK-OFF DATA 60 MINUTES FOR LOT STROKES PRESSURE C~~~~~~~~~~~~~~¡~~~~~~~~~~~~~~¡~~~~~~~!~~~~~1 L______--______L____~A~_____l___~9...e.!L__J L--------------L----~:~-----L-_1~9..p~!_.J L---------------!------~:~----J---~.!9..P_!!_--! ~---------------~------~:~-----~----~~9..P_!!.--i L______---______L_____~:~_____L__~~9..P_!!._J L-------------.J------~:_~-----l---~~9..P_!!---1 L--------------J----_?:~-----L---~~9..P_!!._-! ~---------------~------~:~-----~----~Z9..P_!~---i L______--______L____~:~_____L__~.!9..P_!!__J L--------------L---~-~~9.----L--~~9..p_!!---1 L---------------!-____~_1:9._---L---~~9..P_!!._-! ~---------------~----_1.~:9._---~----~~9..P_!~---i L______---______L____~_~~9.____L__~~9..P_!!__J L-------------J----~-~:9.----1---?~9..P_!!---1 L---------------!-----~-~~9.----L--X~9..p_!!_--! ~---------------~-----~-~:9._---¡---~~9..P_!~---i L______--______L__J_?:9.____1___~Z9..P_!!__J L--------------L---~-~:9.----L--~~9..p_!!---l I I . I 1 I . I I I . I ,..---------------,---------------.,-----------------" I I I I ~---------------1---------------1-----------------t I , I I ..._--------------~-----------..---~---------.._----_.& I I I I I I I I r---------------1...............................t................."""""''''''1 . , , , I I I I ~-~!:'_'!!_~~!-!~-~---------------~!:'_'!!_~!.!:'!~~_~!:'1E L_.Q.:9.._~!~__L______--______l___?_~Q_P_~!__J L--!.:9..-~!~-J.--------------L--~!!9..p~!-.J L--~.:9..-~!~-.t--------------L---~~9...P_!!_--! ~---~.:9..~~~--~---------------~----~~9..P_!~---i L_~.:9.._~!~__L______--______L__~~9..P_!!__J L--~.:9..-~!~-J--------------l---~~9..P_!!-.J L--~.:9..~!~--!---------------L---~Z9..P_!!_--! ~-_X.:9.._~~~--~---------------¡---~Z9..P_!!.--i L__~.:9.._~!D___L______-______L__~Z9..P_!!._J L--~.:9..-~!~-J--------------l--_~Z9.'p_!!_-j L"!Q:9_.r:!~!~-j-----------____l__-~Z9..P_!!_--1 ~PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r---------------r--õïšiks--l-----õ psr --¡ I----------------+---------------+-----------------f L______--______L__~_~_~~!___L___~~_.P-!~--_J L--------------L--~-~-~~!---L---!~-.P-!~--.J ~---------------¡---~_!.~~~---!--_'!~QJ~!~--~ ~---------------¡---~-~-~~---¡---~~~_P-!L_~ L______--______L__!9._!!I!!__L__~!~_P-!~-_J L--------------L--!~-~!~-J---~9.~_P-!~-.J ~------------__-!--_1~_!!I!!_-¡--_!!~~_P-!LJ ~---------------~--_!!?_!!I!!__¡_J-,_1.!9..P~~_~ L______--______L__!~_!~_I!!_.l_-~-,~!?9..P~!_J L--------------L-~9._!!I!!-J-J-,-~~Q..p_!!.J ~---------------!--~~_!!I!!--!-J-,-~!!9..P~!.~ ~---------------¡--~~-~!I!!_-¡_J-,_?!!~-'p_!~-~ L______--______L_~!?_!!I!!__L_~-,_~~9..P_~!_J L--------------L-~~-~!~!--L-~_1Z9..p_!!.J ~--------------!--~9._~!I!!_-¡--~-~~Q..p~!_~ ~---------------¡--~~_!!I!!_-¡--~-~~Q..p_!!_~ I . . I I I I I 1.._-------------_'&'_-------------_'&'_--------------_"& I I I I I I I I I I I I r---------------1---------------t----------------¡ I I I I I I I I ~-~~~~~~~~-~--------------~~~~~!.~~~~~f L_2:9__~!D___L______--______L_,g!.~_~Q_P_~!_J L-_!:9.._~!D__-L--------------L-~-~~~-.p~!.J ! 2.0 min ¡ ¡ 2,490 psi ¡ ~~~~9.~~~~=~!~~~~~~~~~~~~~~~!~~~~~!~~~!~~ L__~9.._~!D__.l___-----______L_~_~!!Q..p~!_J L-§.:9..-~!D..--L--------------l--~-~!!~..P~!.J ~--~.:9.._~!D_--!-__-----------!--~t~~~..P_~!J ~-_?'.:Q.-~~~---¡---------------¡--~-~~..P~~-~ L_~.:9.._~!D___L______--______L_~_~~~.p~!_J L-~.:9..-~!D..--L--------------L--;-~~.p_!!.J ~-_!Q:.9_!!!~r]--!---------------!---;-~~~'p~!_~ ~__!~:.9_!!!~r]__¡---------------¡---;-~~~'p~~-~ L_~Q:.9_!!!~r]__L______--______L_~-,_~~~.p~!_J L~~:.9_!!!~r]--L--------------L-~-~~.p~!.J L--~2:.9__~~r]__L______-------j--~~~~'p~!.J NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ~PHILLlPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Casing Detail 7" Intermediate Casing Well: CD1-NQ 1 Date: 1/20/01 r ..-. -... j . - Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH Jts 3 to 276 Doyon 19 RKB to LDS Casing Landed on Emergency Slips 7" 26# L-80 STCM Csg 7" Davis Lynch Float Collar 7" 26# L-80 STCM Csg 7" Davis Lynch Float Shoe 11162.89 1.46 82.11 1.75 34.45 274 Jts Jts 1 to 2 2 Jts TD 8 1/2" hole Top of Nanuq @ 11252 ' MD. 1 straight blade centralizer per jt. #1 - # 26 39 spiral centralizer (1) every other jt #198 - #274 Total - 65 centralizers Joint # 276 original length (40.77') is ajusted in talley to 35.37' (cutoff 5.40') Used Best-a-Life 2000 pipe dope Remarks: Up Wt -370k Dn Wt - 140k 8t;ANNED ocr 2 "'1 2004 SupelVisor: OA VIO P. BURLEY DEPTH TOPS 34.45 34.45 111 97.34 11198.80 11280.91 11282.66 11304.00 Phillips Alaska Drilling I Well Name: CD1-NQ1 Rig Name: Doyon 19 Casing Size 7. Hole Diameter. 8.5. Angle thru KRU: Report Date: 01122J2oo1 AFC No.: ASDOO3 Shoe Depth: 11283 Cementing Details Report Number: 17 I Field: Alpine I LC Depth: 11197 % washout: State type used, intervals covered and spacing Ran 8-318. straight blade centralizers 1 per Joint on "s 1.26. Ran 8-318" spiral centralizers every other Joint on "s 198-274. Weight: 10.15 Gels before: 7/9/11 Type: ARCO Wash Type: ARCO 845 Type: Additives: Type: G PV(prior cond): 11 Gels after. 411/8 Mix wtr temp: Mix wtr temp: 70 PV(after cond): 10 Total Volume Circulated: 950 Volume: 208BlS Volume: 50 BBlS No. of Sacks: No. of Sacks: 187 Additives: 0.2% 0046, 0.27% 0065,0.20% 0800 AND 0.25% D1S6 Rate(tail around shoe): 7.0 Rate(before tail at shoe): 7.0 Reciprocation length: NIA Calculated top of cement: 10252' WITH 40% EXCESS OH ASSUMED. Theoretical Displacement: 428.9 BBLS. CP: Date: 1122101 Time:1101 HRS. Remarks:Established circulation and staged pumps up to 6.5 BPM, recirpocated pipe for first hour while conditioning mud, then pipe stuck-7'"offbottom. HadJull returns while circulating and cementing, bumped plugs to 1200 psi, 500 over final displacement pressure. \.; , I Cement Company: Dowell I Rig Contractor: DOYON Reciprocation speed: Actual Displacement: 427.8 BBlS Bumped plug: YES YP(prior cond): 21 Weight: Weight: 15.8 PPG Floats héld: YE~ '. I Approved By: ' David P. Burley YP(after cond): 14 Weight: 8.3 PPG Weight: 12.5 PPG Yield: Yield: 1.15 Str. WI. Up: Str. WI. Down; '.. .-. Str. WI. in mud:"',' :' I:... . . ~ 1 ~ '- . . Page 1 of 1 ConocoPhiUipsAl8Ska, 'InC. DaUyDrUling Report 24 HR FORECAST MU BHA #5, RIH PICKING UP 3-1/2" DRILL PIPE. LITHOLOGY \ JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING (in) @ TMD \ TVD \ DFS 11,304.0 6,184.0 AUTH MD \ DAILY T AN~ DAILY INT WIO MUD 0 DATE OF LAST SAFETY MEETING DAILY TOTAL 182,017 I REPT NO. I DATE 171/22/2001 ICUM. TANGO CUM INT ANG WI MUD 0 CUM COST WI MUD 2,415,751 WELL NAME \JOB NUMBER \ EVENT CODE 124 HRS PROG CD1-229 ODR SUPERVISOR I RIG NAME & NO. \ FIELD NAME I OCS NO. DAVID BURLEY Doyon Drilling Inc 19 NANUa CURRENT STATUS ACCIDENTS LAST 24 HRS.? TESTING BOPE. \ LEAK OFF AFE AUTH. ASD003 (ft) \ NEXT CASING (in) @ (ft) LAST BOP PRES TEST 1/17/2001 fROM' ,TO 00:00 02:00 02:00 03:00 03:00 05:00 05:00 07:30 I HOQ.R$ 2.00 1.00 2.00 2.50 CODE CASEP CASEP CASEP CASEP . TROUBLE SUB RUNC CIRC RUNC CIRC 9PI5R.ATIONS..SUMMAR¥ PI:iÄ$E " ' INTRM1 Run 7" casing to 9514'. INTRM1 CBU, 5 BPM @ 550 psi. INTRM1 Run casing to 11289'. INTRM1 Stage pumps up to 6.5 bpm @ 700 psi, circ and cond mud. Reciprocated casing for first hour, then pipe stuck 7' off bottom with shoe @ 11282'. Lay down fill-up tool and MU cement head Continue circulating, held PJSM with Dowell. Attempted to test cement lines, 4 way cross on standpipe manifold washed out. Install loop around washout. Tested lines to 3500 psi, pumped 20 bbls of wash, 50 bbls of 12,5 ppg spacer and 37 bbls of tail cement. Displaced with 20 bbls FW followed with 407.8 bbls of mud, plugs bumped, CIP @ 1100 hrs. Check floats -good. Blow down lines and LD cement head Clear casing tools from floor and clean rig floor. LD 5" running tools and PU 3-1/2" tools. Service Top Drive and Drawworks. Change pipe rams to 3-1/2" X 6"- work platform around BOP stack failed - repair and secure platform. Separate BOP stack from wellhead and land casing on slips with 120k tension. Rough cut 7" casing. LD LJ and cutoff and move stack clear of wellhead. Final cut and dress 7" casing. Install and test packoff to 4300 psi for 15 min. öeSCRIPTioN 07:30 08:00 0.50 CASE P RURD INTRM1 08:00 08:30 0.50 CEMENT P CIRC INTRM1 08:30 09:00 0.50 CEMENT P SEaT INTRM1 09:00 11 :00 2.00 CEMENT P PUMP INTRM 1 11:00 12:30 1.50 CEMENT P PUMP INTRM1 12:30 15:15 2.75 CEMENT P PULD INTRM1 15:15 16:00 0.75 RIGMNT P RSRV INTRM1 16:00 18:00 2.00 WELCTL P EQRP INTRM1 18:00 00:00 6.00 CASE T DH NUND INTRM1 SING:,EST COST TO DATE:2314565 Printed: 10/6/2004 10:46:49 AM OCT 2 « 2004 CASING TEST and FORMATION INTEGRITY TEST /""., Date: 1~/24/2001 f /J 0 Initial Casing Sho~ Test ~..../ 0 Formation Adequacy for Annufár Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Well Name: Reason( s) for test: CD1-NQ1 )Supervisor: D. Burley Casing Size and Description: 95/8" 40# L-80 BTC X 7" 26# L-80 BTMC Casing Setting Depth: 3,260' TM D 2,385' TVD TOC Hole Depth: 10,252' TMD 5,776' TVD Mud Weight: 10.1 ppg Length of Open Hole Section: 6,9921 EMW = Leak-off Press. + Mud Weight 0.052 x TVD Used cement unit Rig pump used 700 psi 600 psi 500 psi w a: 400 psi :J en en w æ 300 psi / 100PSi/~ 0 psi 200 psi = 550 psi 0.052 x 2,385' + 10.1 ppg EMW for open hole section = 14.5 ppg yes #2 Pump output = bbls pumped Fluid Pumped = 12.5 bbls Fluid Sled Sack = 0.0 bbls .~ I~I fA ("S ( ~ ITIME LINE I ., I- I::.. '""-W , ONE MINUTE TICKS ._~ Ø2-n;Öbrð'\ \ . '''--. ''''--.--. 'i>--..'¡,II--'jI--4il--- "--t1>--:;, -+- LEAK-OFF TEST ""'-CASING TEST -§-- LOT SHUT IN TIME ~ CASING TEST SHUT IN TIME -+-TIME LINE 10 12 14 BARRELS 16 18 20 22 24 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA 26 MINUTES FOR LOT BBLS PRESSURE ¡::::===-E~:=:~ L--------------l-----~_:~----j----~~-p.~J_--.J I I 1.5 I 81 p.si I ~---------------t--------------~-------- -------~ ~--------------+-----~:~-----~---~_!!_P.~~---4 L______--______l____!:~_____l___~_l!.~-p.~~-_.J L-------------l-----~:~----j---~_~!_p.~l_-.J l--------------l-----~:~-----l---~-~!_p.~L_-J ~----------------i------~:~-----1----~-~~_P.~~---4 L______-______l_____~:~_____L__~_l!.~-p.~~-_.J L-------------l-----~:~----j---~_~~_p.~l_-.J l---------------l.----_?.:~-----l---~-~~_p.~l___~ ~----------------i-----_?.:~-----~---~~-P.~~--4 L______-______l_____~:~_____l___~_!~-p.~~_.J L-------------.1-----~:~-----L--~-~Q_p.~l_.J l---------------!-----~:~-----l---~-~Q_p.~l_-l ~----------------i------~:~-----~---~-~~_P.~~---4 L______-______l____!~:.Q---_1._-~!~_P.~1__.J L-------------l----!~:É----L--~-~~_p.~l___j ! ! 11.0 ! 419 psi ¡ r~~~~~~~~~~~~~~~¡~~~~I~~~~~~~¡~~~~!~~P-~~~~~ l______---______L___!~:.Q____L__~!..~_P.~1__.J ~---------------+---_!~:É_---~.......~.~.~..p.~~.......! 1 I , , I I -------------- I I ~-~!!~~~-~-~~--i---------------~r,!!:,!!~-~~~~~~~E L_Q.:Q_~l!!__l______--______l___~~_P..~L_.J L--!.:Q-~.!..f!--L------------j---~_~!_p.~L_.J l---~.:Q-~J!!-J--------------l---~-~_p.~l__-J ~---~.:Q-~~!!_--i---------------~---~-~~_P.~~---4 L__~.:Q_~l!!__l______-------_l._-~-~~-p.~1._.J L--~.:Q-~J!!--L-------------l.--~_!~_p.~L..J ~---~.:Q-~J!!--L--------------l---~-~~_p.~l__-J ~_'?.:Q-~~!!_--i---------------~---~-~~_P.~~---4 L__~.:Q_~l!!__l______-------_l._-~_~!_P.~l__.J L-~.:Q_~l!!_-l--------------l.--~_~~_p.~l_-J L1_~.:~U~r]!~--1______--------1._-~_~!.p.~l__j ~PHILLIPS Alaska, Inc. ~ A Subsidiary ($ PHILLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ~~~~~~~~~~~~~~~~~~~~~~~!!~~~~~~~~~~~~~p-~}~~~~~f I I I I &'_--------------..1--------------..1----------------_'& ! i i i "---------------04---------------04-----------------. I . I I ~ : I J r---------------,---------------,-----------------, I I I I ~--------------i---------------i-----------------i J J J J 1._--------------""---------------""----------------_& I , I . I . , I :"---------------~---------------J-----------------: . I I I I . 1 , . I I , r---------------,---------------,-----------------: I I I . ----------------of---------------of-----------------f I : J I L______---------""---------------..I----------------_& I I I I I J : I r---------------,---------------,-----------------¡ . . I I r---------------"I---------------"I-----------------Y , , , . I . . I ----------------of---------------of-----------------f . I I I I I I , L______---------..I---------------..I----------------_& I I , I I , I I I..--------------J---------------J-----------------l I I I I : I : : r--------------.,---------------.,-----------------, I I I I ~--------------i---------------i-----------------i I I I I , I , , L______---------..I---------------..I----------------_& , , , . , , . . , I , I :----------------1---------------1-----------------: I I , I I I 1 I ~-~!!.'1!_~~~I~~-4---------------~t'_'1!_~~!~~~_l!~,E L__Q.:Q_~!!l_.J_------------_J._----~_P..~!_____i ! 1.0 min ¡ ! ! "---------------"'-------------"-----------------t I 2.0 min I I I ~--------------~---------------~-----------------: I 3.0min I I I -----------~---of--------------of-----------------f I 4.0mln I I I "-------------..1---------------..1----------------_& ! 5.0min ! ! ¡ ..---------------~---------------...-----------------t ¡ 6.0 min ! ¡ ¡ r---------------"I---------------"I-----------------' I 7.0 min I I : ------------;----of---------------of----------------f I 8.0 mln I I I L______---------..I---------------"---------------_& ! 9.0 min ¡ ¡ ¡ t----------------..---------------...----------------t ¡ 10.0 min ¡ ! ¡ r--------------,---------------,----------------, I 15.0 min I I I ------------,;,---of---------------of----------------f I 20.0 mln I I I 1---------,,:,---1--------------1-----------------t I 25.0 mln I I I ..------------..---------------...---------------t L-~Q.:9.._~!~_J_-------___--_L__-_--------_J NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Doyon 19 I Date: I 12/31/2003 I Volume Input I Pump used: I Other - See Commen~. Barrels ... .. Pumping down annulus. .. ~ Casinc Test , Pumping Shut-in Bbls psi Min psi 0 1 2 3 4 5 6 7 8 9 10 15 20 25 30 Well Name: Drilling Supervisor: CD1-229 I Rig: I David Burley Type of Test: Annulus Leak Off Test for Disposal Adequacy Hole Size: USE PICK UST I. Casing Shoe Depth I RKB-CHF:I 1Ft 3,260 1Ft-MOl 2,3851 Ft-TVD Casina Size and Description: 19-5/8" 40#/Ft L-80 BTC ChanQes for Annular Adequacy Test :>uter casing shoe test results in comments Description references outer casing string. ;ize is that drilled below outer casing. itimated TOC for Hole Depth. Enter inner casing 00 at right Hole Depth 10,252IFt-MD I 5,776IFt-TVD .r Pressure IntearitvTest Mud Weight: 6.8 ppg Inner casing 00: 7.0 In. Desired PIT EMW: Estimates for Test: 15.0 ppg 1017 psi -1 bbls I. .1 EMW = Leak-off Pressure + Mud Weight = 925 68 0.052 x TVD 0.052 x 2385 + . EMW at 3260 Ft-MD (2385 Ft-TVD) = 14.3 1000 . (/1 w çS a: Þ ~ Z ~ 52.- w m a: 0 Q. a n ->1 1'..) c:> c:> ~~ 0 0 2 3 Barrels 4 5 ---CASING TEST .....-- LEAK-OFF TEST Comments: Used Hot Oil for pumping Initial 9 5/8" casing shoe LOT = 15.6 ppg PIT 15 Second Shut-in Pressure, psi 900 "-,,,u_J 6 7 0 5 10 15 20 25 Shut-In time, Minutes 0 PIT Point Pump Rate: 0.5 Bblfmin ~ BblsfStrk ... 30 Pressure Integrity Test Pumping Shut-in Bbls psi Min psi 0 150 0 910 0.2 180 0.25 900 0.4 190 0.5 900 0.6 190 1 890 0.8 200 1 .5 890 1 210 2 890 1.2 225 2.5 880 1.4 260 3 880 1.6 310 3.5 880 1.8 380 4 880 2 500 4.5 880 2.2 670 5 870 2.4 820 5.5 870 2.6 925 6 870' 2.8 925 6.5 870 3 920 7 870 3.5 920 7.5 870 4 910 8 870 4.5 910 8.5 870 5 910 9 870 5.5 910 9.5 870 6 910 10 870 6.5 910 Volume Pumped O.Ol:sbls Volume Volume Bled Back Pumped J I:5bls. 6.b I:5bls Vo ume Bled Back J I:5bls WElL DIIT AILS Name +NI-S +'EJ.W Notthing Easting ANTI.COLLlSION SETTINGS COMPANYOOI'AILS ConocoPhillps Alaska Inc. ~ Laritnd. Longitude Slot Interpolation Method:1VD Interval: 1.00 Depth Range From: 2350.00 To: 2400.00 MaXÌlDlm Range: 1320.00 Reference: Definitive Survey Calculati>n Method: Minimøn C""",= =~= ~%~JPIone w'=;f:=:.t ~~åt& CDI.229 -200.78 -194.78 5975707.140 385802.200 7!1'20'32,947N 15!1'55'36.558W NlA -1320 -1240 -1033 -827 -620 -413 -207 -0 270 -207 -413 -620 -827 -1033 -1240 -1320 Ç)¡ ,-- 0 IJ20 180 B¿,u Reference Azimuth Angle [deg] vs Centre to Centre Separation [ft] WELlP Am DIIT AILS CDI-229 Drilled from SIo'29 Pmn+::~~ CDI-229PBl 10161.00 Doyon 19 CDt-22</: 56,05 Rig: Ref. DolDm: v.~ ~ +~ Illon' 8.&3 90 ð.œ 56.0511 ~~rom ~JJ 0 300 400 500 750 1000 1250 1500 1750 2000 2500 3000 3500 4000 4500 5000 5500 6500 7500 8500 9500 10000 10500 11 000 12000 Co our ToMD 300 400 500 750 1000 1250 1500 1750 2000 2500 3000 3500 4000 4500 5000 5500 6500 7500 8500 9500 10000 10500 11 000 12000 13000 1/4 Mile Radius of CD1-229... 9-5/8" Csg Pt (@ 3260' MD /2385' TVD) SURFACE CASING SHOE SEPARATION FROM CD1-229/NQ1 CD1-229/NQ1 x y Surface Casing Shoe ASP 4 Coordinates: 386239.91 5973899.61 ~urtace ~urtace ~unace csg. Details @ Permit Distance from Shoe csg.Shoe Shoe Y Wells AOGCC? Permit # Date Object well* TVD X Coord. Coord. CD1-01 y 399-116 7/12/99 2233 2364 386000.88 5976120.23 CD1-02 2214 2398 386406.59 5976107.32 CD1-03 Y 300-005 1/13/00 2757 2370 385744.09 5976611.32 CD1-04 2743 2377 386800.96 5976584.44 CD1-05 Y 300-022 1/27/00 2251 2387 386752.76 5976091.39 CD1-06 2385 3090 387261.90 5976054.67 CD1-07 Y 304-047 2/19/04 1797 2362 387324.34 5975332.78 CD1-08 1786 2373 387790.00 5974786.00 CD1-09 Y 300-163 6/22/00 2451 2790 387400.42 5976058.56 CD1-10 Y 2120 2403 386080.76 5976013.75 CD1-11 CD1-12 CD1-13 Y 399-121 7/19/99 1970 2387 386333.24 5975867.57 CD1-14 2495 2366 388120.50 5975539.11 CD1-15 CD1-16 Y 399-213 11/2/99 1694 2399 386666.50 5975539.37 CD1-17 1657 2385 386386.08 5975549.67 CD1-18 CD1-19 Y 399-064 4/20/99 2974 2393 386182.40 5976873.16 CD1-20 CD1-21 Y 304-009 1/12/04 2848 2391 385033.54 5976479.08 CD1-22 Y 1887 3110 385890.63 5975753.64 CD1-23 Y 399-141 8/5/99 2056 2398 387499.21 5975525.36 CD1-24 1850 2390 387001.62 5975585.79 CD1-25 Y 300-102 4/17/00 1373 2398 386816.46 5975145.40 CD1-26 1109 2389 386511 .26 5974974.98 CD1-27 Y 300-058 3/22/00 921 2366 386148.85 5974816.28 CD1-28 Y 1905 2372 385780.25 5975747.82 CD1-229 0 2385 386239.91 5973899.61 CD 1-30 Y 2700 2387 384814.85 5976193.13 CD1-31 Y 300-263 11/24/00 2319 2378 385054.61 5975893.22 CD1-32 Y 399-245 12/9/99 2435 2413 384754.69 5975829.24 CD 1-33 Y 1808 2430 385796.34 5975652.73 CD1-34 Y 300-133 5/8/00 1642 2361 385543.31 5975386.66 CD1-35 Y 399-086 5/21/99 1869 2388 385634.65 5975667.79 CD1-36 Y 399-260 1/3/00 2021 2406 385189.14 5975626.4 7 CD1-37 Y 399-162 8/27/99 843 2409 385828.32 5974635.64 CD1-38 Y 300-051 2/29/00 955 2376 385516.01 5974522.02 CD1-39 Y 399-181 9/1 0/99 1250 2388 385568.87 5974954.54 CD 1 -40 Y 399-101 6/11/99 1316 2392 385005.59 5974356.58 CD1-41 Y 300-1 04 4/24/00 1892 2394 385231.03 5975499.87 CD1-42 Y 399-261 1/3/00 2173 2384 384596.37 5975321.88 CD 1 -43 Y 300-241 9/20/00 1786 2386 384753.45 5974889.55 ~ C) CD1-44 Y 300-146 5/31/00 2141 2375 384506.22 5975155.17 C,) C"J CD1-45 Y 299-233 11/17/99 1911 2385 384726.63 5975067.43 ~ CD1-46 314 2360 385979.18 5974074.56 ~ - CD 1 -47 t- ü CD1-48 0 CD1-49 0 W * Lateral distance in feet, between surface casing shoes, in the X- Y plane, assumes similar TVD Z Z « Note that this sheet is not the definitive record () <I) Note to File CD1-229/NQ1 Colville River Unit (Alpine) (200-215...304-383) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Approximately 150 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 101 % XS of the calculated hole volume. --On the initial leak off test, the formation broke at 15.6 EMW. A few strokes were pumped in at 15.0 EMW. The pressure declined slightly during the observation period to about14.2 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole. The 7" casing was run and successfully cemented. The 7" was initially reciprocated through the initial stages of the job, but became stuck prior pumping the cement. No loss of fluid was reported. --An injectivity test down 9-5/8" x 7" annulus was conducted when the well was drilled in January 2001. Pressure steadily increases until the break at 14.5 EMW. Pump in was steady at 13.5 EMW. During the observation period, the pressure declined to 12.5 EMW. CPAI has recently performed an injectivity test down the OA. In this most recent test, steady pump in occurs at about 14.3 EMW. After shut down, the pressure slowly declines to about 13.8 EMW. The lower EMWs of both pump in tests indicates 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 ~ mile of CD1-229/NQ 1. There are a total of 7 wells within ~ mile of the surface shoe. The nearest well is CD1-46 about 314' distant. An evaluation of the surface casing cementing operations indicates that CD1-46 was satisfactorily cemented. The remaining wells lie between 840' and 1310' distant. All but one has been approved for AD. An examination of the files did not reveal any problem that would preclude granting CPA's request for CD1- 229/NQ1. Based on examination of the submitted C~OCOPh,i,IIiPS' request for the subject well. ;ër~ ~,,: '^ -'"1 0 Tom Mau~d'e~, ~--v( Sr. Petroleum Engineer October 21,2004 G: \common \tommaunder\ Well Information \By Subj ect\Annular Disposal\041 021--CD I- . 229.doc SCANNE.D OCT 2 7 2.004 information, I recommend approval of ~~ rr/~ fUr. rE¡ c: (f\ì ~ Æ\ f¡1 ¡',r:ñ\ ~'~,~ ~') ~ r I , r I ¡ I!! ¡ """'" \ i ¡.--c \ ï' , ¡ l Uu U ! L~ ~u LJ UbU LJ.~j FRANK H. MURKOWSKI, GOVERNOR ATfA~1iA. OILAlQ) GAS CONSERVATION COMMISSION 333 w. -¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska 700 G Street Anchorage, Alaska 99501 Re: Alpine CDl-229/NQl Sundry Number: 304-383 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. Approval of this request does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annulus of a single well or to use that well for disposal purposes for a period longer than one year. 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. / BY ORDER OF THE COMMISSION DATED this~ay of October, 2004 Ene!. SCANNED OCT 2 7 2004 OCT-22-2004 13:21 ALPINE ANCHORAGE 907 265 1515 P.01 ... f ConocJPhillips Alaska, Inc. I:NE FROM: FACSIMILE TRANSMITTAL SHEET ..._?2.. ~ (!;><:--r- °1 - . ];.A1 ....~C(ÞVÞE.t< .rE: 7t; .. -¡ çr;L .-. .... /!::.te# .. To /Hv5ti)V tL. '0 1- ..;¿" -~ - 6' (3~ I daa~~\s- DATE: TO: FAX#: c~ \ - d-d-~ Notes: -- ., Ð """ ...~ f~ç~ Se.e fL /r> <> (..~) ¿"sj7l> 'h / re(..~s 4v cDt-1\) ~ ( (COf.22"1). f lec.$ c.. ;~ C ~)t.. f~~ ,~<:ðý;~ ~;IC It~ c:'t Þ? ...., c..,. t ,. J. ;Sf~ <;... ( ... /' /' Ii (. c>'¡'~ /;, CDI... /VQr . T h.C^ Icr ~~ <- NO. OF PAGES FOLLOWING COVER: J ~3~.L. <'{.-'~ Fa,,: (907) 265-1515 Phone: (907) 263-4414 1700l 6 ll:JO a3NNV~S (J) ~. z z m Q.. 0 ". <:) 0 u n - --I .-t ~ ". ~ 0 ,......, - C) ~ 0 OÞ> C to ,..., r CONQCOPH1LLlpS..DAfL Y ANNULAR ~NJ~CTION R~CORD 'R!G #~ l HOT-þll, 'I DA TE :12131/2003'-'0 12131120{)~ PAGE._., Injecting into annulus of well: I: - 9p,1::N 0-1 .\rI \, I 1.. ..of 2 , J 1800 HRS 100D HRS , ,- ¿ \. FOR MUD aNt y ': - : ' '>UMP , S~aUç ~ In~c.\~11 OJlCllilliM fhill i, ongl~ Of Start Stop 1ATE Ple&fiure Pte&iUlflt, ç"~.r$ØW&~1 Au.ds I Time TIme ~BPM)¡ (PS1~ ~ {PS~, MUD 0935 I 095'0, 1 ' 475 ." 920 BARRELS INJECTED ( Lisr under Prop &¥ fluid Typ e) .WÃTER for .DlÊSE.l1cr . MUD ¡ ¡:~uSihin9 . Fre~<':8 : OTH~R Annulus ¡ PlofeC4i!1g ~ig Wash Wa(et', (S~lfy) . . ...,. . 7 Comments ~ KU1P TOTAL , CummUlalwt" :WEright I Funne1 . Volume" (PPG) ~scos'ty. , - - - -. - t. 7 ,6.8 2,f LOT ~ I: . " .. - . .irrrrr..-I. 1- . . Vt/ -'" . v ~ -- ,. - I '... f , ...- . , ~ ., ~. - . , , ~ - -'-~ ... 'I ~ " - - . ~ ' ~ "I þ- ,I ß -...... , J\ .. ,. \ - u,' ,"I " . - ! -- , Y.' '~ .;., - ---... . -II... .'-1 If - ... - ir ,1¿ u- v'--t. oJ -- "\. .-.... ... f ' I , I 1 . r - , \-1#\ ", r ~ , I . - - . ....,¡ " .' -. ~, .- ! ., . ! ~ - MUD . . '1 ¡ TOTAL FOR; CummtIlativ~ rotal New Tatal for this WATER ctESEl WASH WATER OTfo/ER TODAY' from PreIJiOU5 Day AnnUrU3 TOTAL VOLUMES FOR DAY: ¡ ADDITIVES USED: ~ Gel NlGHTS " r i' J-' '... ; 409 a-GEL X-TN 0 7 I \" -. - "'mCARB i PH6 , . - 402 ; J, , ; DAYS r~~ INJE.cnðtlsupE:R'I,I}SOO 1./ ~ ;- - -.--- Y'" J ~ ") I ØAYtN'JI:.ÇTIOtfSUP!:A;1JI~. I. ,~ ;, L r ¡/J~Jtl '- ./1-"1 ,. "'" - ..., I ~IOÆCOO"~P"vl~þ(. .-ll t.,.¡oc°t'"~oo~ ,,~ 0 () ~ -; - I I\.) I\.) I I\.) IS) IS) .c:.. 'I f-'- 0J I\.) f-'- ", D r -0 ...... Z m D z () I 0 ;u D Q m ¡. \..D IS) --J I\) m Ul f-'- Ul f-'- Ul I LJ (S) I\) -.: N "'" C) ~ ..þ, PPÇQ,.pAI"'YNf~ULAR INJEqlQt,I ~CQ1tQ ! u'" ""'" -- RlG.1k r'f),~El.s J DATE 11231200{ 10 "'11'23i2õô:ï: PAGE 1. of 2 ~ 7g into .nnul~. óï~il:-r ðÖ1-N,af. f'" -~-, - - --- ~ .. ~" .~ ì«,HR8_-- .,~: -> t~~ " -... -~ ~.- ':~~.- ~ .~ .' , -. - '-'hl- "1.- . . ~ - '" - ,." - ( - - a: 8AlfREtS1lIJi:.c;,eU I ,FOR"UØ ONI..Y i' N f UIt u,,* PlDlWIIrdd r¡pøJ . :':,' " - ~"'-1Idc ..~.,.' ~ ' . - . - '~'.. ~WAteRfor-œSt:L~ À," -' -" -' \'- .!.. f~ Start,Stop :tAT&'AMan Pr_':-v::. ~MUD I FMtin9 ,FfetU ' :. OTHeR : T1me 'ßme~) (1'64), (P8) ~ AntØa ¡iFfofdQAlgWMhWaterl (Spadf) .'-' '" ~...- . - 'f-." I . .- - . - -\.011' . -. .' .,. - - - ~ - -" ". .. -, ~ 03:25: 03:49..5 150.. 450 FfØéZ8: 12 , 'I iJ L - ~ V.W '" -, ~, .., . Ir' - ;04:01 '05:18' " ,'425 1094 t freeze ~ 306 Ø7I -.,. .~, ~', I, '.. \.. ," - \.rIA ... -- ~ '05:20' 05:53, 2.2 aoo.; eeo Fre&ze ,. I "ï n ' - ~ _A' t .' V' ./ ~ I ;r ~,' \'-,! VI ~ C3 . c» 'ulM. ".-' ,-... -~ Cumm"-' ,W.Jtht fUnnef co ...... . Vøbtte {PPG} :'~" mmel'~ , '12 ~ 10.2~ - 41' 'fnjecllvity Test - K' -, , ,. - .... .,- -- - .. -- ~I' A""" , " , ,-- , 305 8~3. 26 t~1uihJ Teat !, , .,. \, ' ..- .. urrw;n,~"J ' ¥' ,~~..."~ 15 6~B" 24 ! Freeze Protect ~ -, ! ./ 6\' '\ J I v 75 " 'I , u(' ¥ "\ . ~ .~ I f , - ' . .X .,- .. ,,- 04 '\'~ " ~ ,- ..,- ¡'-,. ~. - . \ 'W A ! '" \., , 'V - '.~ .. - 'I! " ., A'- -.. If ...~\V - .¿ ". ,- ' ""IIOf' -.:.: , , ~ ( I' , )If, ~ \, - , --.. \ -~-~ - .Jur .. ~ . "1:",....- -uJ '-.- , ~ I " ' .' ~ -. .. ~--X"'.' / - I' r ~ I ' -1MX''' , IIIl ¡', ", . I fI ,. -, ~_.... ..I~ " ,.Au ~¿¡(' " J _I I. "I.' ,- ,.,...., - ., r- , '! n, - J '~ ~ ¡ -~ ~ . ~ ~ " J ~, -v- " AT "'I' - ---., ~ \Jt1r.. , J ;" -.. ï ~-' ..".. f -- ~ ~ 1.' v , ,,,,J - ~ ' ¿ '" ,..".,. ~ 6 ... - 4 .It. .... , 'ur'" . u, - , - \ - ,~. . \ -,,-- ¥- , ... III " '.. ":,A\'W (f) ('j » :z z m 0 0 (,J -----i ð r ~' ~-_f: Ld ~ ')i n. . -J < 1:' n ... I.L. ~ - : --, \Yr.:! - - 1¥{ n !' . ." - I ..~' ÞX ~.. ~ j 1'" I r ~ u, " ' -I ~ E 'AI t '" "iI.1 ..¡ , 1 ' A"\- -' .., '6'- - 'ac " .-." - '\I - . ' ::t W" '~- ~ ~ \.J ..... " ... ... MUD X' ~ L '-~ A - 4 ,~" I " .,. -" '..., ~ .. . ~ ~ I ..- u ' I'" ,... ~, 'I' .. TOTA1. FOR ~lsI!ve TotaJ TODAY: from PreWoti. Day \'...' , ,.,-" 392 - 0 ~ - "" ~ . .. ! ~ . \ WATER IM8Et WAaflWA'ÆR OTHER TOTAL VOLUESFOR DAY: t - 12 "], ~5,',.I, .:!5~ \r J: ~'V ~J- .- , ,Q.Ga_a ~- X~lND 'DRB .. ~6 ~ .' -N v an c:t PHS '" 'II"' -" GEL' ' ADomvES USED: - ÑtGtiTs --1 ~ ' L I ~- ' ,,>V \. UI \<' _....~ ...1 '.. ~ ¡;' - -- . ~ - - ~-- ..... 8:) ~ C\4 !: DAYS: I ~ ~ t ~ ~-' 0\ ...- -.u \ .' , 't '-I-~' '" ,v. .,. n -~.. '-,,,,--- '# - ,J ..- ~~., , ,-' - 'j{'.' "~) ,-: , ~~~ . 5~ cMlNlECœN~ -, -' - iWX)~ . - ',~ JI'- .'L ..- wl!fJ . ... ,. ,. ,,~.,A.. L x ..\6h4}. ~.If^ \ -- -,.. ~ , 'I.' ¥ " - '" , '., JJ( .. ,- '''.\ - 'J v---~ I New TOIaI for (his J AAMs 392 \ '- ... - v "I ~. . -... ..-.. 0 n -I I '. ~ J I\) (S) (SJ A f->- 0J I\) f->- ,..; ~ f D r -0 ....... Z m D Z n I 0 ÃJ D G1 m .. " .. of ... ill (SJ --J I\) m U1 f->- U1 f->- U1 ""U (S) 0J CONQCO PtiILLIPS-DA1L Y AN NUlAR INJECTION f(ECORD RIG #~ (' !10T'Ollf DA TIE 12130/2003'0 12/30120°4 PAGE Injecting into annulus of well: r CD.1-NQ1 , ,. . L ~ . -.' , 3UMÞ St.atio' InJecUort OpeI41ÏCIII !hat : Ongln Of Start: Sto p ~A TE. Press.ure, PreSSiJre (let'lsmed Waor.1e , FMds . Time '¡Time 'BPM) (PSI); {PSI} ~D KÜTP 2244. 2255~. 1 -~. 475 ,. 1350 r ¡, . )' ~ ' .---~ .. " r ,. ! ; en () ~\\ ~ Z m 0 a.. v c::>V C")u -Ø'J 0 -.:f ~ ~ ,¡lGm tlJEC'1CN SUPEJlYISOR . ..,., (J . . U IJ¡ . (S)Q -Þ>. i . I¡ ~ TOTAL VOLUMES FOR DAY: ADDITIVES USED; 'NIGHTS I . DAY'S , ~ÿ INJECTt014 SUPERVISOR . - .. -.. ~ . v- BARRELS INJECTED ( usr under PropsT nJJid Tvpe) , ~WAtER for OfESElfcr 'MUD' Fiushin.g ',Freeze OTHER Ann.ulu5,Pr((ecling iig Wash Water (Specify) - 1G 'I ' I. I ')1''''. ...........: \ , - , i .. , I MUD WATER DIESEL WASH WATER OTHER l ,,' J r , i . 10 GEL Q-GEL flCÄRB ~-TND .. " ~ , ~ ;1 ,.of 2 FOR MUD ONLY' TOTAl - CtJmmulslNð Weight Funnel Volume' (PPG) VisCGsity Comments {O ~ 6.8 ' ~24 ~njectMty Test - j ; -', ., '--. . n .... j --- , '.J '" -~ ~ ',," ~ ... TOTAL FOR Cummufative Total TODAY. from PreVious Day, 1 0 ~ 392 New Total for ""is Annul us 4G2 ITHS ì " , ,- - - ~toJJECTlmf5UPERVSOJl.~ß- .. . C!JNOCO~~jPSns ; RVISOR I'¿ E.- ~ i Æ.. '), r 1 / ~~(..~ - -- - -. -" - , ~.. ~.r--. 7 .. - .., ¿\ ~ 0 () -; I I\) I\) I I\) (S) (S) -Þ>. ~ tAl I\) ~ D r lJ ....... Z m D z () I 0 ;0 D C) m IJ) lS) -(J I\) (J) V1 ~ V1 ~ V1 lJ (S .þ. Permit to Drill 2002150 MD 16118 - 'rVD DATA SUBMITTAL COMPLIANCE REPORT 411i2003 Well Name/No. COLVILLE RIV UNIT CD1-229 Operator CONOCOPHILLIPS ALASKA INC 6165, Completion Dat 2/3/2001 '"" Completion Statu 1-OIL Current Status 1-OIL APl No. 50-103-20358-00-00 UIC N REQUIRED INFORMATION Mud Log N.._.Qo Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No FINAL ray RES 2/5 FINAL rray RES 2/5 FINAL ~D A.D N ~) V~ [ 2 FINAL 9932 FINAL Directional Survey FINAL I~D A D N ~t ~ I 2/5 FINAL ~'VD CDR '~ ~ ~ 2/5 FINAL Directional Suwey~ FINAL C L L L t.~ 'Well Come/Samples In[ormafion: Name (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop OH I CH 3260 3250 3250 -5260 3260 3260 3260 3260 3260 16118 16072 16072 16118 12471 12638 12471 12638 12698 oh oh 3/2312001 oh 3/23/2001 Open 3/23/2001 Open 2/26/2001 oh 2/2612001 oh 2/26/2001 2/2212001 oh 2/2612001 oh 2/2612001 ch 2/2612001 Dataset Received N. tu m~l~ r 3/23/2001 C1~)005 Comments 3260-16118 Digital Data ~ ~,~,~ 3250-16072 BL, Sepia 3250-16072 BL, Sep)a 3260-16118 ~~ 3260-12471 3260-12638 BL, Sepia 3260-12471 Digital Data It Dir Survey Paper Copy 3260-12638 BL, Sepia 3260-12698 BL, Sepia Directional Survey Paper Copy Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y/~ Chips Received? ~ Analysis ~ R ~.r.~.iv~.d ~ Daily History Received? Formation Tops Comments: Permit to Drill 2002150 DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. COLVILLE RIV UNIT CD1-229 Operator CONOCOPHILLIPS ALASKA INC APl No. 50-103-20358-00-00 MD 16118 TVD 6165 Completion Dat 2/3/2001 Completion Statu 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: Date: PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE. ALASKA 99510-0360 February 21,2002 Mr. Mark D. Myers, Director of Division of Oil and Gas Department of Natural Resources 550 W. 7th Avenue, Suite 800 Anchorage, Alaska 99501-3560 RECEIVED f. ~.~ .,, RE: Nanuq CD1-229 (CD1-NQ1): 10 Month Status Report Dear Mr. Myers: The DNR's approval of pilot production from the Nanuq CD1-NQ1 well, subsequently renamed CD1-229, required a status report of operations conducted after 10 months of pilot production. The purpose of this letter is to document the status of operations during this reporting period. Pilot production at Nanuq CD1-229 began on FebruarY 11, 2001. All well tests recorded since the start of.pilot production and during the reporting period are shown in Table 1. Significant well operations conducted since the start of pilot produCtion are summarized in Table 2. The only significant event during the reporting period was production testing and sampling conducted on July 20, 2001 to acquire stock tank oil samples for laboratorY displacement experiments. The well has been shut-in since that time pending completion of ongoing development studies. Drilling and subsequent production testing at the Nanuq CD1-229 well has confirmed a significant hydrocarbon accumulation. Subsurface development studies are underway and additional delineation drilling is planned with the drilling of Nanuq #5 this winter. The commercial viability of the development is uncertain pending the additional drilling results .and subsequent evaluation activity, As you are aware the owners are pursuing a unit expansion and have proposed associated commitments to delineate the' Nanuq accumulation. An application for a Nanuq participating area is not imminent and would only be pursued after, 1) delineation drilling and development studies confirm a viable development project and, 2) permits are apprOved that would allow for construction of facilities. At this time, Phillips Alaska, Inc., as the Operator, is not requesting continuation of the pilot production at the CD1-229 well. Sincerely, Eric W. Reinbold Sr. Staff Reservoir Engineer cc: M. Ireland- Phillips Alaska, Inc. D. Rodgers- Phillips Alaska, Inc D. Soria- Phillips Alaska, Inc J. VVinegarner- Phillips Alaska, Inc C. Lively- Anadarko Petroleum Co. Teresa Imm- ASRC ~ Commissioners- AOGCC. Table 1 - Well tests recorded during reporting period Test Well Date Ftp Wht Time psi De,IF hrs CD1-229 02/11/01 205 50 8.3 CD1-229 02/12/01 197 51 6.0 CD1-229 02/12/01 196 51 6.0 CD1-229 02/13/01 195 51 7.0 CD1-229 02/16/01 198 50 20.1 CD1-229 02/18/01 197 49 4.9 CD1-229 02/28/01 195 44 14.0 CD1-229 03/08/01 204 41 22.0 CD1-229 03/11/01 200 12 14.8 CD1-229 03/20/01 214 44 7.2 CD1-229 03/23/01 200 47 7.2 CD1-229 03/30/01 189 46 6.1 CD1-229 04/12/01 213 50 6.8 CD1-229 05/08101 204 46 7.7 CD1-229 05/09/01 202 47 5.0 CD1-229 05/10/01 202 47 6.0 CD1-229 07/20/01 196 45 12.0 Oil Rate Water Rate Gas Rate Water Cut stbld stbld Mscfd % 463 114 6493 19.8 428 26 5972 5.7 412 18 5839 4.3 384 12 5628 3.0 362 7 5588 2.0 335 5 5415 1.4 303 1 4827 0.4 288 1 4661 0.4 175 0 2722 0.0 415 1 7058 0.2 387 5 5793 1.2 297 1 4931 0.5 330 0 6594 0.0 372 0 5413 0.0 343 0 5231 0.0 334 0 5118 0.0 517 0 4473 0.0 Gor scflstb 14012 13958 14167 14644 15440 16170 15910 16187 15596 16989 14965 16589 19968 14535' 15248 15344 8654 Table 2 - Well events during reporting period Date 2/05/01 4/16/01 6/28/01 7/20/01. Operation Initial Static Pressure Survey CT Production Log Pressure Build-Up Test Production Test and Sample for'Laboratory Studies PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 April 25, 2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED 0 ! 2001 Alaska Oil & ~.~s Cons. Commission Anchorage Subject: CD 1-NQ1 (200-215) Completion Report Dear Mr. Commissioner: Phillips Alaska, Inc., as operator of the CD1-NQ1 well, submits the attached "Well Completion Report" (AOGCC form 10-407). Other attachments to the completion report include the directional survey and report of daily well operations. We will send under separate cover the logs, the mud logs, and other well data and reports. The Commission is requested to keep confidential the enclosed information due to the exploratory nature of this well. If you have any questions regarding this matter, please contact me at 265-6120 or Scott Reynolds at 265-6253. Sincerely, G. C. Alvord Alpine Drilling Team Leader PA1 Drilling GCA/skad STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ~] Gas El Suspended D Abandoned r~ service [~ Producer 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 200-215 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 1~ 50-103-20358-00/50-103-20358-70 4. Location of well at surface ~la~=~ ~ 9. Unit or Lease Name 422' FNL, 2377' FWL, Sec. 5, T11 N, RSE, UM (ASP: 385802, 597570~) t ~'""' '": :~'": ~~ Colville River Unit i ...-~z ,; 10. Well Number ~ At Top Producing Interval~ .2.. ~ ~'_~ ~ 3735 FNL, 4198 FWL, Sec. CD~ & CD1-NQ1PB1 ~,~ 8, T11N, RSE, UM (ASP: 387518, 5967092), "' i'i'. L','i ~7.:.; ~ ~ ...... At Total Depth i '~'z"'" [ - 11. Field and Pool 1890' FNL, 741' FWL, Sec. 17, T11 N, RSE, UM (ASP: 384021,5963708}'Z--':'i~':.Z':~-TZ,~7~~: Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 36 feetI ADL 25559 / ALK 372097 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions January 6, 2001 January 30, 2001 February 3, 2001 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 16118' MD / 6165' TVD 16118' MD / 6165' TVD YES r~ No r~I 1906, feetUD 1688' 22. Type Electric or Other Logs Run GR/Res/Dens/Neu 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT. PER FT. GRADE TOP BoTroM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" lO cu yds Portland Type 3 9.625' 40# L-80 Surface 3260' 12.25" 591 sx AS III & 231 sx Class G 7" 26# L-80 Surface 11283' 8.5" 187 sx Class G 3.5' 9.3# L-80 11110' 15958' 6.125" N/A CD1-NQ1 PB1 cement plug dressed off to start CD1-NQ1 sidetrack 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 11122' 11100' Combination slotted & blank 3.5" liner from 11148'-15958' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12439'-11749' Plug #1:235 sx 15.8 ppg Class G 11310'-10735' Plug #2:196 sx 15.8 ppg Class G 10821 '- 10234' Plug #3:227 sx 17 ppg C lass G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 11, 2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 2/18/2001 4.9 Test Period > 68 1105 1 95I 16170 Flow Tubing Casing Pressure Calculated .OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press. 197 Psi 560 24-Hour Rate > 335 5415 5 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED MAY 0 1 ?_.001 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 0 R 161NAE"'""'" 29. ~,.. so. GEOLOGIC MARKERS FORMATION TESTS NAME Include intewal tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Nanuq 11247' 6181' (@ heel of Horizontal) Top Nanuq N/A (@ Toe of Horizontal) 16095' 6166' 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hAreby certify that the following is true and correct to the best of my knowledge. Questions? Call Vern Johnson 265-6081 Signe (ii ~/_~,_~ ,/'~.,,~ ~.~ Title Alpine Drillin.q Team Leader Date Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Rpt No 1/6/01 1/6/01 1/6/01 1/6/01 1/6/01 1/6/01 1/6/01 1/7/01 1/7/01 1/7/01 1/7/01 1/7/01 1/7/01 1/7/01 1/7/01 1/8/01 1/8/01 1/8/01 1/8/01 1/8/01 1/9/01 1/9/01 1/9/01 1/9/01 1/9/01 1/9/01 1/9/01 1/9/01 Operations Summary ( .... CD1-NQ1 Comments Prep cellar for rig move Move rig f/CD1-33 to CD1-NQ1 and rig up N/U 20" Hydril, riser, flow line, diverter valve & line, and other misc. rigging up M/U BHA #1 - orient MWD,motor, & UBHO sub - had to thaw out torque gauge and rotary table Attempt Diverter drill - Hyddl wouldn't close completly - work Hydril & heat up Hyrdil with steam - Diverter test ok - Witnessing of test waived by Lou Grimaldi AOGCC - Pre-spud meeting with rig crew Thaw hole fill pump - fill hole check for leaks Break circ. - Spud-in - Drill 12 1/4" hole f/114' to 265' (261' TVD) ADT .9 AST .4 Drill 12 1/4" hole f/265' to 626' - AST 2.3 - Monitor well - Blow down TC Pull out - Adjust AKO f/1.6 to 1.4 - Orient Service top drive Problem with top drive air pump for hydralics - repair Slip & cut drill line 60' R IH to 535' Thaw ice plug in mud line between pits & sub Break circ - Wash F/535' to 626' - Drill 12 1/4" hole f/626' to 1144' - 1116 TVD - ADT 2.8 AST 2.0 Drill 12 1/4" hole f/1144' to 3270' - 2390 TVD Pump hi vis sweep - circ hole clean. Monitor well - wiper trip f/3270' to 1670' Pump hi vis sweep - circ and condition mud and hole for 9 5/8" csg Monitor well - pump dry job - blow down Top Drive Pull out to run 9 5/8" csg - hole in good condition Handle BHA - std back HWDP, I std. DC - L/D UBHO, stabs, MWD,Pony DC, motor & bit Clean up rig floor Rig up to run 9 5/8" csg PJSM - Ran 78 its. 9 5/8" 40# L-80 csg w/FC & FS - P/U landing jt. & land w/shoe @ 3260' MD - 2385' TVD Circ & condition hole & mud for cmt job - L/D fill up tool - M/U cmt head & lines - Continue circ PJSM - cmt. 9-5/8 csg - 40 bbls Viscosified water - test lines to 2500 psi - drop btm plug- 50 bbls Arco spacer @ 10.5 ppg - mix & pump 591 Sxs (467 bbls) lead slurry @ 10.7 ppg - 48 bbls tail slurry @ 15.8 ppg - Observered nut plug marker @ 450 bbls lead - drop top plug w/20 bbls water f/Dowell - switch to rig pumps - displace w/224 bbls mud - didn't bump plug - floats held - CIP @ 1530 hrs. L/D cmt head & landing jt - flush 20" hydril with water 1/9/01 1/9/01 1/9/01 1/9/01 1/10/01 1/10/01 1/10/01 L/D csg equip. PJSM - N/D 20" diverter - install FMC Unihead - N/U BOP stack - flow line, turnbuckles Install test equip.- PJSM testing BOPE Test BOPE - test hydril 250 psi Iow & 2500 psi hi - choke valves 250 psi Iow & 3500 psi hi Continue testing BOPE - Pipe rams, Blind rams, all valves to 250 psi Iow & 3500 psi hi - Test wavied by Lou Grimaldi AOGCC R/D test equip. Install wear bushing Install bales, elevators, M/U 8 1/2" bit, b/s, xo - prep to P/U 5" DP ., CD1-NQ1 1/10/01 1/10/01 1/10/01 1/10/01 1/10/01 1/10/01 1/10/01 1/10/01 1/10/01 1/10/01 1/10/01 1/10/01 1/11/01 1/11/01 1/11/01 1/11/01 1/11/01 1/12/01 1/12/01 1/12/01 1/12/01 1/12/01 1/12/01 1/13/01 1/13/01 1/13/01 1/13/01 1/13/01 1 / 13/01 1 / 14/01 1/15/01 1/15/01 1/15/01 1/15/01 1/15/01 1/15/01 1/15/01 1/15/01 1/16/01 1/16/01 1/16/01 1/16/01 1/16/01 1/16/01 1/16/O 1 1/16/O 1 1/16/01 RIH to 2864' -picking up 5" DP from pipe shed - 90 jts. Circ and condition mud for csg test R/U to test csg - Pressure test 9 5/8 csg to 2500 psi for 30 mins. - ckmetal to metal seal on unihead OK - R/D test equip. Pull out w/5" DP for std. back in derrick P/U & RIH w/21 jts. 5" DP - pull out & std back in derrick M/U BHA # 3 - RIH to 363' - test MWD - RIH w/HWDP to 1105 RIH f/1105' - P/U 5" DP f/shed - tag cmt @ 3168' (7/0 cmt f/3168 to 3177 - drill FC @ 3177 - (7/0 shoe tract - drill shoe @ 3260 - (7/0 rat hole to 3270' - drill 20' new hole to 3290' Circ & condition mud for LOT Perform LOT to 15.6 ppg W/9.6 ppg mud Change well over to 9.6 ppg LSND mud Drill 8 1/2" hole f/3290' to 3479' - 2492 TVD - ADT 1.1 hrs. Drill 8 1/2" hole f/3479' to 4812' - 3122 TVD - ADT8.2, AST.4 Pump hi vis sweep & circ hole clean for wiper trip Monitor well @ 4811' - wiper trip to 9 5/8" shoe - monitor well @ shoe - RIH to 4716' · Break circ - safety wash to 481'2' - circ btms up Drill * 1/2" hope f/4812' to 6049' - 3745' TVD - ADT6.1, AST .6 Drill. 8 1/2" hole f/6049' to 7287' - 4363 TVD - ADT5.8 AST .3 Circ hi vis sweep prep for wiper trip - monitor well Wiper trip f/7287' to 4707' - monitor well RIH to 7287' Break cim - pump hi vis sweep Drill 8 1/2" hole f/7287' to 8478' - 4945' TVD ADT-5.8 AST - 1.1 Drill 8 1/2" hole f/8478' to 9759' - 5542'TVD - ADT 7.6 AST 1.0 Pump hi vis sweep - ciro for wiper trip Wiper trip f/9759' to 6910' - monitor well RIH to 9759' (fill pipe @ 8338') Pump hi vis sweep - circ Drill 8 1/2" hole f/9759' to 10300' - 5800' TVD - ADT3.8 AST 1.0 Drill 8 1/2" hole f/10,300' to 12,257' - 6935 TVD ADT 16.5 AST 3.5 Drill 8 1/2" hole f/12257' to 12741' 7276'TVD ADT4.3 Ciro and condition for wiper trip Wiper trip f/12741' to 9560' - work pipe through several tight spots - monitor well RIH to 10978' - fill pipe - cont. RIH to 12741' - work tight spot @ 12250' Break circ. - pump. hi vis sweep & circ hole clean POOH to 2700' - hole in good condition L/D 2 stds 5" DP f/derrick (bad box & pin) Cont. POOH to 1600' Cont. POOH - L/D drilling jars PJSM - Recover RA source f/MWD - L/D BHA Housekeeping rig floor - Change to 3 1/2" handling tool Service rig & cut & slip drill line M/U mule shoe & run 10 stds. 3 1/2" DP - change to 5" handling tools - cont. RIH w/5" DP to 12,439' circ & condition for cmt plug PJSM Mule shoe set @ 12439' - set cmt plug #1 w/235 Sxs G cmt @ 15.8 ppg - displace to equalize calc. top cmtl 1,749' (71P @ 13:56 hrs. Pull up to 11,310' Circ drill string volume - blow down TD - R/U for plug #2 " Operations Summary ~" CD1 -NQ1 1/16/01 1/16/01 1/16/01 1/16/01 1/16/01 1 / 16/01 1/16/01 1/17/01 1/17/01 1/17/01 1/17/01 1/17/01 1/17/01 1/17/01 1/17/01 1/17/01 1 / 17/01 1/17/01 1/17/01 1/17/01 1/17/01 1/18/01 1/18/01 1/19/01 1/19/01 1 / 19/01 1/19/01 1/19/01 1/19/01 1 / 19/01 1/20/01 1/20/01 1/20/01 1/20/01 1/20/01 1/20/01 1/20/01 1/20/01 1/20/01 1/20/01 With mule shoe @ 11310' - set cmt plug #2 w/196 Sxs G cmt @ 15.8 ppg - displace to equalize calc. top cmt @ 10735' ClP @ 16:45hrs Break out cmt line - pull up to 10821 Circ and condition mud for plug # 3 With mule shoe @ 10821' set cmt plug #3 w/227 Sxs G cmt @ 17.0 ppg - displace to equalize -calc. top 10234' - ClP@ 20:00 hrs. Break out cmt line - pull up to 9870' Circ & condition mud Flow check - Pump slug - POOH to 8500' POH to 3200', monitor well, POH to 3-1/2" drill pipe. Standback 3-1/2" drill pipe. MU wash sub and flush BOP Stack, pull wear bushing and install test plug. Test BOPE, choke valves and surface safety valves 250/3500 psi, Annular Preventor 250/2500 psi. John Crisp (AOGCC) waived witnessing test. Pull test plug and set wear bushing. MU BHA #4 and shallow test tools. R IH to 3250'. CBU. RIH to 6300'. Circ and condition mud. R IH to 9870'. Circ and condition cement contaminated mud. RIH to 10298'. Clean out cement from 10298' to 10350'. Time drill off of plug from 10350' to 10359'. Time drill off plug from 10359' to 10390'. AST=2.3 Drill from 10390' to 11086'. ART= 6.9 AST=8.3 Drill from 11086' to 11304'. ART=0 AST=4.4 Pumped weighted (12.0 ppg) high vis sweeps and circ hole clean. Monitor well, slight flow. Circ and cond mud, increased mud wt. f/9.8 to 10.0 ppg. Monitor well 15 min, static. Pump out to 10850', max overpull 35K. Continue wiping hole to 9796', 25-40k over. Backreamed tight spot from 10160' to 10084', last 3 stands pulled short on hole fill. Monitor well, static. RIH, worked pipe past tight spots @ 10370' and 10450'. CBU, no problems. Pumped weighted (12.0 ppg) sweeps and circ hole clean. Increased mud wt. for trip margin to 10.15 ppg, monitor well 15 min, static. Pump out 5 stands to 10942', max overpull 25k. Blow down Top Drive, monitor well, static. POH slowly to 9053' @ midnight, max overpull 35K, hole taking proper fill. POH, wiped through numerous tight spots from 9007' to 8590' and from 7784' to 7720'. Continue to POH, dragging 50-70k over from 6490' to 6430'. Established circ @ 6905', pumped wt. high vis sweep and circ hole clean. POH to BHA, wiped through numerous tight spots from 6365' to 4875' and @ 3500', 25- 40k over. Handle BHA, lay down MWD and motor, clear tools from and clean rig floor. Service Top Drive and Drawworks. MU BHA # 5. RIH to 6655, no problems, fill pipe every 2000'. CBU and condition mud. RIH to 11304' - no problems. Stage pumps up to 12.0 BPM and CBU. Pumped wt. high vis sweeps and circ hole clean. Monitor well 15 min Operations Summary CD1 -NQ1 1/20/01 1/21/01 1/21/01 1/21/01 1/21/01 1/21/01 1/21/01 1/21/01 1/21/01 1/21/01 1/21/01 1/21/01 1/21/01 1/21/01 1/22/01 1/22/01 1/22/01 1/22/01 1/22/01 1/22/01 1/22/01 1/22/01 1/22/01 1/22/01 1/22/01 1/22/01 1/22/01 1/23/01 1/23/01 1/23/01 1/23/01 1/23/01 1/23/01 1/23/01 1/23/01 1/24/01 1/24/01 1/24/01 1/24/01 1/24/01 1/24/01 1/24/01 Circ and cond mud - balance mud in and out @ 10.2 ppg. Monitor well 15 min, static. Pump out to 10844', no problems, blow down top drive. POH to 5612', no problems, max overpull 25K. POH, LD 148 jts of 5" drillpipe, monitor well at shoe, static. Handle BHA, lay down tools. PU wash sub and flush BOP stack, change out wear bushing. Service Top Drive and Drawworks. RU to run 7" casing. PJSM. Run 7" casing to 3241'. Cup on fill-up tool leaked - change out cup. CBU - 6 bpm @ 350 psi. Run casing to 6547'. CBU - 5 BPM @ 400 psi. Run casing - 7800' @ midnight. Run 7" casing to 9514'. CBU, 5 BPM @ 550 psi. Run casing to 11289'. Stage pumps up to 6.5 bpm @ 700 psi, circ and cond mud. Reciprocated casing for first hour, then pipe stuck 7' off bottom with shoe @ 11282'. Lay down fill-up tool and MU cement head Continue circulating, held PJSM with Dowell. Attempted to test cement lines, 4 way cross on standpipe manifold washed out. Install loop around washout. Tested lines to 3500 psi, pumped 20 bbls of wash, 50 bbls of 12,5 ppg spacer and 37 bbls of tail cement. Displaced with 20 bbls FW followed with 407.8 bbls of mud, plugs bumped, CIP @ 1100 hrs. Check floats -good. Blow down lines and LD cement head Clear casing tools from floor and clean rig floor. LD 5" running tools and PU 3-1/2" tools. Service Top Drive and Drawworks. Change pipe rams to 3-1/2" X 6"- work platform around BOP stack failed - repair and secure platform. Separate BOP stack from wellhead and land casing on slips with 120k tension. Rough cut 7" casing. LD LJ and cutoff and move stack clear of wellhead. Final cut and dress 7" casing. Install and test packoff to 4300 psi for 15 min. NU BOPE and flowline. Change saver sub on top drive to 3-1/2 IF. Test BOPE and surface safety valves 250/3500 psi, Annular Preventor 250/2500 psi. Changed out gates and seats on choke valves #'s 4 and 16. John Spaulding (AOGCC) waived witnessing test. Install wear bushing. MU BHA # 6. RIH picking up 3-1/2" drill pipe to 10773'. Slip and cut drilling line, service top drive. RIH picking up 3-1/2" drill pipe, tag cement @ 11101'. Clean out soft cement from 11101' to 11120', med hard from 11120' to 11197' (FC). Circ and condition mud. RU and test casing to 3500 psi for 30 min. Drill out FC @ 11197'. Drill out cement and FS @ 11282' and drill 20' of new hole to 11324'. CBU for LOT. RU and perform FIT to 11.6 ppg. Troubleshoot MWD, signal failed. Operations Summary CD1-NQ1 1/24/01 1/24/01 1/24/01 1/24/01 1/24/01 1/24/01 1/24/01 1/24/01 1/25/01 1/26/01 Change well over to 9.2 ppg FIo-Pro mud. Monitor well - clean surface equipment. Pump out 5 stands and POH. Handle BHA - change out MWD collar. RIH to 1000' and shallow test tools. RIH to 9528' Service Top Drive. RIH to 11324'. Drill from 11324' to 11339'. ART=0.5 AST=0 Drill from 11339' to 12022'. ART=6.61 AST=7.05 Drill from 12022' to 12765'. ART=6.69 AST=3.54 1/26/01 1/26/01 1/27/01 1/27/01 1/27/01 1/28/01 1/28/01 1/28/01 1/28/01 1/28/01 Observed connection gas at possum belly, mud wt. cut 0.2 - 0.5 ppg 12595', did not continue below 12595' Pump wt. high vis sweep and circ hole clean for wiper trip. Pump out of hole, no problems, 11900' at midnight. Pump out to shoe, max overpull 10k, monitor well, static. RIH to 12675', no problems. Precautionary ream last 95', circ. Drill from 12765' to 13995'. ART=I 1.62 AST=2.34 Drill from 13995' to 14454'. ART=4.6 AST=1.0 Pumped wt. high vis sweep and circ hole clean. Monitor well, static. Pump out of hole to 12690', no problems. RIH to 14359'. Precautionary ream last stand and circ hole. Drill from 14454' to 15008'. ART=7.45 AST=0 1/29/01 1/29/01 1/29/01 1/29/01 1/30/01 1/30/01 1/30/01 1/30/01 1/30/01 1/30/01 1/31/01 1/31/01 1/31/01 1/31/01 1/31/01 1/31/01 1/31/01 1/31/01 2/1/01 2/1/01 2/1/01 2/1/01 *** Rig on highline power 1530 hrs.** Drill from 15008' to 15127'. ART=1.24 AST=1.1 Observed pump pressure loss of 700 psi over 15 min. drilling. Troubleshoot and pressure test surface equipment, ok. Pump out to 14520', located wash out in tool joint upset, removed joint from service and RIH. Drill from 15127' to 15991'. ART=9.86 AST=0 Drill from 15991' to 16118', TD. ART=3.24 AST=0 Pumped high vis sweep and circ hole clean. Monitor well, static. Pump out of hole to shoe, no problems. Monitor well, static, blow down Top Drive. RIH to 16118', no problems. CBU, pump high vis sweep and circ hole clean. Monitor well, static. Pump out, 11820' @ midnight, no problems. Cont. POOH f/11820' to 11151' Pump hi vis sweep @ 7" shoe Monitor well - Pump out f/11151' tp 10480' - Pump dry job - drop I 7/8" rabbit - POOH to BHA Pump 40 bbls inh. fresh water through BHA - L/D BHA Clean up rig floor - rig up to run liner - PJSM Ran 3 1/2" 9.3# L-80 SLHT slotted and blank liner 120 jts slotted & 35 jts. blank - ran 5 HES 3 1/2" X nipples Rig up & run 2 1/16 inner wash string Space out inner string - P/U Baker PBR M/U packer assembly & PBR RIH w/3 1/2" liner assembly on 3 1/2" Dp to 11,206' Circ. pipe volume @ 2 bbls/min @ 1080 psi Continue RIH w/3 1/2" liner assembly w/shoe to 15958' top of liner @ 11110 Operations Summary CD1-NQ1 2/1/01 2/1/01 2/1/01 2/1/01 2/1/01 W1/01 2/1/01 2/1/01 2/2/01 W2/01 2/2/01 2/2/01 2/2/01 2/2/01 2/2/01 Drop & pump down liner hanger setting ball - pressure up to 1700 psi & set hanger - pressure up to 2500 psi & relaese running tool f/ liner - pressure up to 3200 psi & shear out ball PJSM - displace 3 1/2" x 6 1/8" annulus to 9.2 ppg brine Set liner top packer - displace inside of 3 1/2" liner to 9.2 ppg brine - monitor well - very slight losses - pump dry job - blow down top ddve POOH laying down 3 1/2" DP Cut drill line Cont. POOH and laying down 3 1/2" DP Break and lay down liner running tool Pull & lay down 2 1/16" inner wash string Continue POOH & L/D 2 1/16" inner wash string L/D 2 1/16" tools - Pull wear bushing Rig up to run 3 1/2" completion - PJSM Run 3 1/2" completion - Baker seal assembly, 290 jts- 3 1/2" 9.3# L-80 8rd mod tbg - HES X nipple, 3 CAMCO GLMs, HES $SSV M/U control line to HES SSSV & test to 5000 psi Continue to run 3 1/2" completion - ran 58 jts 3 1/2" 9.3 # L-80 8rd Mod tbg - total of 348 jts P/u 2 jts. 3 1/2" tbg, xo, 2 jts. 3 1/2" DP - idle pump and observe seal assembly enter PBR - observe Iocator tag up - 2/2/01 2/2/01 2/2/01 2/2/01 2/2/01 2/3/01 2/3/01 2/3/01 2/3/01 2/3/01 2/3/01 2/3/01 2/3/01 2/3/01 2/3/01 obtain space out measuremen PJSM - pull back to top liner top - Change well over to 9.2 brine - blow down top drive and lines L/D space out pipe - P/U 3 1/2" space out pups - OX - 1 jt. 4 1/2" 12.6# IBM tbg and tbg hanger M/U control line to hanger & test to 5000 psi Land out tbg hanger - Run in lock down screws - L/D landing jt. A Set 2 way check in tbg hanger - P/U landing jt. B - test tbg hanger seals to 5000 psi for 10 mins Remove test equip - L/D landing jt B Change top' pipe rams & rig top drive for 5" Nipple down BOPE - turn buckles - drain hoses - flow line Connect control line to well head & test - N/U tree & test to 5000 psi R/U lubicator & pull 2 way check R/U circ manifold and. line to well head - PJSM Test lines to 3500 psi - Attempt to test 7" x 3 1/2 "annulus to 2500 psi - RP valve sheared out @ 2200 psi Displace well to diesel - pumped 302 bbls of 373 bbls calc volume - observed diesel to surface - shut down - rig down lines & manifold R/U lubicator & set BPV - 450 psi on tbg - R/D lubicator & secure well Finish cleaning mud pits - Release Rig @ 1200 hrs. 2/3/01 ALPINE CD1-NQ1 PH Alaska State Plane INTF_,Q Coordinates Measured Angle Azimuth TVD-RKB TVD X Y N/-S E/-W DLS SVY# Depth deg deg ft Subsea ft ft ft ft deg/100 ft 51 6737.00 59.88 165.87 4086.79 4030.79 386949.46 5970953.05 -4736.06 1221.16 0.63 52 6927.00 60.25 165.59 4181.61 4125.61 386987.55 5970792.88 -4895.64 1261.75 0.23 53 7117.00 59.29 165.33 4277.27 4221.27 387026.29 5970633.37 -5054.54 1302.96 0.52 54 7306.00 60.36 165.25 4372.26 4316.26 387065.31 5970474.72 -5212.57 1344.45 0.57 55 7498.00 61.01 166.28 4466.27 4410.27 387103.94 5970311.85 -5374.84 1385.61 0.58 56 7687.00 61.22 168.34 4557.58 4501.58 387137.77 5970149.88 -5536.27 1421.96 0.96 57 7878.00 60.62 167.72 4650.41 4594.41 387169.84 5969986.09 -5699.56 1456.57 0.42 58 8069.00 59.87 167.32 4745.20 4689.20 387203.14 5969823.66 -5861.46 1492.40 0.43 59 8259.00 60.47 168.10 4839.71 4783.71 387235.71 5969662.10 -6022.51 1527.48 0.48 60 8449.00 61.84 168.43 4931.37 4875.37 387267.02 5969498.67 -6185.45 1561.33 0.74 61 8639.00 60.74 168.21 5022.64 4966.64 387298.21 5969334.99 -6348.64 1595.06 0.59 62 8830.00 62.84 166,55 5112.93 5056.93 387332.44 5969170.22 -6512.87 1631.86 1.34 63 9020.00 62.16 166.12 5200.66 5144.66 387369.70 5969005.88 -6676.63 1671.67 0.41 64 9210.00 62.44 165.15 5288.98 5232.98 387408.89 5968842.30 -6839.59 1713.41 0.48 65 9397.00 62.52 164.87 5375.39 5319.39 387449.29 5968681.47 -6999.79 1756.30 0.14 66 9589.00 62.87 164.36 5463.46 5407.46 387491.98 5968516.31 -7164.28 1801.56 0.30 67 9779.00 61.48 165.08 5552.15 5496.15 387533.74 5968353.57 -7326.36 1845.85 0.80 68 9970.00 62.27 164.02 5642.19 5586.19 387576.09 5968190.55 -7488.72 1890.73 0.64 69 10161.00 61.54 163.67 5732.14 5676.14 387620.44 5968028.02' -7650.56 1937.61 0.41 70 10351.00 59.60 164.91 5825.49 5769.49. 387662.77 5967868.07 -7809.84 1982.43 1.17 71 10541.00 58.65 163.86 5923.00 5867.00 387704.21 5967710.36 -7966.89 2026.32 0.69 72 10731.00 58.81 163.64 6021.62 5965.62 387747.22 5967553.78 -8122.80 2071.76 0.13 73 10922.00 58.27 166.03 612.1.31 6065.31 387787.39 5967395.92 -8280.03 2114.38 1.10 74. 11113.00 57.05 165.63 6223.48 6167.48 387824.45 5967238.88 -8436.49 2153.88 0.66 75 11303.00 55.39 164.68 6329.12 6273.12 387862.52 5967085.63 -8589.14 2194.33 0.97 76 11491.00 53.25 164.17 5438.77 6382.77 387901.21 5966937.93 -8736.24 2235.32 1.16 77 11682.00 53.63 164.20 6552.54 6496.54 387940.72 5966789.70 -8883.85 2277.13 0.20 78 11873.00 48.74 164.83 6672.23 6616.23 387978.23 5966645.74 -9027.21 2316.88 2.57 79 12063.00 45.81 166.73 6801.13 6745.13 388010.45 5966509.98 -9162.47 2351.21 1.71 80 12253.00 45.32 166.51 6934.15 6878.15 388039.79 5966377.53. -9294.46 2382.61 0.27 81 12444.00 45.01 166.20 7068.82 7012.82 388069.69 5966245.44 -9426.08 2414.56 0.20 82 12635.00 45.96 165.48 7202.73' 7146.73 388100.95 5966112.89 -9558.14 2447.88 0.57 83 12741.00 45.96 165.48 7276.41 7220.41 388118.90 5966038.85 -9631.90 2466.99 0.00 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 100 VSect. Plane = 1 65.86 Vert. Sec ft 4890.89 5055.54 5219.70 5383.08 5550.48 5715.90 5882.71 6048.45 6213.19 6379.46 6545.95 6714.19 6882.71 7050.93 7216.75 7387.32 7555.31 7723.71 7892.10 8057.51 8220.52 8382.81 8545.69 8707.06 8864.96 9017.61 9170.97 9319.70 9459.25 9594.91 9730.35 9866.54 9942.74 projected to td SVY# 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 144 145 146 147 148 149 150 mia INTEQ Measured Angle Depth deg 11479,00 91,41 11573,00 90.86 11667,00 91,30 11763,00 89,86 11858,00 90,27 11952,00 90,62 12048,00 90,99 12143,00 89,49 12237,00 90.00 12333,00 90,31 12428,00 90.48 12522,00 89,00 12617,00 86,77 12713,00 ,88;39 12805,00.' 88,63 12901,00 88,56 12996,00 88,59 13093,00 88,66 13189,00 88,76 13284,00 88,94 13378,00 88,94 13475,00 88,28 13571.00 88.11 13664,00 87,94 13759.00 87,87 13851.00 89,69 13943,00 89,76 14036,00.. 90,93 14128,00 91,13 14219,00 91,24 14308,00 91,24 14403,00 91,23 14493,00 91,47 14588,00 91,54 14681,00 91,65 14772,00 91,44 14864,00 91,37 14956,00 91.06 15047,00. 90.75 15141.00 91,13 15230,00' 91,30 15323,00 91,64, 15416,00' 91,54 15505,00 91,65 15599,00 91,61 15692,00 91,68 15785,00 91,82 15880,00 92,52 15970,00 92,60 16064.00 92,85 16118.00 92,85 ALPINE CD1-NQ1 Alaska State Plane Coordinates Azimuth TVD-RKB TVD X Y N/-S deg ff Subsea ff ff 221.30 6192,10 6136,10 387365,38 5966917,04 -8765.46 222,85 6190,24 6134,24 387301,33 5966848,28 -8835,21 224,23 6188.47 6132,47 387235,54 5966781.17 -8903,34 224,49 6187.50 6131,50 387167,37 5966713.60 -8971,97 224.99 6187,39 6131,39 387099.47 5966647,17 -9039,45 225,54 6186,66 6130,66 387031.68 5966582,07 -9105.61 225,70 6185,31 6129,31 386962,05 5966516,01 -9172.74 224.40 6184,91 6128.91 386893.79 5966449,96 -9239.86 224.74 6185,33 6129.33 386826.79 5966384.03 -9306.82 225,91 6185.07 6129.07 386757.49 5966317.61 -9374.31 225,09 6184,42 6128,42 386688,72 5966252,10 -9440,90 225,55 6184,84 6128,84 386620,87 5966187,06 -9506.99 225,46 6188,35. 6132,35 386552,13 5966121,59 -9573,52 225,56 6192,40 6136,40 386482,68 5966055,46 -9640,74 225,58 6194,80 6i38,80 386416,02 5965992,11 -9705,12. 225,84 6197,15. 6141,15 386346,29 5965926,18 -9772,13 225,79. 6199,51 6143,51 386277,17 5965861,06 -9838.33 225,44 6201,84 6145,84 386206,83 5965794,32 -9906,16 225,43 6204,00 6148,00 386137,42 5965728,05 -9973,50 225,56 6205,91 6149,91 386068,66 5965662.53 -10040,08 226,31 6207,65 6151,65 386000,12 5965598,24 -10105,44 226,30 6210,00 6154,00 385928,99 5965532,35 -10172.43 226,37 6213.02 6157,02 385858.56 5965467,19 -10238.68 226,36 6216,23 6160.23 385790,31 5965404.12 -10302,82 225,89 6219,70 6163.70 385720,86 5965339,39 -10368,62 225,22 6221,66 6165,66 385654,21 5965276,02 -10433,02 225,12 6222,10 6166,10. 385587,97' 5965212,19 -10497,88 224,35 6221,54 6165,54 385521,50 5965147,16 -10563,94 225,09 6219,89 6163,89 385455,78 5965082,82 -10629,30' 224,00 6218,01 6162,01 385390,96 5965018,99 -10694,15 224,56 6216,08 6160,08 385327,86 5964956,26 -10757,85 223;92 6214,03 6158,03 385260,56' 5964889,26 -10825,89. 224,76 6211.91 6155,91 385196,68 5964825,90'-10890,24 225,70 6209,42' 6153,42 385128.24 5964760,09 -10957,12 226,07 6206.83 6150,83 385060,50 5964696,42 -11021,84 225,98 6204,37 6i48,37' 384994,07 5964634,29 -11085.00 226,19 6202,12 6146.12 384926,84 5964571.55 -11148,79 226.13 6200,17 6144,17 384859,52 5964508.88 -11212.50 225,24 6198.73 6142,73 384793.44. 5964446.34 -11276,06 225,46 6197,19 6141,19 384725,56 5964381,34 -11342,11 225,29 6195,30. 6139,30 384661,28 5964319,84'-11404,62 225,82 6192,92 6136,92 384593,90 5964255,78 -11469,72 225,89 6190,34 6134,34 384526,20 5964192,09 -11534,47 225,61 6187,86 6131,86 384461,52 5964131,01 -11596,55 225,37 6185,18 6129,18 384393,51 5964066,19 -11662,42 225,66 6182,51 6126,51 384326,19 5964002,10 -11727,56 225,25 6179,67 6123,67 384258,94 5963937,94 -11792,76 224,55 6176,08 6120,08 384190,89 5963871,75 -11860,01 227,01 6172,06 6116,06 384125.50 5963810,06 -11922,71 225.83 6167,56 6111.56 384056,49 5963746.41 -11987,43 225.83 6164.87 6108,87 384017.23 5963709,44 -12025,01 PROJECTED TO TD VSect. Plane = 2. E/-W DLS ff deg/100 ff 1699.83 6,61 1636,85 1.75 1572,12 1.54 1505,00 1,52 1438,13 0,68 1371.36 0,69 1302.75 0.42 1235.52 2,09 1169.56 0.65 1101.29 1,26 1033.54 0,88 966.70 1,65 898.99 2,35 830.57 1,69 764,89 0,26 696,19 0,28 628,09 0,06 558,79 0,37 490,41 .0,10 422,67 0,23 355,14 0.80 285,03 0.68 215.62 0,19 148.35 0.18 79,91 0,50 14,25 2,11 -51.00 0,13 -116,45 1,51 -181,17 0,83 -244,99 1,20 -307,12 0,63 -373,38 0.67 -436,26. 0,97 -503,68' 0,99 -570,43 0,41 -635.89 0,25 -702,14 0.24 -768,49' 0.34 -833,59 1,04 -900,45 0,47 -963,78 0,27 -1030,15 0,68 -1096,86. 0,13 -1160,59 0,34 -1227,60 0,26 -1293,92 0,32 -1360,17 0,47 -1427,18 1.04 -1491.61 2,73 -1559.62 1.28 -1598,31 0,00 :25.13 Vert. Sec ff 4979.35 5073.19 5167.14 5263.12 5358.12 5452.11 5548.10 5643.09 5737.09 5833.09 5928.08 6022.08 6117.00 ,6212.91 6304.88 6400.85 6495.81 6592.78 6688.75, 6783.73 6877.70 6974.66 7070.59 7163.51' 7258.43 7350.40 7442.40 7535.40 7627.38 7718.35 78O7.32 7902'.29 7992.25- 8087.22 8180.18 8271.13 8363.09 8455.05 8546.04 8640.02 8729.00 8821.97 8914.93 9003.89 9097.85 9190.81 9283.76 9378.69 9468.59 9562.46 9616.38 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 24, 2001 Stephen McMains Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Request for Well Name Change Permitted Name: CD1-NQ1 New Name: CD1-229 RECEIVED 4PR ZOO1 Dear Stephen: In reference to our conversation today, please change the name of permitted well CD1-NQ1 to CD1-229. This well is drilled to the Nanuq formation from the Alpine CD1 pad location, and is currently undergoing production testing to evaluate the Nanuq satellite accumulation. All future correspondence and reporting will use the new well name. If you have any questions, please contact me at (907) 263-4465. Sincerely, .,,,,~ '~, ,~/,~ Eric W. Reinbold Sr. Staff Reservoir Engineer CC: C. Alvord- PAl, ATO-868 D. Bannan- PAl, ATO-866 M. Erwin- PAl, ATO-810 M. Ireland- PAl, ATO-870 D. Schwartz- PAl, ATO-1492 J. Winegarner- PAl, ATO-1496 Craig Lewis, Anadarko Petroleum Corporation Bill Liddell, Anadarko Petroleum Corporation Mike Kotowski- DNR, Division of Oil and Gas Teresa Imm- ASRC Scklumber Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1'5 Company: Alaska Oil & Gas Cons Comm Attn: Lisa WeePie 333 West 7th Ave, SUite 100 Anchorage, AK 99501 Field: Alpine " 3/22/01 Well Job it Log DescriPtion. Date BL' Sepia' CD Color Prints o~Ql-O~ CD1-21 21125 SCMT 02/28/0!' 1 CD1-229 21101 CDR/ADN/IMP LWD - _ 01131101. '- 1 · CD1-229 21101 MD' ARRAY RES 01131101 1. -1 CD1-229 21101 TVD -ARRAY RES 01131101 I 1 A~=: 5~-/o3-~ao8 ~R'-oo · , . . · . -. , R [CEIl'ED SlGN~ DATE: MAD I Ifil Please sign and return one copy of this transmittal to Sherrie at tho abOve address or fax to (907) 561. -~J'~P~AiffI~. 1/29/01 Schlmb Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 923 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine (Open Hole) Color Well Job # Log Description Date BL Sepia Prints CD CD1-33 21034 M10,1MP & CDR LWD (PDC) 010104 1 CD1-33 21034 MD ARRAY RES (PDC) 010104 1 1 CD1-33 21034 TVD ARRAY RES (PDC) 010104 I 1 CD1-229 PB1 21035 ADN & CDR LWD (PDC) 010116 1 CD1-229 PB1 21035 MD ADN (PDC) 010116 I 1 CD1-229 PB1 21035 TVD ADN (PDC) 010116 I 1 CD1-229 PB1 21035 MD CDR (PDC) 010116 I 1 CD1-229 PB1 21035 TVD CDR (PDC) 010116 I I SIGNE~ ~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska, Inc Field .................... : Colville River Well ..................... : CD1-NQ1 API number ............... : 50-103-20348-00 Engineer ................. : Brown COUNTY: .................. : Doyon 19 STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : 56.05 ft DF above permanent ....... : 56.05 ft Vertical section origin- Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point ............... Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 225.13 degrees 30-Jan-2001 09:37:50 Page 1 of 7 Spud date ................ : 06-Jan-01 Last survey date ......... : 30-Jan-01 Total accepted surveys...: 152 MD of first survey ....... : 0.00 ft MD of last survey ........ : 16118.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 25-Dec-2000 Magnetic field strength..: 1147.20 HCNT Magnetic dec (+E/W-) ..... : 25.55 degrees Magnetic dip ............. : 80.55 degrees ..... MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.20 HCNT Reference Dip ............ : 80.55 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees ..... Corrections Magnetic dec (+E/W-) ..... : 25.54 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.54 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2001Anadrill IDEAL ID6_lC_08] RECEIVED FEB 2 6 001 Alaska Oil & Gas Cons. Commission Anchorage ANADRILL SCHLUMBERGER Survey Report 30-Jan-2001 09:37:50 Page 2 of 7 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 1 0.00 0.00 0.00 2 114.00 0.00 0.00 3 261.00 3.50 168.00 4 446.00 9.20 161.68 5 564.00 14.05 159.71 6 653.00 16.72 157.66 7 743.00 17.11 159.25 8 832.00 16.77 160.12 9 922.00 17.19 159.72 10 1013.00 21.20 159.35 Course length (ft) 0.00 114.00 147.00 185.00 118.00 89.00 90.00 89.00 90.00 91.00 TVD depth (ft) 0.00 114.00 260.91 444.70 560.25 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 0.00 0.00 0.00 0.00 0.00 0.00 2.44 -4.39 0.93 12.12 -23.97 6.76 22.30 -46.37 14.70 Total At DLS Srvy displ Azim (deg/ tool (ft) (deg) 100f) type 0.00 0.00 0.00 TIP 0.00 0.00 0.00 MWD 4.49- 168.00 2.38 GYR 24.90 164.25 3.10 MWD 48.65 162.41 4.12 MWD 646.05 31.70 -68.35 23.31 72.22 161.17 3.06 732.16 42.07 -92.71 32.92 98.38 160.45 0.67 817.29 52.85 -117.02 41.93 124.31 160.29 0.48 903.37 63.87 -141.71 50.95 150.59 160.22 0.48 989.29 76.22 -169.73 61.42 180.50 160.11 4.41 MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 11 1109.00 22.92 164.14 12 1204.00 25.56 168.73 13 1298.00 28.48 170.18 14 1393.00 32.82 170.07 15 1489.00 37.80 167.80 96.00 95.00 94.00 95.00 96.00 1078 1164 1248 1330 1408 .27 92.41 -203.96 72.65 216.51 160.39 2.59 .89 112.72 -241.86 81.72 255.30 161.33 3.41 .63 136.82 -283.85 89.50 297.62 162.50 3.18 .33 164.59 -331.55 97.81 345.67 163.56 4.57 .65 195.39 -385.96 108.52 400.93 164.30 5.36 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 16 1584.00 40.37 166.08 17 1679.00 43.03 166.24 18 1775.00 44.98 166.34 19 1870.00 49.11 165.48 20 1966.00 52.93 165.19 21 2061.00 56.54 166.14 22 2156.00 59.75 166.25 23 2253.00 60.31 165.64 24 2346.00 60.76 164.95 25 2443.00 61.22 165.63 95.00 95.00 96.00 95.00 96.00 95.00 95.00 97.00 93.00 97.00 1482 1553 1622 1687 1747 1802 1852 1900 1946 1993 .39 226.93 -444.29 122.08 460.76 164.64 2.94 .31 259.51 -505.65 137.19 523.93 164.82 2.80 .36 294.02 -570.44 153.00 590.60 164.99 2.03 .08 329.58 -637.86 169.93 660.11 165.08 4.40 .46 367.11 -710.04 188.83 734.72 165.11 3.99 .30 .43 .89 .63 .68 406.52 -785.18 208.02 448.16 -863.53 227.27 491.20 -945.05 247.68 531.89 -1023.36 268.23 574.51 -1105.41 289.77 812.27 165.16 3.89 892.94 165.26 3.38 976.96 165.31 0.79 1057.93 165.31 0.81 1142.76 165.31 0.78 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 26 2537.00 61.25 165.89 27 2633.00 61.27 165.90 28 2725.00 61.16 166.12 29 2820.00 61.30 166.28 30 2918.00 61.12 165.33 94.00 96.00 92.00 95.00 98.00 2038.91 2085.07 2129.37 2175.09 2222.29 616.49 -1185.28 659.55 -1266.92 700.93 -1345.16 743.91 -1426.03 787.72 -1509.29 310.04 330.55 350.04 369.91 390.97 1225.16 165.34 0.24 1309.33 165.38 0.02 1389.96 165.41 0.24 1473.22 165.46 0.21 1559.10 165.48 0.87 MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 30-Jan-2001 09:37:50 Page 3 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool ~ depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 31 3013.00 61.42 166.25 95.00 2267.96 830.20 -1590.04 411.42 1642.41 165.49 0.91 MWD 6-axis 32 3109.00 61.67 165.82 96.00 2313.70 873.55 -1671.95 431.79 1726.81 165.52 0.47 MWD 6-axis 33 3203.00 62.06 165.05 94.00 2358.02 915.38 -1752.18 452.63 1809.70 165.52 0.83 MWD 6-axis 34 3308.00 61.09 166.63 105.00 2408.01 962.53 -1841.71 475.23 1902.03 165.53 1.61 MWD 6-axis 35 3499.00 60.17 164.59 191.00 2501.69 1046.96 -2002.92 516.58 2068.47 165.54 1.05 MWD 6-axis '~--' 36 3689.00 59.81 168.15 190.00 2596.74 1132.26 -2162.78 555.35 2232.94 165.60 1.63 MWD 6-axis 37 3880.00 62.73 166.12 191.00 2688.55 1220.98 -2326.02 592.67 2400.34 165.71 1.79 MWD 6-axis 38 4070.00 62.08 167.58 190.00 2776.56 1309.50 -2489.98 630.98 2568.69 165.78 0.76 MWD 6-axis 39 4258.00 62.23 165.79 188.00 2864.38 1396.49 -2651.74 669.27 2734.89 165.84 0.85 MWD 6-axis 40 4452.00 62.38 165.77 194.00 2954.54 1484.06 -2818.25 711.46 2906.67 165.83 0.08 MWD 6-axis 41 4642.00 62.35 165.84 190.00 3042.67 1569.93 -2981.43 752.74 3074.99 165.83 0.04 MWD 6-axis 42 4829.00 60.69 165.24 187.00 3131.84 1653.13 -3140.59 793.78 3239.35 165.82 0.93 MWD 6-axis 43 5021.00 59.74 164.88 192.00 3227.22 1736.28 -3301.59 836.73 3405.97 165.78 0.52 MWD 6-axis 44 5213.00 59.78 165.37 192.00 3323.91 1819.20 -3461.91 879.31 3571.83 165.75 0.22 MWD 6-axis 45 5403.00 59.26 165.09 190.00 3420.29 1901.32 -3620.24 921.06 3735.57 165.73 0.30 MWD - 46 5594.00 59.46 165.23 191.00 3517.63 1983.56 -3779.09 963.15 3899.90 165.70 0.12 MWD 6-axis 47 5784.00 59.85 164.25 190.00 3613.62 2064.57 -3937.28 1006.31 4063.84 165.66 0.49 MWD 6-axis 48 5974.00 60.68 165.05 190.00 3707.86 2145.87 -4096.37 1049.97 4228.79 165.62 0.57 MWD 6-axis 49 6166.00 60.98 164.97 192.00 3801.44 2229.39 -4258.32 1093.34 4396..43 165.60 0.16 MWD 6-axis 50 6356.00 60.34 164.97 190.00 3894.54 2311.80 -4418.28 1136.29 4562.05 165.58 0.34 MWD 6-axis 51 6546.00 59.28 164.67 190.00 3990.08 2393.15 -4576.77 1179.29 4726.27 165.55 0.'57 MWD 6-axis 52 6737.00 59.88 165.87 191.00 4086.79 2475.85 -4736.06 1221.16 4890.96 165.54 0.63 MWD 6-axis 53 6927.00 60.25 165.59 190.00 4181.61 2559.66 -4895.63 1261.75 5055.62 165.55 0.23 MWD - 54 7117.00 59.29 165.33 190.00 4277.27 2642.56 -5054.54 1302.96 5219.77 165.55 0.52 MWD 6-axis 55 7306.00 60.36 165.25 189.00 4372.26 2724.65 -5212.57 1344.45 5383.16 165.54 0.57 MWD 6-axis 56 7498.00 61.01 166.28 192.00 4466.27 2809.96 -5374.84 1385.61 5550.57 165.54 0.58 MWD - 57 7687.00 61.22 168.34 189.00 4557.58 2898.09 -5536.27 1421.96 5715.96 165.60 0.96 MWD 6-axis 58 7878.00 60.62 167.72 191.00 4650.41 2988.76 -5699.56 1456.57 5882.74 165.66 0.42 MWD 6-axis 59 8069.00 59.87 167.32 191.00 4745.20 3077.59 -5861.46 1492.40 6048.47 165.72 0.43 MWD 6-axis 60 8259.00 60.47 168.10 190.00 4839.71 3166.34 -6022.51 1527.48 6213.20 165.77 0.48 MWD 6-axis ANADRILL SCHLUMBERGER Survey Report 30-Jan-2001 09:37:50 Page 4 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool ~ depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 61 8449,00 61,84 168,43 190,00 4931,37 3257,31 -6185,45 1561,33 6379,46 165,83 0,74 MWD 6-axis 62 8639.00 60,74 168,21 190,00 5022,64 3348,54 -6348,64 1595,06 6545,95 165,90 0,59 MWD 6-axis 63 8830,00 62,84 166.55 191,00 5112.93 3438,32 -6512,87 1631,86 6714,19 165,93 1,34 MWD 6-axis 64 9020,00 62,16 166.12 190,00 5200.66 3525.64 -6676.63 1671,67 6882,72 165,94 0,41 MWD 6-axis 65 9210,00 62,44 165.15 190,00 5288,98 3611,03 -6839,59 17-13,41 7050,94 165,94 0,48 MWD 6-axis 66 9397,00 62,52 164,87 187.00 5375,39 3693,65 -6999,79 1756,30 7216,76 165,91 0,14 MWD 6-axis 67 9589,00 62,87 164,36 192,00 5463,46 3777,62 -7164,28 1801,56 7387,32 165.88 0.30 MWD 6-axis 68 9779,00 61,48 165,08 190,00 5552,15 3860,58 -7326,36 1845,85 7555,31 165,86 0,80 MWD 6-axis 69 9970,00 62,27 164,02 191,00 5642,19 3943,32 -7488,71 1890,73 7723,71 165,83 0,64 MWD 6-axis 70 10161,00 61,54 163,67 191,00 5732,14 4024,27 -7650,55 1937,61 7892,10 165,79 0,41 MWD 6-axis 71 10350,00 59,17 166.59 189,00 5825,63 4106,34 -7809,27 1979,80 8056,32 165,77 1,84 MWD 6-axis 72 10392,00 59,18 168,00 42,00 5847,15 4125,54 -7844,45 1987,73 8092,37. 165,78 2,88 MWD 6-axis 73 10419,00 58,56 169.45 27,00 5861,11 4138,33 -7867,11 1992,25 8115,45 165,79 5,14 MWD 6-axis 74 10452,00 57,54 170,82 33,00 5878,57 4154,39 -7894,70 1997,05 8143,37 165,80 4,69 MWD 6-axis 75 10484,00 55,22 173,17 32.00 5896,29 4170,37 -7921,08 2000,77 8169,86 165,82 9,48 MWD 6-axis 76 10513,92 53,72 175,70 29,92 5913,68 4185,78 -7945,31 2003,13 8193,93 165,85 8,51 MWD 6-axis 77 10546,00 53,46 175,60 32,08 5932,72 4202,56 -7971,05 2005,09 8219,37 165,88 0,85 MWD 6-axis 78 10579,00 54,80 177,02 33,00 5952,06 4220,17 -7997,74 2006,81 8245.67 165,91 5,35 MWD - 79 10609,00 56,80 179.87 30,00 5968.92 4237.19 -8022.53 2007,48 8269,89 165,95 10,30 MWD - 80 10642,00 60,03 182,80 33,00 5986,21 4257.48 -8050,63 2006,81 8296,98 166,00 12,37 MWD 6-axis 81 10674,00 63,24 185,44 32,00 6001,41 4278,73 -8078,71 2004,78 8323,74 166,06 12,38 MWD 6-axis 82 10705,00 65,76 186,44 31,00 6014,76 4300,42 -8106,53 2001,88 8350,05 166,13 8,63 MWD 6-axis 83 10742,00 66,19 187,56 37,00 6029,82 4327,00 -8140,08 1997,76 8381,64 166,21 3,00 MWD 6-axis 84 10774,00 66,44 187,56 32,00 6042,67 4350,23 -8169,13 1993,90 8408,94 166,28 0,78 MWD 6-axis 85 10800,00 66,62 187,52 26,00 6053,03 4369,13 -8192,77 1990,77 8431,17 166,34 0,71 MWD 6-axis 86 10836,00 67,05 187,28 36,00 6067,19 4395,30 -8225,59 1986,51 8462,07 166,42 1,34 MWD 6-axis 87 10870,00 67,52 187,08 34,00 6080,32 4420,03 -8256,71 1982,59 8491,40 166,50 1,49 MWD 6-axis 88 10900,34 68,02 188,12 30,34 6091,80 4442,31 -8284,54 1978,88 8517,61 166,57 3,58 MWD 6-axis 89 10933,00 68,85 191,13 32,66 6103,81 4467.03 -8314,49 1973,80 8545,56 166.65 8,94 MWD 6-axis 90 10963,00 69,48 193,28 30,00. 6114,48 4490.56 -8341,89 1967,87 8570,86 166,73 7,02 MWD 6-axis ANADRILL SCHLUMBERGER Survey Report 30-Jan-2001 09:37:50 Page 5 of 7 Seq Measured Incl Azimuth Course TVD % depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 91 10991.00 70.28 197.01 28.00 6124.11 92 11024.00 71.39 200.30 33.00 6134.95 93 11055.00 72.52 202.35 31.00 6144.55 94 11086.00 73.10 204.56 31.00 6153.71 95 11118.00 75.44 207.57 32.00 6162.39 96 11148.00 78.31 209.88 97 11181.00 82.56 211.00 98 11219.00 85.06 215.45 99 11245.00 85.29 217.45 100 11380.00 87.15 219.92 30.00 33.00 38.00 26.00 135.00 6169.20 6174.69 6178.78 6180.97 6189.87 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 4513.33 -8367.26 1961.00 4541.23 -8396.79 1951.03 4568.20 -8424.24 1940.31 4595.72 -8451.41 1928.52 4624.82 -8479.07 1914.99 4652.85 -8504.68 4684.32 -8532.73 4721.27 -8564.32 4746.88 -8585.16 4880.72 -8690.30 Total At DLS Srvy displ Azim (deg/ tool (ft) (deg) 100f) type 8593.98 166.81 12.83 MWD 8620.47 166.92 10.00 MWD 8644.80 167.03 7.27 MWD 8668.65 167.15 7.06 MWD 8692.63 167.27 11.64 MWD 1900.94 8714.54 167.40 12.15 1884.46 8738.35 167.55 13.31 1863.76 8764.77 167.72 13.37 1848.37 8781.88 167.85 7.72 1764.18 8867.56 168.52 2.29 MWD MWD MWD MWD IMP Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 101 11425.00 87.94 220.47 102 11479.00 91.41 221.30 103 11573.00 90.86 222.85 104 11667.00 91.30 224.23 105 11763.00 89.86 224.49 45.00 54.00 94.00 94.00 96.00 6191.80 6192.11 6190.24 6188.47 6187.50 4925.51 -8724.64 4979.35 -8765.46 5073.20 -8835.21 5167.14 -8903.34 5263.13 -8971.97 1735.17 8895.51 168.75 1699.83 8928.75 169.03 1636.85 8985.56 169.50 1572.11 9041.07 169.99 1505.00 9097.32 170.48 2.14 6.61 1.75 1.54 1.52 IMP IMP IMP IMP IMP 6-axis 6-axis 6-axis 6-axis 6-axis 106 11858.00 90.27 224.99 107 11952.00 90.62 225.54 108 12048.00 90.99 225.70 109 12143.00 89.49 224.40 110 12237.00 90.00 224.74 111 12333.00 90.31 225.91 112 12428.00 90.48 225.09 113 12522.00 89.00 225.55 114 12617.00 86.77 225.46 115 12713.00 88.39 225.56 116 12805.00 88.63 225.58 117 12901.00 88.56 225.84 118 12996.00 88.59 225.80 119 13093.00 88.66 225.44 120 13189.00 88.76 225.43 95.00 94.00 96.00 95.00 94.00 96.00 95.00 94.00 95.00 96.00 92.00 96.00 95.00 97.00 96.00 6187.39 6186.66 6185.31 6184.92 6185.33 6185.07 6184.42 6184.85 6188.35 6192.41 6194.80- 6197.15 6199.51 6201.84 6204.00 5358.12 -9039.45 5452.12 -9105.61 5548.11 -9172.74 5643.10 -9239.85 5737.09 -9306.82 5833.09 -9374.31 5928.09 -9440.90 6022.08 -9506.99 6117.01 -9573.52 6212.92 -9640.73 6304.88 -9705.12 6400.85 -9772.13 6495.81 -9838.32 6592.78 -9906.15 6688.76 -9973.50 1438.13 9153.13 170.96 1371.36 9208.29 171.44 1302.75 9264.79 171.92 1235,52 9322.09 172.38 1169.56 9380.02 172.84 1101.29 9438.78 173.30 1033.53 9497.30 173.75 966.70 9556.01 174.19 898.98 9615.64 174.64 830.56 9676.44 175.08 764.89 9735.21 175.49 696.19 9796.90 175.93 628.09 9858.35 176.35 558.79 9921.90 176.77 490.41 9985.55 177.18 0.68 0.69 0.42 2.09 0.65 1.26 0.88 1.65 2.35 1.69 0.26 0.28 0.06 0.37 0.10 IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP IMP 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 30-Jan-2001 09:37:50 Page 6 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ ~ depth angle angle length depth section +N/S- - (ft) (deg) (deg) (ft) (ft) (ft) (ft) 121 13284.00 88.94 225.56 95.00 6205.91 6783.73 -10040.08 422.67 10048.97 177.59 0.23 122 13378.00 88.94 226.31 94.00 6207.65 6877.71 -10105.44 355.14 10111.68 177.99 0.80 123 13475.00 88.28 226.30 97.00 6210.00 6974.66 -10172.43 285.02 10176.42 178.40 0.68 124 13571.00 88.11 226.37 96.00 6213.02 7070.59 -10238.68 215.61 10240.95 178.79 0.19 125 13664.00 87.94 226.36 93.00 6216.23 7163.51 -10302.82 148.35 10303.89 179.18 0.18 Displ Total At DLS Srvy Tool +E/W- displ Azim (deg/ tool qual (ft) (ft) (deg) 100f) type type IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis 126 13759.00 87.87 225.89 95.00 6219.70 7258.44 -10368.62 79.91 10368.92 179.56 0.50 127 13851.00 89.69 225.22 92.00 6221.66 7350.41 -10433.02 14.25 10433.03 179.92 2.11 128 13943.00 89.76 225.12 92.00 6222.10 7442.41 -10497.88 -51.00 10498.00 180.28 0.13 129 14036.00 90.93 224.35 93.00 6221.54 7535.40 -10563.94 -116.45 10564.58 180.63 1.51 130 14128.00 91.13 225.09 92.00 6219.89 7627.38 -10629.30 -181.18 10630.85 180.98 0.83 IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis 131 14219.00 91.24 224.00 91.00 6218.01 7718.36 -10694.14 -244.99 10696.95 181.31 1.20 132 14308.00 91.24 224.56 89.00 6216.08 7807.33 -10757.85 -307.12 10762.23 181.64 0.63 133 14403.00 91.23 223.92 95.00 6214.03 7902.29 -10825.89 -373.38 10832.33 181.98 0.67 134 14493.00 91.47 224.76 90.00 6211.91 7992.26 -10890.24 -436.26 10898.97 182.29 0.97 135 14588.00 91.54 225.70 95.00 6209.42 8087.22 -10957.12 -503.68 10968.69 182.63 0.99 IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis 136 14681.00 91.65 226.07 93.00 6206.83 8180.18 -11021.83 -570.43 11036.58 182.96 0.41 137 14772.00 91.44 225.98 91.00 6204.38 8271.13 -11084.99 -635.89 11103.22 183.28 0.25 138 14864.00 91.37 226.19 92.00 6202.12 8363.09 -11148.79 -702.14 11170.87 183.60 0.24 139 14956.00 91.06 226.13 92.00 6200.17 8455.06 -11212.49 -768.49 11238.80 183.92 0.34 140 15047.00 90.75 225.24 91.00 6198,73 8546.04 -11276.06 -833.59 11306.83 184.23 1.04 141 15141.00 91.13 225.46 94.00 6197.19 8640.03 -11342.11 -900.45 11377.80 184.54 0.47 142 15230.00 91.30 225.29 89.00 6195.30 8729.01 -11404.62 -963.78 11445.27 184.83 0.27 143 15323.00 91.64 225.82 93.00 6192.92 8821.97 -11469.71 -1030.15 11515.88 185.13 0.68 144 15416.00 91.54 225.89 93.00 6190.34 8914.93 -11534.46 -1096.86 11586.50 185.43 0.13 145 15505.00 91.65 225.61 89.00 6187.86 9003.89 -11596.54 -1160.59 11654.47 185.72 0.34 IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis 146 15599.00 91.61 225.37 94.00 6185.19 9097.85 -11662.41 -1227.60 11726.84 186.01 0.26 147 15692.00 91.68 225.66 93.00 6182.52 9190.81 -11727.55 -1293.92 11798.72 186.30 0.32 148 15785.00 91.82 225.25 93.00 6179.68 9283.76 -11792.76 -1360.17 11870.94 186.58 0.47 149 15880.00 92.54 224,55 95.00 6176.06 9378.69 -11860.00 -1427.18 11945.56 186.86 1.06 150 15970.00 92.60 227.01 90.00 6172.03 9468.59 -11922.70 -1491.61 12015.64 187.13 2.73 IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis ANADRILL SCHLUMBERGER Survey Report 30-Jan-2001 09:37:50 Page 7 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool % depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - (ft) (dog) (dog) (ft) (ft) (ft) (ft) (ft) (ft) (dog) I00f) type type 151 16064.00 92.85 225.83 94.00 6167.56 9562.46 -11987.42 -1559.62 12088.46 187.41 1.28 IMP 6-axis Projeoted to Total Depth: 152 16118.00 92.85 225.83 54.00 6164.87 9616.39 -12025.00 -1598.31 12130.76 187.57 0.00 MWD [(c)2001 Anadrill IDEAL ID6 lC 08] ANADRI LL SCHLUMBERGER Survey report Client ................... : Phillips Alaska, Inc Field .................... : Colville River Well ..................... : CD1-NQ1PH API number ............... : 50-103-20358-70 Engineer ................. : Dammeyer ~OUNTY: .................. : Doyon 19 '~-~TATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor ..... Depth reference --- Permanent datum .......... : MEAN SEA LEVEL Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 56.05 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point .... ~--'~atitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 165.86 degrees 15-Jan-2001 12:47:00 Page 1 of 4 Spud date ................ : 06-Jan-01 Last survey date ......... : 15-Jan-01 Total accepted surveys...: 84 MD of first survey ....... : 0.00 ft MD of last survey ........ : 12741.00 ft Geomagnetic data Magnetic model ........... : Magnetic date ............ : Magnetic field strength..: Magnetic dec (+E/W-) ..... : Magnetic dip ............. : BGGM version 2000 25-Dec-2000 1147.20 HCNT 25.55 degrees 80.55 degrees MWD survey Reference Reference G .............. : Reference H .............. : Reference Dip ............ : Tolerance of G ........... : Tolerance of H ........... : Tolerance of Dip ......... : Criteria 1002.68 mGal 1147.20 HCNT 80.55 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees Corrections -Magnetic dec (+E/W-) ..... : 25.54 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.54 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6 lC 08] RECEIVED JAN 2 2001 Alaska Oil & Gas Cons, Commission Anchorage ANADRILL SCHLUMBERGER Survey Report 15-Jan-2001 12:47:00 Page 2 of 4 Seq Measured Incl Azimuth ~ depth angle angle - (ft) (deg) (deg) 1 0.00 0.00 0.00 2 114.00 0.00 0.00 3 261.00 3.50 168.00 4 446.00 9.20 161.68 5 564.00 14.05 159.71 Course TVD Vertical Displ length depth section +N/S- (ft) (ft) (ft) (ft) 0.00 0.00 0.00 0.00 114.00 114.00 0.00 0.00 147.00 260.91 4.49 -4.39 185.00 444.70 24.90 -23.97 118.00 560.25 48.56 -46.37 Displ +E/W- (ft) 0.00 0.00 0.93 6.76 14.70 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 0.00 0.00 0.00 TIP - 0.00 0.00 0.00 MWD - 4.49 168.00 2.38 GYR - 24.90 164.25 3.10 MWD 6-axis 48.65 162.41 4.12 MWD 6-axis 6 653.00 16.72 157.66 7 743.00 17.11 159.25 8 832.00 16.77 160.12 9 922.00 17.19 159.72 10 1013.00 21.20 159.35 89.00 90.00 89.00 90.00 91.00 646.05 732.16 817.29 903.37 989.29 71.98 -68.35 97.94 -92.71 123.72 -117.02 149.86 -141.71 179.59 -169.73 23.31 32.92 41.93 50.95 61.42 72.22 161.17 3.06 MWD 6-axis 98.38 160.45 0.67 MWD 6-axis 124.31 160.29 0.48 MWD 6-axis 150.59 160.22 0.48 MWD 6-axis 180.50 160.11 4.41 MWD 6-axis 11 1109.00 22.92 164.14 12 1204.00 25.56 168.73 13 1298.00 28.48 170.18 14 1393.00 32.82 170.07 15 1489.00 37.80 167.80 96.00 95.00 94.00 95.00 96.00 1078.27 1164.89 1248.63 1330.33 1408.65 215.53 -203.96 254.50 -241.86 297.11 -283.85 345.39 -331.55 400.78 -385.96 72.65 81.72 89.50 97.81 108.52 216.51 160.39 2.59 MWD 6-axis 255.30 161.33 3.41 MWD 6-axis 297.62 162.50 3.18 MWD 6-axis 345.67 163.56 4.57 MWD 6-axis 400.93 164.30 5.36 MWD 6-axis 16 1584.00 40.37 166.08 17 1679.00 43.03 166.24 18 1775.00 44.98 166.34 19 1870.00 49.11 165.48 20 1966.00 52.93 165.19 95.00 95.00 96.00 95.00 96.00 1482.39 460.66 -444.29 122.08 1553.31 523.85 -505.65 137.19 1622.36 590.53 -570.44 153.00 1687.08 660.05 -637.86 169.93 1747.46 734.66 -710.04 188.83 460.76 164.64 2.94 MWD 6-axis 523.93 164.82 2.80 MWD 6-axis 590.60 164.99 2.03 MWD 6-axis 660.11 165.08 4.40 MWD 6-axis 734.72 165.11 3.99 MWD - 21 2061.00 56.54 166.14 22 2156.00 59.75 166.25 23 2253.00 60.31 165.64 24 2346.00 60.76 164.95 25 2443.00 61.22 165.63 95.00 95.00 97.00 93.00 97.00 1802.30 1852.43 1900.89 1946.63 1993.68 812.21 -785.18 892.89 -863.53 976.92 -945.05 1057.88 -1023.36 1142.71 -1105.41 208.02 227.27 247.68 268.23 289.77 812.27 165.16 3.89 MWD 6-axis 892.94 165.26 3.38 MWD 6-axis 976.96 165.31 0.79 MWD 6-axis 1057.93 165.31 0.81 MWD 6-axis 1142.76 165.31 0.78 MWD 6-axis 26 2537.00 61.25 165.89 27 2633.00 61.27 165.90 28 2725.00 61.16 166.12 29 2820.00 61.30 166.28 30 2918.00 61.12 165.33 94.00 96.00 92.00 95.00 98.00 2038.91 2085.07 2129.37 2175.09 2222.29 1225.11 -1185.28 1309.28 -1266.92 1389.91 -1345.16 1473.18 -1426.03 1559.07 -1509.29 310.04 330.55 350.04 369.91 39~.97 1225.16 165.34 0.24 MWD 6-axis 1309.33 165.38 0.02 MWD 6-axis 1389.96 165.41 0.24 MWD 6-axis 1473.22 165.46 0.21 MWD 6-axis 1559.10 165.48 0.87 MWD 6-axis RECEIVED [(c)2001 Anadrill IDEAL ID6_IC_08] Alaska Oil & .Gas, Cons. Commission ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 15-Jan-2001 12:47:00 TVD Vertical Displ depth section +N/S- (ft) (ft) (ft) 31 3013.00 61.42 166.25 95.00 2267.96 32 3109.00 61.67 165.82 96.00 2313.70 33 3203.00 62.06 165.05 94.00 2358.02 34 3308.00 61.09 166.63 105.00 2408.01 35 3499.00 60.17 164.59 191.00 2501.69 36 3689.00 59.81 168.15 190.00 2596.74 ~ 37 3880.00 62.73 166.12 191.00 2688.55 38 4070.00 62.08 167.58 190.00 2776.56 39 4258.00 62.23 165.79 188.00 2864.38 40 4452.00 62.38 165.77 194.00 2954.54 3042.67 3131.84 3227.22 3323.91 3420.29 41 4642.00 62.35 165.84 190.00 42 4829.00 60.69 165.24 187.00 43 5021.00 59.74 164.88 192.00 44 5213.00 59.78 165.37 192.00 45 5403.00 59.26 165.09 190.00 46 5594.00 59.46 165.23 191.00 3517.63 47 5784.00 59.85 164.25 190.00 3613.62 48 5974.00 60.68 165.05 190.00 3707.86 49 6166.00 60.98 164.97 192.00 3801.44 50 6356.00 60.34 164.97 190.00 3894.54 51 6546.00 59.28 164.67 190.00 3990.08 "~' 52 6737.00 59.88 165.87 191.00 4086.79 53 6927.00 60.25 165.59 190.00 4181.61 54 7117.00 59.29 165.33 190.00 4277.27 55 7306.00 60.36 165.25 189.00 4372.26 56 7498.00 61.01 166.28 192.00 4466.27 57 7687.00 61.22 168.34 189.00 4557.58 58 7878.00 60.62 167.72 191.00 4650.41 59 8069.00 59.87 167.32 191.00 4745.20 60 8259.00 60.47 168.10 190.00 4839.71 [(c)2001Anadrill IDEAL ID6_1C_08] Displ +E/W- (ft) 1642.37 -1590.04 1726.77 -1671.95 1809.66 -1752.18 1902.00 -1841.71 2068.43 -2002.92 411.42 431.79 452.63 475.23 516.58 2232.92 -2162.78 2400.33 -2326.02 2568.69 -2489.98 2734.89 -2651.74 2906.67 -2818.25 555.35 592.67 630.98 669.27 711.46 3074.99 -2981.43 3239.35 -3140.59 3405.97 -3301.59 3571.83 -3461.91 3735.56 -3620.24 752.74 793.78 836.73 879.31 921.06 3899.88 -3779.09 4063.82 -3937.28 4228.76 -4096.37 4396.39 -4258.32 4562.00 -4418.28 963.15 1006.31 1049.97 1093.34 1136.29 4726.20 -4576.77 4890.89 -4736.06 5055.54 -4895.63 5219.70 -5054.54 5383.08 -5212.57 1179.29 1221.16 1261.75 1302.96 1344.45 5550.48 -5374.84 5715.90 -5536.27 5882.71 -5699.56 6048.45 -5861.46 6213.19 -6022.51 1385.61 1421.96 1456.57 1492.40 1527.48 Page Total displ (ft) At Azim (deg) 165.49 165.52 165.52 165.53 165.54 1642.41 1726.81 1809.70 1902.03 2068.47 2232.94 2400.34 2568.69 2734.89 2906.67 165.60 165.71 165.78 165.84 165.83 3074.99 3239.35 3405.97 3571.83 3735.57 165.83 165.82 165.78 165.75 165.73 3899.90 4063.84 4228.79 4396.43 4562.05 165.70 165.66 165.62 165.60 165.58 4726.27 4890.96 5055.62 5219.77 5383.16 165.55 165.54 165.55 165.55 165.54 5550.57 5715.96 5882.74 6048.47 6213.20 165.54 165.60 165.66 165.72 165.77 3 of 4 DLS (deg/ 100f) 0.91 0.47 0.83 1.61 1.05 1.63 1.79 0.76 0.85 0.08 0.04 0.93 0.52 0.22 0.30 0.12 0.49 0.57 0.16 0.34 0.57 0.63 0.23 0.52 0.57 0.58 0.96 0.42 0.43 0.48 Srvy Tool tool qual type type MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD - MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD - MWD 6-axis ~fWD 6-axis MWD - MWD 6-axis 5fWD 6-axis MWD 6-axis MWD 6-axis RECEIVED JAN 3 2001 Naska Oil & Gas Cons. Commission ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth ~ depth angle angle - (ft) (deg) (deg) 61 8449.00 61.84 168.43 62 8639.00 60.74 168.21 63 8830.00 62.84 166.55 64 9020.00 62.16 166.12 65 9210.00 62.44 165.15 Course length (ft) 190.00 190.00 191.00 190.00 190.00 66 9397.00 62.52 164.87 67 9589.00 62.87 164.36 68 9779.00 61.48 165.08 69 9970.00 62.27 164.02 70 10161.00 61.54 163.67 187.00 192.00 190.00 191.00 191.00 71 10351.00 59.60 164.91 72 10541.00 58.65 163.86 73 10731.00 58.81 163.64 74 10922.00 58.27 166.03 75 11113.00 57.05 165.63 190.00 190.00 190.00 191.00 191.00 76 11303.00 55.39 164.68 77 11491.00 53.25 164.17 78 11682.00 53.63 164.20 79 11873.00 48.74 164.83 80 12063.00 45.81 166.73 190.00 188.00 191.00 191.00 190.00 81 12253.00 45.32 166.51 82 12444.00 45.01 166.20 83 12635.00 45.96 165.48 84 12741.00 45.96 165.48 190.00 191,00 191.00 106.00 TVD depth (ft) 4931.37 5022.64 5112.93 5200.66 5288.98 5375.39 5463.46 5552.15 5642.19 5732.14 5825.49 5923.00 6021.62 6121.31 6223.48 6329.12 6438.77 6552.54 6672.23 6801.13 6934.15 7068.82 7202.73 7276.41 15-Jan-2001 12:47:00 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 6379.46 -6185.45 1561.33 6545.95 -6348.64 1595.06 6714.19 -6512.87 1631.86 6882.71 -6676.63 1671.67 7050.93 -6839.59 1713.41 7216.75 -6999.79 7387.32 -7164.28 7555.31 -7326.36 7723.71 -7488.71 7892.10 -7650.55 Page 8057.50 -7809.84 8220.52 -7966.89 8382.81 -8122.80 8545.69 -8280.03 8707.06 -8436.49 Total At displ Azim (ft) (deg) 6379.46 165.83 6545.95 165.90 6714.19 165.93 6882.72 165.94 7050.94 165.94 8864.96 -8589.14 9017.61 -8736.24 9170.97 -8883.85 9319.70 -9027.21 9459.25 -9162.47 1756.30 7216.76 165.91 1801.56 7387.32 165.88 1845.85 7555.31 165.86 1890.73 7723.71 165.83 1937.61 7892.10 165.79 9594.91 -9294.46 9730.35 -9426.08 9866.54 -9558.14 9942.74 -9631.90 1982.43 8057.52 165.76 2026.32 8220.54 165.73 2071.76 8382.85 165.69 2114.38 8545.73 165.68 2153.88 8707.10 165.68 2194.33 8865.01 165.67 2235.32 9017.68 165.65 2277.13 9171.04 165.62 2316.88 9319.79 165.61 2351.21 9459.34 165.61 2382.61 9594.99 165.62 2414.56 9730.42 165.63 2447.88 9866.62 165.64 2466.99 9942.81 165.63 4 of 4 DLS (deg/ I00f) 0.74 0.59 1.34 0.41 0.48 0.14 0.30 0.80 0.64 0.41 1.17 0.69 0.13 1.10 0.66 0.97 1.16 0.20 2.57 1.71 0.27 0.20 0.57 0.00 Srvy Tool tool qual type type MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD - MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD Projected [(c)2001 Anadrill IDEAL ID6_lC_08] RECEIVED JAN 2, 3 00! Alaska Oil & Gas Cons. Cnmmi~i~. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 19, 2001 Mr. Mark D. Myers, Director of Division of Oil and Gas Department of Natural Resources 550 W. 7th Avenue, Suite 800 Anchorage, Alask~.,...9..9~01-3560 R anuq CD1-NQ1: on De~y~,~ ......... .~,,.~.:.,...' ............................ ' ..... '". of Spud Date and Initial Production Reference is made to your letter dated February 5, 2001 giving Phillips Alaska, Inc. approval to, conduct a plan of testing, evaluation and pilot production for the CD1-NQ1 Well. 'In accordance with your.approval, this letter provides notification to Division of the spud date and date of first production from the well, as follows: Spud Date: January 6, 2001 First Production: ., February 11, 2001 If you have any questions, please contact 'me at (907) 263-4465. 'Sincerely, '~"~ ' '/7 ' Eric W.. Reinbold 'Sr.' Staff Reservoir Engineer CC: M. Ireland- Phillips Alaska, Inc. 'Teresa Imm'- ASRC Commissioners- AOGCC ' . RECEIVED FEB 1 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage PHILLIPS Alaska, Inc. A Subsidiary o! PHILLIPS P~I'ROLEUM COMPANY P.O. SOX 100~60 ANCHORAGE, ALASKA 99510-0360 RECEiVED . 15 ?.001 February 14, 2001 Alas 0il & Gas Cons. Commiai0 Ms. Julia M. Heusser, Commissioner Ms. Camille Taylor, Commissioner Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 w. 7th Avenue, Suite 100 Anchorage, Alaska 99,501 -~ --,,, ) RE: Request for Walver to 20 AAC 25.2~- Nanuq CD1-NQ1 i~/.../ ,~~LI x--.~.~___I ___.~.-~ ........ Dear Commiseioners: Phillips Alaska In(:, has recently completed the Nanuq CD1-NQ1 well and Initiated test pro(luction on February t 1, 2001. The initial well test recorded an oil production rate of 463 BOPD and a. gas rate of 6.5 MMscf/d, resulting in a Gas-OiI-Ratio(GOR) or 14,000 scf/stb. The GOR is considerably higher than the solution gas-oil-ratio measured during the Nanuk #2 production test in April of 2000, suggesting .that.the CD1-NQ1 well has intersected or is in close proximity to a Gas-Oil-Contact. By this letter, Phillips Alaska Inc. iS requesting a waiver to the GOR limit imposed by statewide regulation 20 AAC 25.240. Initially, a 3 month waiver iS requested so that tlie production testing can be continued. The production test is a critical element of our ongoing reservoir evaluation activity, 'We will be acquiring a static pressure survey after 1 month of production, and evaluating the impaot of continuing' production on ultimate resewoir performance, Based on the results of this evaluation, we may request an extension of the waiver. Thank you for your prompt oonsideration in this matter, If you have any questionS, please contact me at (907) 263-4465. ' ' Eric W. Reinbold Sr. Staff Reservoir Engineer cc: M. Ireland'- Phillips Alaska, Inc. M, Myers- Director, Division ol~ Oil and Gas Teresa Imm- ASRC MWD/LWD Log Product Delivery Customer Phillips Alaska Inc. Dispatched To: AOGCC Well No CD1-NQ1 Date Dispatche 12-Feb-01 Installation/Rig Do¥0n 19 Dispatched By: Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrosel @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 MWDILWD Log Product Delivery Customer Phillips Alaska Inc. Dispatched To: AOGCC Well No CD1-NQ1 PH Date Dispatche 19-Jan-01 Installation/Rig Doyen 19 Dispatched By: Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) ~L~/,3"o~!5 2 . , .. 'm .., m Received BY~-~.~ia~~~,~ Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrosel @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 S T A T E OF ALASKA TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSER VA TION COMMISSION Chip Alvord Drilling Team Leader Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 PHONE: (907) 279-1433 FAX: (907) 276-7542 Rc: Coiville River Unit CD I-NQ 1 Phillips Alaska, Inc. Permit No: 200-215 Sur Lee: 422'FNL, 2377'FWL, Sec. 5, TI 1N, R5E, UM Btmhole Loc. 1769TNL, 903'FWL, Sec. 17, T1 IN, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you' from obtaining additional permits required by law from Other governmental agencies, and does not authorize conducting drilling operations until all other required. permitting determinations are made. Annular disposal of drilling wastes will not be approved for this . well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing' confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. In accOrdance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (CD1-NQ1 PH) and API number (50-103-20358-70) from records, data and logs acquired for well CD 1-NQ 1. BloWout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the. North Slope'pager at 659-3607. S~incercly, ' _. ~.~ ' ' ~. "-"- l~ahiel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~"~ day of January, 2001 dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Subject: Date: Wed, 3 Jan 2001 16:20:46 -1000 From: "Scott D Reynolds" <SREYNOL2@ppco.com> To: julie_heusser@admin.state.ak, us Phillips Alaska, Inc. requests the Commission expedite the processing of the Permit to Drill for CD1-NQ1. We shortened the drilling operations for CD1-33 and we will be moving to CD1-NQ1 several days in advance of the original timeframe. We would appreciate receiving the permit by this Friday, January 5, 2001. If there are any questions, please contact me at 265-6120 or Scott Reynolds at 265-6253. Sincerely, G. C. Alvord Alpine Drilling Team Leader Phillips Drilling 1 of 1 1/4/01 12:03 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill } lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen~ Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. DF 56' feet Colville River Field 3. Address 6. Property DesigDation Nanuq Reservoir P. O. Box 100360, Anchorage, AK 99510-0360 ADL ~"25559,372097 4. Location of well at sudace 7. Unit or pr6~rty Name 11. Type Bond (see 20 AAC 25.025) 422' FNL, 2377' FWL, $ec.5, T11 N, R5E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 1556' FSL, 1122' FEL, Sec. 8, T11N, R5E, UM CD1-NQ1 59-52-180 At total depth 9. Approximate spud date Amount 1769' FNL, 903' FWL, Sec. '17, T11N, R5E, UM 01/08/2001 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line Alpine CD1- 28 15928 MD feet 903' E. ,of Sec 18 feet 8.4' 294' Feet 2560 6178 TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth ' ' Maximum surface 2099 psig' At total depth (TVD) 2720 at. psig 250' feet Maximum hole angle 90.43° 6140' ' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole casing Weight Grade Coupling Length.. MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC. 3234' 37' 37' ' 327.1' 2400' 591 Sx Arcticset III L & 232 Sx Class G 8.5" 7" 26# L-80 BTC-M 1.1247' 34' 34' 11281' 6193' 170 sxClass G 6.125" 3.5" 9.3# L-80 SLHT 7093' 1'1131' 6174' 14781' 6180' Slotted Liner N/A 3.5" 9.3# L-80 8Rd-Mod 11099' 32' 32' 11131' 6174 Tubing 19. To be completed for Redriil, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size cemented Measured ~e{t~ True Vertical depth Structural.RECE,v ED Conductor Surface Productionlntermediate DEC 1 9 2000 Liner. Perforation depth: measured ' Alaska 0il & 'Gas Cons. CommjSsjor true vertical .AnChorage 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch . Drilling program X, Ddlling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements 'X 21. I hereby certify that the foregoing is true and correct'to the best of my knowledge , . Signed. ~ L,~ ~ Title Drilling Team Leader Date / - ~ ', Commission Use Only PermitNu~r~__~_ ...,~../~..-J APl number ' ¢~ /./~.~_/ ~/' J See letterfor ' 50-/~:):~"' ~--,~'_~~ ~ IAppr°val-dat~ ....OtherC°Verr_equirements ' Conditions of approval Samples required Yes ~ , ~lud Icg r-~'uired Yes Hydrogen sulfide measures Yes N~ Directional survey required ~ ,' No Required working pressure for BOPE 2M 3M ~ 10M 15M by order of Approved'by ORIGI NAE, S IG N E D BY commissioner the commission' Date Form 10-401 Rev. 7,24-89L) .taylor Seamount ,, ORIGINAL ( Alpine- CD1-NQ1PH (Pilot Hole) & CD1-NQ1 Procedure . 2. 3. 4. 5. Install diverter and function test. Pressure test Slip-Loc seals to 400 psi. Move on Doyon 19. Drill 12 1/4 inch hole to the surface casing point at 3271' MD / 2400' TVD. Run and cement 9 5/8 surface casing. N/D diverter. Install casing head. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. RECEIVED DEC 19 2000 Alaska Oil & Gas Cons. Commission Anchorage 6. Drill out 20' of new hole. Perform leak off test. Stop at a 16 ppg EMW FIT if no leak off. . . M/U drilling assembly - PDC bit / MWD/LWD (GR/Res/Dens/Neut). Drill 8 1/2 pilot hole to +/- 100' TVD below the base Alpine (12714' MD / 7241' TVD). RIH with muleshoe / drill pipe. Set a 600', 15.8 ppg Class G cement plug from 12440' to +/- i 1840' MD. P/U and circulate clean. Set a 500', 15.8 ppg Class G balanced cement plug from 11310~ to 10810'. P/U and circulate clean.. 10. 11. Set a 500', 17 pPg Class G balanced cement plug from 10810' to 10310'. P/U t/10310' and circulate clean and P0H 12. 13. 14. 15.. 16. 17. 18. 19. P/U build assembly- MWD/LWD (GR/Res). , , . RIH and tag cement plug. Dress off plug and kick off from +/- 10410' MD. 'Build and turn to the 7" casing point, at 11281' MD./6193' TVD in the Nanuq reservoir.. " Run and cement'7 inch casing' as' per program (Top of cement 1000 feet above the Nanuq reservoir). Install pack-off and test to 5000 psi. .Conduct a LOT down the 9-5/8".x 7'" casing annulus. Freeze 'protect the casing annulus to 2000' TVD.- use 300 bbls fresh water flush prior to 'freeze protecting. Pressure test BOPE to 3500 psi (annular tO 2500 psi). M/U and run the drilling assembly (GR/Res). Pressure test casing to 3500 psi.' Drill' out and perform formation integrity test to 11.0 ppg EMW. Minimum. acceptable leak off to drill ahead is 10.5 ppg EMW. DisPlace well to FIo-Pro drill in fluid. POH. Drill'6 1/8" horizontal section to well TD at 15928' MD./6178' TVD. 20. 21. 22. 23. 24. 25. Displace well to brine and pull out of hole. Run'3 1/2, 9.3# L-80 SLHT Slotted Line~'& ZXP-HMC LTP. P/U 2-3/8" inner Wash string and 'run .inside liner. P/U running/setting tool and RIH with DP to setting depth @ .11,131' MD. Set Liner Top Packer and test'to 2500 psi. POOH.' Run'3 1/2, 9.3 #, L-80 8rd-Mod tubing with'seal assembly, Hydro-Trip Sub, gas lift .mandrels, .Heat Trace, 'SSSV nipple..Space Out and Land Hanger. .. Nipple down BOP. Install wellhead adapter aSsembly. Pressure test adapter assembly tO 5000 psi. . . Test.tubing to 2500 psi / 30 minS.. Test casing annulus to 2500 psi / 30 mins. shear out' valve in lower GLM. Circulate tubing to diesel and install freeze.protection and packer fluid in annulus. ., Set BPV and secure well: Move rig off. Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-28 will be the closest well to CD1-NQ1 (9.9' at 250' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 8.4' at 294' MD. Drillinq Area Risks: Shallow Hazards: Although the CD1-NQ1 well targets the Nanuq reservoir, the drilling will take place from the CD1 development pad at Alpine. Extensive development drilling has indicated no threat of shallow hazards. There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Although seismic interpretation of the Nanuq formation does not show anomalies that could indicate faulting, faulting within the Nanuq reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material will be utilized to deal with lost circulation should it occur. Additional care and attention will be given to.the higher potential of inducing a kick when drilling, horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD1-NQ1 will be injected .into the annulus of another permitted well on the CD1 pad.. The CD1-NQ1 surface/intermediate casing annulus will' be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD1-NQ1 be permitted for annular Pumping of fluids occurring as a. result of drilling operations, per regulation 20 AAC 25.080. 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 below the base of the Schrader Bluff' Formation (C-30). 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 .= R E C E I'V'E D = 2,998 psi 'Pore Pressure = 1,086 psi DEC '1 9 ;)000 Therefore Differential = 2998 - 1086'= 1912 psi. Alaska 0il & Gas Cons. C0mmissior'. Anchorage 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: wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst ,BurSt 9-5/8" 36 J-55 3 BTC 2,020 Psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4~599'psi 7,240 psi. 6,154 psi CD1-NQ1 & CD1-NQ1 PH DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing point - 8 Y2" Section - 6 1/8" casing point- 12 Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0 ppg PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 10 % Glycol 5 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surfaCe interVal. Keep flowline viscosity at +_ 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing..Maintain mud weight < 916 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 Alpine 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 Iow drill solids (by diluting as required)'will all be .impOrtant in maintaining wellbore stability. .. Production Hole Section · . .The horizontal production interval will be drilled.with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 10% KCl, with + 30PPB calcium .carbonate bridging material to minimize formation damage. FIo-Vis ' 'Polymer and DuaI-FIo starch will be used for viscosity and fluid loss control respectively. 5% glycol will be used to stabilize the shale sections. .. RECEIVED DEC 'l 9 2000 Alaska Oil'& Gas Cons. Commissior, · Anchorage ,,. Colville River Field CD I-NQ1 Pilot Hole- Prior to Sidetracking RKB - GL - 37' Updated 12/05/00 Wellhead 16" Conductor to 114' 9.8 ppg drilling mud in hole I Top Nanuq (Albian 9'6) Reservoir at 11105' MD / 6196' TVD Top Alpine Reservoir at 12440' MD / 7056' TVD Pilot Hole TD at 127'14, MD / 7241' TVD (+/- 47.5 deg inc.) · > Cement Plug , 9-5/8" 36 ppf J-55 BTC Surface Casing @ 3272' MD / 2400' TVD cemented to surface Piuq #3: 500', 17 pp.q to cover the Albian-96 when in place (top at +/- 10310') Top of cement plug #3 dressed off to 10410' MD / 5859' TVD (+/- 61..02 deg inc.) . 5~1-~ ftBottom . , of Cement Plug #2 at +/- 11310' Top of Cement Plug #1 at +/- 11840' RECEIVED. DEC 19 2000 Alaska 0il & Gas Cons. Commission Anchorage ' III Colville River Fielc~"'' CD1-NQ1 (Liner Top packer to TD) .i:.".,'k ,, i~.,::' ,, 16 Conductor to 114' ;i;;"i? 9-5/8 36 ppf J-SS BTC ~ Surface Casing @ 3272' MD / 2400' TVD cemented to surface Production Well Completion Plan Updated 12/06/00 Completion (Tops) ZXP-HMC LTP 3-1/2" TBG 3-1/2" 9.3# SLHT, Slotted Liner (3500' of Slotted Liner) 11131' 11281' TvD 6'174' 6193' ' RECEIVED DEc 19 2000 TOC @ +/- 10281' MD (1000' MD above top Nanuq Baker ZXP-HMC Liner Top Packer at +/- 11131' AlaSka 0il & Gas Cons, Commissior Anchorage Well TD al 15928' M D 6178' TVD _--_- q) Top Nanuq (Albian-'96) at 11281' MD/ 6193' TVD 7" 26.ppf L-80 BT(3 Mod 'Production Casing @ 11281' MD / 6193' TVD @ 87 deg' 3-112" 9.3# SLHT Slotted .Liner TD at' 14781' MD / 6180' TVD Colville River 'Field CD1 -NQ1 Production Well Completion Plan (Liner Top packer to Surface) : ' i i 16" Conductor to 114' /.'.'."! I ~'lala''~ I I~!'.::.=t 3-v2,,SSSVUipple at 1700'TVD DEC 1c) 2000 ! ':' '~ I I I ~ ~'::":":"!"1 : 'lS/~!'at~°on. oS4l;'e;~s control lines Alaska Oil & Gas Cons. CommissJop /II*° @ 3272' MD / 2400' TVD installed later cemented to surface Packer Fluid mix: 9.6 ppg KCl Brine GLM at 3400' TVD for E Dummy with 2000' TVD diesel cap Tubing Supended with diesel to lowest GLM 3-1/2" 9.3 ppf L-80 EUE 8rd Mod. R2 tubing run with Jet Lube Run'n!Seal .pipe dope GLM at 5200' TVD for E Dummy GLM set 2 joints above the X landing nipple ' \ \ ~, ~ Baker ZXP-HMC Liner Top Packer \~%~~,,,,~,//,,/\ ...~\ \ ~ ' at +/- 11131' ~ , ~~ Seal Assembly , TOC'@ +/- 10281' MD (1000' MD above top Nanuq Top Nanuq (Albian-96) at 11281' MD/ 6193' TVD Completion MD TVD Tubing Hanger 32'. 32' 3-1/2", 9.3#/ft, 8rd-Mod Tubing .. SSSV Nipple 1896' 1700'' 3-1/2", 9.3#/ft, 8rd-Mod Tubing GLM (3.909" ID) 5335 3400' 3-1/2", 9.3#/ft, 8rd-Mod Tubing GLM (3.909" ID) .9051' 5200' 3-1/2", 9.3#/ft, 8rd-Mod Tubing GLM'(3.909" ID) 10709' 6018' 3-1/2" tubing joints (2) HES"X" Nipple 1'0791' 6059' 3-1/2" tubing joint (8) Hydro-Trip Sub 11119' 6171' 3-1/2" 10' pup joint 'Seal' assembly 11131' 6174' . , Well TD at 15928' ,MD,/ 6178' TVD, .i 7"'26 ppf L-80' BTC Mod Production Casing @ 11281' MD / 61931' TVD @ 87 deg .3-1/2" 9.3# SLHT Slotted Liner TD at 14781' MD./'6180' TVD CD1-NQ1 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 Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 114 / 114 10.9 52 53 9 5/8 2401 / 2400 14.5 1086 1532 7" 11281 / 6193 11.0 2719 2099 N/A 15928 / 6178 11.0 2712 N/A · NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a. gas gradient to the sudace, 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) - 0.1ID' . Where:' ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of cas!ng seat in ft RKB OR ., 2) ASP = FPP-(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS. .1. Drilling below conductor casing (16") 'R'ECE, IVED DEC 'Ic) 2000 Alaska 0il & Gas cons, Commissior Anchorage ASP = [(FG x 0.052)-0.1} D = [(10.9 x 0.052) -0.1] x 114 = '53. psi OR ASp = FPP- (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below'surface casing (9.5/8") . ASP = [(FG x 0,052)-0,1}. D = [(14,2 x 0,052) - 0,1] x 2400 = 1532 psi OR ASP = FpP - (0,1 x D) . = 2719- (0,1 x 6193')' 2099 psi Drilling below intermediate casing (7") . . AsP = FPP- (0,1 x D) = 3184 - (0',1 x 7036') = 2480 psi ( (' t Alpine, CD1-NQIPH Cementinq Requirernen s CD1-NQIPH Cement Plug #1 · 12440' MD to 11840' MD = 600'. Cement with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. Slurry: 600' X 0.3941 ft3/ft X 1.15 (15% excess) = 272 ft3 => 235 Sx @ 1.16 ft~/sk CD1-NQIPH Cement Plug #2: 11310' MD to 10810' MD 500. Cement with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. Slurry: 500' X 0.3941 ft~/ft X 1.15 (15% excess) = 227 ft~ => 196 sx @ 1.16 ft~/sk CD1-NQIPH Cement Plug #2: 10810' MD to 10310' MD 500. Cement with Class G + additives @ 17 ppg. Assume 15% excess on Open hole volume. Slurry: 500' X 0.3941 ft3/ft X 1.15 (15% excess) = 227 ft~ => 227 sx @ 1.00 'ft~/sk RECEIVED DEC 19 2000. Alaska 0ii & Gas Cons. C0mmissio~ Anchorage, For B Reynolds Phillips Alaska, Inc. Structure: CD~I Well: HQ1PH Field: Alpine Fiold Loaation: North Slope, Alaeka East (feet) -> 5600 4900 4200 3500 2800 2100 1400 700 0 700 1400 2100 2800 ~§00 4200 4900 5600 6300 i i i i i i i I I I I I I I ! i I i i ! ! i i i i ! i i i i i i I SURFACE LOCATION: 422' F'NL. 2377' FWL SEC. 5, T11N, RSE Bid/Tm Base Permafrost West 0-40 ,g_5~/08 Casing Pt, 16,5.86 AZIMUTH 9918' (TO PH TD) *~Plane of Proposal*~ TRUE K-3 K-2 I CD1-NQ1 TA~ET I' . ' B~;, ~,~0~,7~ ' . I 1556' FSI., 1122' EEL I ~ . ~ ~ . I SEC. 8, T11N, RSE '1 . .B~. BId~rn to lgt ~ ' Tgt-DsgP,-Nan~lbg6 ~ ~ TOt-~g. Drop-~b-96 ~ ./' ~ Kupamk ~" Alp;ne , ,,. . ~ . , ' ~-<~ ~ I ~'" . ' sec. ~7..?~.~,. ~t I ~/~ _ c,, .t. ' ' .RECEIVED ., DEC 19 2000 700 700 1400 2100 28O0 35OO 49O0 56O0 706o 77D0 9100 gso0 1O500 1120O 11900 12600 1330O Alaska Oil & Gas Cons. Commissior Anchorage 0 5250 55OO 7280 7513O 77.5O Creotoa by e, mT~boo, FOr: H llejPnolds Dote plottad: 4-Dec-2000 Pio~ Refo~nce la NQt VomiS. Coordlflot# om i,, ~ mf. mf~ eiot Phillips Alaska,. Inc. . Struoturo: CD#I Well: field: Alpine field Looaflon: Nort-h Slope, Alaska ees. 13 AZIMUTH 0415' (TO TI)) ***Plofle of Proposol*** xqk ~ ~'~v,' TARGET ANGLE ~"~gi;-Drop/Tur fl 9v' ~ ~ 'Eec ~o* ~ Bee. BId~rn to Tgi ~ ' ~ 51.00 D~: 3.00 ~g ~r 100 ft ~48.00 Kuporuk ' ~Alpln8 Bose Alpifle ID . TANGENT ANGLE 90.43 .DEG I I I I I I I I [ I I I I 4000 4250 4500 4750 5(X)O 5250 5500 I I I ! I I I I I I I I I I I I I I 8C~ ,5750 5000 15200 6500 6750 70110 7250 7500 7750 Vertical Section (feet) -> Azimuth 225.15 with reference 0.00 N, 0.00 ir from slot #29 FINAL ANGLE 90..13 DEG I I I / I I I I I I I I I 6250 8500 8750 go00 9250 9500 97 60O 6OO 1200 1600 2400 "~ 3600 ~) 4200 480O I V 84o0 6000 660O 7200 780O 'lPhillips Alaska, Inc. $truature: CD#I Well: NQIPH : Field: Alpine Field Locotlon: Nodh Slope, Alaska ~l.d ~ I.~lahad . Yor B ]le~mo]d. I ' RKB Elevation: 56' ~ ~gin BId~rn 7.47 13.46 ~ I ' lg,45 D~: 3.00 deg per 100 ~ 25.45 ~ ~7.4~ ,43 45 Bass P. er_m.ofrost ~t9.45 West =OK - 58~4~Cr., ' - ~ C-40 - - . . ~ 9 §/B Casing Pt. - v ~ C-30 . ~ - 165.86 AZIMUTH ~ 99,1.8' (TO PH Tn) ~ *~Plane of Proposal*** TANGENTANCLE-~ "-~' ' . ' ' , '. ' .. Tgf.-Beg.Orop-AIb-96 '£0 · Kuparuk' - . FINAL ANGLE ~U~.l~lne ....... % Base Alpine 4?.b~ DEG 'r:~ 'TD . i i i , i i i i i i i I i i i i i i i i i i i i i i i i i i -i .i i i. i I i i i i I i 600 0 600 1200 1800 2400 ;~X)O 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 Vertical Section (feet) -> Azimuth 165.86 with reference 0.00 S, 0.00 £ from slot #29 . b~ ~c~t For: Date pbtted: 4-~ ~ot ~m~ ~ ~1 Ve~ ~N are in f~ ~lmP~ Phillips Alaska, Inc. 'Struoture: CD~I Well: HQ1 'field: Alpine field Looation: North Slope, Alaska 'Point Begin Drop/Turn EOC .Beg. BId/Trn to Tgt Tgt-CsgPt-NanqAIb96 EOC Beg. Fnl Orp/Trn EOC TD.- Csg Pt. PROFILE COMMENT DATA MD Inc Dir TVD North East 0410.00 '61.02 . 165.94 5859.29. -7846.05 1976.72 10481.03 57.02 171.76 5895.87 -7905.75 1988,55 10648.00 57.02 171.76 5986.76 -8044.35 2008.61 11281.25 87.00 223.72 6193.00 -8580.70 1811.62 11624.56' .90.43 223.72 " 6200.69 -8828.72 1574.44 14004.48 90.43- 223.72 6182.71 -10548.70 -70.36 14149.09 . . 15927.90' 90.13 225.13 6182.00 -10651.97 -171.58 90.13 ' 225:13 6178.00 -11906.85 -1452.33 V. Sect Deg/1 O0 4134.47 0.00 4168.20 9.00 4251.77 0.00 4769.78 9.O0 5112.84 1.00 7491.98 0.00 7636.57 1.00 9415.38 0.00 [ Cr~d W I~.k~,~ i'm': El ! Coora"matn are in '~.~t r~.rence ~ IZg.. Point KOP Begin BId/Trn Base Permafrost West Sak EOC C-40 9 5/8 Casing Pt. C-30 K-3 K-2 Albion-g7 Tgt-Beg. Drop-AIb-96 EOC HRZ Kuporuk Alpino Base Alpine TD Phillips .Alaska, Inc. S*iru~lur~: CD~I Well: NQ1PH Field: Alpine Field Loaaflon: North Slope, Alasko PROFILE COMMENT MD Inc Dir 250.00 0.00 0.00 366.67 3.50 156.00 1687.50 43.07 165.62 1829.46 47.33 165.71 2285.67 61.02 1 65.94 2850.28 61.02 165,94 3271.27 61.02 1 65.94 3283.65 61.02 165.94 6172.80 61.02 1' 65.94 6688.72 61.02 165.94 10300.1 6 61.02 165.94 11104.97 61.02 1 65.94 11555.00 47.52 1 65.94 11699.79 47.52 1 65.94 12158.79 47.52 1 65.94 12440.11 47.52 1 65.94 12552.63 47.52 165.94 12714.02 47.52 165.94 TVD 250.00 366.60 1556.00 1656.00 1922.41 2196.00 2400.00 2406.00 3806.00 4056.00 5806.00 6195.99 6458.21 6556.00 6866.00 7056.00 7132.00 7241.00 DATA North 0.00 -3.25 -496.80 -594.37 -952.1 6 -. -1431.27 - 1788.50 - 1799.01 -4250.60 -4688.39 -7752.88 -8435.80 -8789.35 -8892.93 -9221.28 -9422.53 -9503.03 -9618.48 East 0.00 1.45 135.24 1 60.17 250.46 ,370.43 459.89 462.52 1076.41 1186.04 1953.40 2124.41 2212.94 2238.88 2321.10 2371.49 2391.65 2420,56 V. Sect 0.00 3.51 514.78 615.49 984.50 1478.39 1846.66 1857.49 4,384.77 4836.08 7995.18 8699.19 9063.65 91 70.43 9508.92 971 6.38 9799 9918.38 Deg/1 O0 0.00 3.00 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.00 0.00 0.0~ 0.0~ 0.00 0.00 Phillips Alaska, Inc. CD#i NQIPH slot #29 Alpine Field North Slope, Alaska RECEIVED DEC 9 ?.000 Alaska Oil & Gas Cons. Commission Anchora~le PROPOSAL LISTING by Baker Hughes INTEQ .Your ref : NQ1PH1 Vets#5 Our ref : prop3529 License : Date printed : 4-Dec-2000 Date.created = 11-Aug-1999 Last revised = 4-Dec-2000 Field is centred on nT0 20 37.100,w150 51 37.53 Structure ks centred on ~70 20 37.100,w150 56 46.041 Slot location is n70 20 32.847,w150 55 36.558 Slot Grid'=oordinates are N 5975707.126, E 385802.188 Slot'local coordinates are 421.89 S 2378.46 E Projection type: alaska - zone 4, .Spheroid: Clarke - 1866 Reference North ks True North. Phillips Alaska, ~nc. CD#1,NQIPH Alpine Field,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 300.00 1.50 156.00 299.99 366.67 3.50 156.00 366.60 400.00 4.49 158.29 399.85 500.00 7.47 161.51 499.29 600.00 10.46 162.90 598.06 700.00 13.46 163.67 695.88 800.00 16.46 164.17 792.48 900.00 19.45 164.52 887.60 1000.00 22.45 164.77 980.97 1100.00 25.45 164.97 1072.35 1200.00 28.45 165.13 1161.48 1300.00 31.45 165.27 1246.12 1400.00 34.45 165.38 1332.03 1500.00 37.45 165.47 1412.97 1600.00 40.45 165.55 1490.73 1687.50 43.07 165.62 1556.00 1700.00 43.45 165.63 1565.10 1800.00 46.45 165.69 1635.87 1829.46 47.33 i65.71 1656.00 1900.00 49.45 165.75 1702.84 2000.00 52.45 165.81 1765..84 2100.00 55.45 165.86 1824.69 2200.00 58.45 165.90 1879.23 2285.67 61.02 165.94 1922.41 2500..00 61.02 165.94 2026.26 2850.28 61.02 165.94 2196.00 3000.00 61.02 165.94' 2268.55 3271.27 61.02 1'65.94 2400.00 3283.65 61.02 165.94 2406.00 3500.00 61.02 165.94 2510.84 4000.00 61.02 165.94 2753.12 4500.00 61.02 165.94' 2995.41 5000.00 61.02 165.94 3237.69 5500.00 61.02 165.94 3479.98 6000.00 61.02 165.94 3722.26 6172.80 61.02 165.94 3806.00 6500.00 61.02 165.94 3964.55 .6688.72 61.02 165.94 4056.00 7000.00 61.02 165.94 4206.84 7500.00 61.02 165.94 4449.12 8000.00 61.02 165.94 4691.41 8500.00 . 61.02 165.94 4933.69 9000.00 61.02 165.94 51.75.98 9500.00 61.02 165.94. 5418.26 10000.00 61.02 165.94 5660.55 10300.16 61.02 165.94 5806.00 10500.00 61.02 165.94 5902.84 11000.00 61.02 165.94 6145.12 RECTANGULAR COORDINATES 0.00S 0.00£ 0.00N O.00g 0.60S 0.27£ 3.25S 1.45E 5.40S 2.35E 15.20 S 5.85 30.04 S 10.59 49.89 S 16.53 74.69 S 23.67 104.37 S 31.98 138.85S 41.44E 178.04S 52.03E 221.82S 63.71E 270.08S 76.46E 322.69S 90.24E 379.50 S 105.01 440.36S 120.74 496.80S 135.24 505.09S 137.37 573.53S 154.86 594.37S 160.17E' 645.48S 173.17E 720.75S 192.24E 799.13S 212.03E 880.40S 232.47E 952.16 S 250.46E 1134.03S 296.00E 1431.27S 370.43E 1558.31S 402.25E 1788.50S 459.89E 1799.01 S 462.52 1982.59S 508.49 2406.86S 614.73 2831.14S 720.97 3255.'42 S 827.21 3679.69 S 933.45 E 4103.97 S 1039.69 E 4250.60S 1076.41E 4528.25S 1145.93E 4688.39S 1186.04E 4952.52 S 1252.18 E 5376.80S ' 1358.42E 5801.07S 1464.66E 6225.35S 1570.90E 6649.63S 1677.14E 7073.90 S 1783.38 E 7498.18 S 1889.62 E 7752.88S 1953.40E 7922.46S 1995.87E 8346.73S 2102.11E PROPOSAL LISTING Page 1 Your ref = NQ1PH1 Vets#5 Last revised : 4-Dec-2000 Dogleg Deg/100ft 0.00 0.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 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.O0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vert Sect 0.00 0.00 KOP 0.64 3.51 Begin Bld/Trn 5.80 16.17 31.72 52.42 78.21 109.02 144.77 185.35 230.67 280.58 334.96 393.66 456.51 514.78 Base Permafrost 523.35 593.98 615.49 West Sak 668~23 745.87 826.71 910.52 984.50 EOC 1171.99 1478.39 C-40 1609.36 1846.66 9 5/8" Casing Pt. .1857.49. C-30 2046.74 2484.11 2921.49 3358.86. 3796.24 4233.61 4384.77 K-3 .4670.99 4836.08 K-2 5108,36 5545.74 5983.12 6420.49 6857.87 729512'4 7732.62 7995.18'Alhian-97 8169.99 8607.'37 RECEIVED DEC 7 9 2000 Alaska Oil & Gas Cons. Commission Anchorage All data is in feet unless.otherwise stated. Coordinates from slot #29 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level), Bottom hole distance is 9918,38 on azimuth 165,87 degrees from wellhead, Total Dogleg for wellpath is 74.57 degrees, vertical section is from wellhead on azimuth 165,86 degrees. Calculation uses the minimum curvature method, Presented by Baker.Hughes,INTEQ Phillips Alaska, Inc. CD#1,NOiPH Alpine Field, North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : N01PH1 Vets#5 Last revised : 4-Dec-2000 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 00 R D I N A T E S Deg/100ft Sect 11104.97 61.02 165.94 6195.99 8435.80 S 2124.41 E 0.00 8699.19 11105.00 61.02 165.94 6196.00 8435.83 S 2124.42 E 0.00 8699.21 11138.85. 60.00 165.94 6212.67 8464.41 S 2131.57 E 3.00 8728.68 11238.85 57.00 165.94 6264.91 8547.11S 2152.28 E 3.00 8813.93 11338.85 54.00 165.94 6321.54 8627.05 S 2172.30 E 3.00 8896.34 11438.85 51.00 165.94 6382.41 8704.00 S 2191.57 E 3.00 8975.66 11538.85 48.00 165.94 6447.35 8777.75 S 2210.04 E 3.00 9051.70 11555.00 47.52 165.94 6458.21 8789.35 S 2212.94 E 3.00 9063.65 11699.79 47.52 165.94 6556.00 8892.93 S 2238.88 E 0.00 9170.43 12000.00 47.52 165.94 6758.76 9107.69 S 2292.66 E 0.00 9391.82 12158.79 47.52 165.94 6866.00 9221.28 S 2321.10 E 0.00 9508.92 12440.11 47.52 165.94 7056.00 9422.53 S 2371.49 E 0.00 9716.38 12500.00 47.52 165.94 7096.45 9465.38 S 2382.22 E 0.00 9760.55 12552.63 47.52 165.94 7132.00 9503.03 S 2391.65 E 0.00 9799.37 12714.02 47.52 165.94 7241.00 9618.48 S 2420.56 E 0.00 9918.38 Tgt-Beg. Drop-Alb-96 Nanuq PH1 Tgt Rvsd 13-Nov-00 EOC HRZ Kuparuk Alpine Base Alpine TD RECEIVED DEC 1 9 2000 Alaska Oil & 'Gas Cons. Commission, Anchorage All data is in feet unless otherwise'stated. Coordinates from slot #29 and TVD £rom RKB '(Doyon 19) (56.00 Ft above mean sea level).. Bottom hole distance is 9918.38 on azimuth 165.87 degrees from wellhead. Total Dogleg for wellpath is 74.57 degrees. . vertical section is from wellhead on azimuth 165.86 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes IHTEQ ' Phillips Alaska, Inc. CD#I,NQIPH Alp/ne F/eld, North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : NO1PH1 Vets#5 Last revised : 4-Dec-2000 Comments in wellpath MD TVD Rectangular Coords. Comment 250.00 250.00 0.00 N 0.00 E KOP 366.67 366.60 3.25 S 1.45 E Begin Bld/Trn 1687.50 1556.00 496.80 S 135.24 E Base Permafrost 1829.46 1656.00 594.37 S 160.17 E West Sak 2285.67 1922.41 952.16 S 250.46 E EOC 2850.28 2196.00 1431.27 S 370.43 E C-40 3271.27 2400.00 1788.50 S 459.89 E 9 5/8" Casing Pt. 3283.65 2406.00 1799.01S 462.52 E C-30 6172.80 3806.00 4250.60 S 1076.41E K-3 6688.72 4056.00 4688.39 S 1186.04 E K-2 10300.16 5806.00 7752.88 S 1953.40 E Albian-97 11104.97 6195.99 8435.80 S 2124.41E Tgt-Beg. Drop-Alb-96 11105.00 6196.00 8435.83 S 2124.42 E Nanuq PH1Tgt Rvsd 13-Nov-00 11555.00 6458.21 8789.35 S 2212.94 E EOC 11699.79 6556.00 8892.93 S 2238.88 E HRZ 12158.79 6866.00 9221.28 S 2321.10 E Kuparuk 12440.11 7056.00 9422.53 S 2371.49 E Alpine 12552.63 7132.00 9503.03 S 2391.65 E Base Alpine 12714.02 7241.00 9618.48 S 2420.56 E TD t £CEIVED DEC 1 9 2000 41aska Oil & Gas Cons. Co,~nissior Anchorage Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bo= MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00S 0.00E 3271.2.7 2400.00 1788.50S 459.89E 9 5/8" 0.00 0.00 0.OOS 0.00E 11281.30 6288.42 8581.40S 2160.87E 7" Casing Targets associated with ~h2s wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised Nanuq PH1Tgt Rvsd i 387795.000,5967240.000,0.0000 6196.00 8435.83S 2124.42E 13-Nov-2000 Phillips Alaska, Inc. CD#1 NQ1 slot %29 Alpine Field North Slope, Alaska R£C£1v£D DEC 192000 Oil & Gas Cons. AnChorage C°mr~issior PROPOSAL LI'ST I NG by Baker Hu~;hes INTEQ , Your ref : NO1 Vets#5 Our ref : prop3039 License : Date printed : 4-Dec-2000 Date. created : '1-Ju1-1998 Last revised : 4-Dec-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 32.947,w150 55 36.558 Slot Grid coordinates are N 5975707.126, E 385802.188 Slot local coordinates are 421.89 S 2378.46 E Projection type: alaska - Zone 4,.Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. CD#1,NQ1 Alpine Field, North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T Depth Degrees Degrees Depth C O O R 0.00 0.00 0.00 0.00 0.00 100.00 0.00 156.00 100.00 0.00 200.00 0.00 156.00 200.00 0.00 250.00 0.00 156.00 250.00 0.00 350.00 3.00 156.00 349.95 2.39 366.67 3.50 156.00 366.59 3.25 400.00 4.49 158.29 399.85 5.40 500.00 7.47 161.51 499.29 15.20 600.00 10.46 162.90 598.06 30.04 700.00 13.46 163.67 695.88 49.89 800.00 16.46 164.17 792.48 74.69 900.00 19.45 164.52 887.60 104.37 1000.00 22.45 164.77 980.97 138.85 1100.00 25.45 164.97 1072.35 178.04 1200.00 28.45 165.13 1161.48 221.82 1300.00 31.45 165.27 1248.12 270.08 1400.00 34.45 165.38 1332.03 322.69 1500.00 37.45 165.47 1412.97 379.50 1600.00 40.45 165.55 1490.73 440.36 1700.00 43.45 165.63 1565.10 505.09 1800.00 46.45 165.69 1635.87 573.53 1900.00 49.45 165.75 1702.85 645.48 2000.00 52.45 165.81 1765.84 720.75 2100.00 55.45 165.86 1824.69 799.12 2200.00 58.45 165.90 1879.23 880.40 2285.67 61.02 165.94 1922.41 952.16 2500.00 61.02 165.94 2026.27 1134.03 3000.00 61.02 165.94 2268.56 '1558.30 3500.00 61.02 165.94.'2510.85 1982.58 4000.00 61.02 165.94 2753.14 2406.85 4500.00 ' 61..02165.94 2995.43 2831.13 5000.00 61.02 165.94 3237.72 3255.40 5500.00 61.02 165.94 3480.01 3679.68 6000.00 61.02 165.94 3722.29 4103.95 6500.00 61.02 165.94 3964.58 4528.23 7000.00 61.02 165.94 4206.87 4952.50 7500.00 61.02 '165.94 4449.16 5376.78 8000.00 61.02 165.94 4691.45 5801.05 8500.00 61.02 165.94 4933.74 6225.33 .9000..00 61.02 165.94 5176.03 6649.60 9500.00 61.02 165.94 5418.32 7073.87 10000.00 61.02 165.94 5660.61 7498.15 10410.00 61.02 165.94 5859.29 7846.05 10481.03 57.02 171.76 5895.87 7905.73 10500.00 '57.02 171.76 5906.19 7921.48 10648.00 57.02 171.76. 5986.76 8044.35 10700.00 58.75 176.90 6014.42 8088.16 10800.00 62.61 186.23 6063.47 81'75.15 10900.00 67.04 194.89 6106.06 8263.96 11000.00 71.92 202.97 6141.15 8352.40 ANGULAR DINATES S 0.00 E S 0.00 E S 0.00 E S 0.00 E S 1.06 E S 1.45 E S 2.35 E S 5.85 E S 10.59 E S 16.53 E S 23.67 S 31.98 S 41.44 S 52.03 S 63.71 S 76.46 E S 90.24 E S 105.01 E S 120.73 E S 137.37 E S 154.86 S 173.17 S 192.24 S 212.02 S 232.47 S 250.46 S 296.00 $ 402.24 S 508.48 S 614.72 S 720.96 S 627.20 S 933.44 S 1039.68 S 1145.92 S 1252.16 S 135B.40 S 1464.64 S 1570.88 S 1677.12 ~ 1783.36 S ' 1889.60 S' 1976.72 S 19BB.55 S 1990.83 S 2008.61 S 2012.94 S 2010.43 S 1993.75 S 1963.32 PROPOSAL LISTING Page 1 Your ref : NOl Vets#5 Last revised : 4-Dec-2000 Dogleg Deg/100ft 0.00 0.00 0.00 0.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 ,3.00 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 0,00 0.00 0,00 0,00 9.00 0,00 0.00 9,00 9,00 9,00 9,00 Vert Sect 0.00 0.00 0.00 0.00 0.93 1.27 2.14 6.57 13.69 23.48 35.92 50.97 68,59 88.73 111.34 136.35 163.70 193.31 225.11 258.99 294.87 332.66 372.25 413.52 456.37 494.25 590,28 814.31 1038.34 1262.38 1486.41. 1710.44 1934.48 2158.51 2382.54. 2606.57 2830.61 3054.64 3278.67 3502.70 3726.74 3950.77 4134.47 Begin Drop/Turn' 4168.20 EOC 4177.69 4251.77 Beg. Bld~Trn to Tgt 4279.61 4342.76 4417.23 4501.20 All data is in feet unless otherwise stated. Coordinates from slot #29 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 11992.69 on azimuth 186.86.degrees from wellhead. Total Dogleg for wellpath is 129.34 degrees. Vertical section is from S 0.00 B 0.00 on azimuth 225.13 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes' INTEQ Phillips Alaska, Inc. CD#1,NO1 Alpine Field, North Slope, Alaska Measured ln¢lin. Azimuth True Vert Depth Degrees Degrees Depth 11100.00 77.11 210.60 6167.87 11200.00 82.52 217.91 6185.57 11281.25. 87.00 223.72 6193.00 11281.27 87.00 223.72 6193.00 11381.27 88.00 223.72 6197.36 11481.27 89.00 223.72 6199.98 11581.27 90.00 223.72 6200.85 11624.56 90.43 223.72 6200.69 12000.00 90.43 223.72 6197.85 12500.00 90.43 223.72 6194.07 13000.00 90.43 223.72 6190.30 13500.00 90.43 223.72 6186.52 14000.00 90.43 223.72 6182.74 14004.48 90.43 223.72 6182.71 14100.00 90.23 224.65 6182.15 14149.09 90.13 225.13 6182.00 14149.11 90.13 225.13 6182.00 14500.00 90.13 225.13 6181.21 15000.00 90.13 225.13 6180.09 15500.00 90.13 225.13 6178.96 15927.90 90.13 225.13 6178.00 15927.92 90.13 225.13 6178.00 RECTANGULAR COORDINATES 8438.29 S 8519.52 S 8580.70 S 8580.72 S 8652.92 S 1919.87 1864.48 1811.62 1811.61 1742.56 1673.47 1604.36 1574.44 1314.97 969.41 623.85 278.29 67.26 70.36 136.94 171.58 171.60 420.29 774.67 1129.05 1432.33 1432.34 8725.17 8797.44 8828.72 9100.06 9461.41 9822.76 10184.11 10545.46 10548.70 10617.19 10651 10651 10899 11252 11604 .97 S .98 S .52 S .24 S .97 S 11906.83 11906.84 PROPOSAL LZSTING Page 2 Your ref : NQ1 Vets#5 Last revised : 4-Dec-2000 Dogleg Deg/100ft 9.00 9.00 9.00 9.00 1.00 1.00 1.00 1.00 0.00 0.00 0.00 0.00 0.00 0.00 1.00 1.00 1.00 0.00 0.00 0.00 0.00 '0.01 Vert Sect 4592.59 4689.15 4769.78 Tgt-CsgPt-NanqAlb96 4769.80 Nanuq TgtCsgPt Rvsd 13-Nov-00 4869.67 4969.61 5069.57 5112.84 EOC 5488.16 5988.00 6487.83 6987.67 7487.50 7491.98 Beg. Fnl Drp/Trn 7587.48 7636.57 EOC 7636.59 Nanuq TgtIntrmdPt Rvsd 13-Nov-00 7987.48 8487.48 8987.48 9415.38 TD - Csg Pt. 9415.40 Nanuq TgtTD Rvsd 13-Nov-00 .. RECEIVED O£C 1 9 2000., Alaska Oil & Gas Cons. Commissio~ Anchorage Ail data is.in feet unless otherwise stated. Coordinates from slot #29 and TVD from RKB'(Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 11992.69 on azimuth 186.86 degrees from wellhead. Total Dogleg for wellpath is 129.34 degrees. Vertical section is from S 0.00 E 0.00 on azimuth 225.13 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. CD#1,NQ1 Alpine Field, North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : NO1 Vets#5 Last revised : 4-Dec-2000 Comments in wellpath MD TVD Rectangular Coords. Comment 10410.00 5859.29 10481.03 5895.87 10648.00 5986.76 11281.25 6193.00 11281.27 6193.00 11624 56 6200.69 1400448 6182.71 1414909 6182.00 1414911 6182.00 1592790 6178.00 1592792 6178.00 7846.05 7905.73 8044.35 8580.70 8580.72 8828.72 10548.70 10651.97 10651.98 11906.83 11906.84 1976.72 E Begin Drop/Turn 1988.55 EEOC 2008.61E Beg. Bld/Trn to Tgt 1811.62 E Tgt-CsgPt-NangAlb96 1811.61 E Nanug TgtCsgPt Rvsd 13-Nov-00 1574.44 E EOC 70.36 W Beg. Fnl Drp/Trn 171.58 W EOC 171.60 W Nanug TgtIntrmdPt Rvsd 13-Nov-00 1432.33 W TD - Csg Pt. 1432.34 W Nanug TgtTD Rvsd 13-Nov-00 Casing positions in string Top MD Top TVD Rectangular Coords. Rot MD Bot TVD ' Rectangular Coords. Casing 0.00 0.00 0.00S 0.00E 3271.25 2400.00 1788.47S 459.88E 9 5/8" 0.00 0.00 0.00S 0.00E 11281.30 6193.00 8580.74S 1811.59E 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised Nanuq TgtCsgPt Rvsd 387480.000,5967100.000,0.0000 6193.00 8580.72S .. 1811.61E 13-Nov-2000 Nanuq TgtIntrmdPt Rv 385465.000,5965060.000,0.0000 6182.00 10651.98S 171.60W 13-Nov-2000 Nanuq TgtTD Rvsd 13- 384185.000,5963825.000,0.0000 6178.00 11906.84S 1432.34W 13-Nov-2000 RECEIVED 'DEC"7 9,.,2000 41aska Oil & Gas Cons. Comrnissio~ Anchorage k,,ot,d by b~.,~s For: S. Reynolds O~lll plolled: 1-Dec-2000 Plot Relerenca ;I HQ1 VefsJ'~. Coor~;nOtll afl ;n lilt rilelnCl slot 129. ~Truc VCf~;col ~pl~s o~e relemnce RKB (~on 19).~ !~_5~ .................................. Phillips Alaska, Inc. Structure: CD#1 Well : NO1 Field : Alpine Field Locotion : North Slope, Aloskoi ~6oo '330 ~ooo~,ooo TRUE NORTH 550~., ~ [~ 1~.~ 3OO ~oo 50 oo ,. 6O 29O 7O 280 .8O 270 260 9O 100 25O 110 .24© 120 ' 230 130 220, 140 210 150 200 1 6O 190 180 i70 Norma Plane Travelling. Cylinder - Feet' All dept~hs shown are Measured depths on Reference Well RECEIVED DEC 19'2000 Alaska 0il & Gas Cons. Commission. Anchorage iCr.oted ~, bo-e,s For: S. Reynolds Dote plotted: 30-H~,-2000 Plot Reference ;e HQ1 PH1 . Coord~notes ore in leer reference S~Ol J29. ~True Vert~al ~ptha ore refere~e RKB (Ooyon 19).~ Phillips Alaska, Inc. Structure : CD#1 Well: NO1PH Field : Alpine Field Location : North Slope, Alaska <- West (feet)' East (feet) -> 160 140 120 100 80 60 40 20 0 20 40 60 80 100 120 140 60 80 I I I I I I I I I I I I I I I I I I I I I I I ~1 I~ I ~ I I I I 80 ~ ".,.500~ ~ 1000 ~ 60 ~o ~ .......,~oo ~'e ~9oo __~°~°° ' ~o . ' "--...:0oo ~oo o~"-~°;' ~;oo '"- '* ~ ' ....... ~--.]~"',~ 600 ~ 900 ~nn : ~ ouu ~ ___ 700 ........ ~:... 700 "-.. ~ ~ 700 -~ ~00 '~"~- x' ' ............. 15oo .... ~' "' ' ...... e ~ ' %soo~~oo ' . ' ~00 t . ' o~ ..... ' ...... ' ........... ~.oo ~ ....~ e ~,~ ~ '~. [3~ 1 ]uu ........... ~ 130n .' "-~.~ b400~ ~700~800 J~' .............* ......... 1000 ............. -. ~00 ~ ~ ' 'x ~ ............ . .......... 900 so~'"~'x ..... ;-~ 5oog ,)o . N / ........ ~ ........... ~ /:~ =m:~,.~ ' ....... , ............ , , /~ 900 800 ' / ~, ' 60~ 700 ~ '%~ ~ ' I~ ~2o0 ~,~ oo ~ooo_ ..,. ~ ~oo ~;oo~ e . ~oo , ~ ~o ~~::~.:;::::::~::Z~ ................. ~, .~ ~ ~' ,.,~o~'~ ', ~ , ~oo ~, ~ooo .......... ~ .......... · ...... ~- ~--~ ,.,~ ~ ~ , , ~oo ~0o .o ~oo -z~ ~.o,..,'~oo ~o4.oo N 60 ~ ~5800 ~.." 3700 ' ~t N '~.~ ~ ~ "~ ~oo ~ ;oo, ' '~ ~'ooo ~oo ~ ....... ~.. 500 ~ ~ '- ¥ 600 % . 800~ ~ ~ ~o q _ ~.-' ....... ~ .... e ~so~¥~ .~soo . ~ ~ ~ '.,,~ ~ ............... ~ f 400~..~ 4~00 ~ 700 x ~ . ~ .................. , ,.~' ' ~ 900 ~ ..... ~o ..~.~-~- ........... ~ '/.,..,..~ ~o~ ~" ~ .. X,,oo ~oo- ~Oo ~oo _~"'%/~oo,,~ ~,,oo~ ~oo ~,ooo ~ . ~ .......... ~..-....* ........ ;foo.," / .'.' t t ,o& ~1,oo .oo~ooo . ,,o. ,o~?~.' .- ,oo~..,,o0o~ .oo X',~oo ~ / t,ooo ,, ,,oo ,,o , oo ,,oo ,,. ~ '/..'__.~,~oo x /,~oo ,,t . ~oo i ,',' ~u t~ ~ / ",t ' / ."' . I~ t _/~oo ' ' ',.~ · 180 / "' '1 ~ % / '~ t / "6200 I t ~/ ' / , /~4oo ~oo ~oo~ ~oo ' ' ~ooo~ ..' ~ooo~ ~ /' ~ ~ ~ ~oo ' / ~ ' I !~~ ~' . '[ ~ . / " . / /1~oo ~' ~ ~ ' /,/ .' ~/ I ' '~ ~ ~'~ , .' .,., ~ ~ . ~o /. ~.~oo . / / ;~oo ~ , ' / ,. /~1900/ ~ ~' 1200 ~ ~ ~oo/ .' . /" / I ~ ', ~ / ..' ~-~ 1100 ~ ~ ~ t ~ 1300 ~o ' / .,. /'~ooo / I ~ ~oo~ ~' , ..... ..... ....... .... ,,, 40 o 20 40 60 , O 160 140 120 100 80 . 60 40 20 0 20 40 60 80 <- West (feet)· East (feet) -> 0 100 I' ~2o. V 140' 160 . 180 2OO 220 240 26O 1 O0 12'0 140 160 .RECEIVED' DEC 19 2000 Alaska Oil & Gas cOns. Commissior~ ' Anchorage b, b .... For: S. Reynolds Dote plOtted: 30-HDv-2000 Co01d~notll ore in tilt refefenCll slot ~2g. Veftl¢OI ~lplhs ore feterence RKB (Doyon 19).i Phillips Alaska, Inc. 600 200 3OO 400 500 800 700 800 900 "+- ' 1000 11oo 0 1200 1300 1400 1500 1600 1700 1800 1900 600 East (feet) -> o 1 aa 200 300 500 400 300 200 100 400 500 600 700 800 900 I I I I I I I I ~ I i__ I /. I I I I I I I I I I I I I / ' 140~/ ~'"'" '/" , / J 130~ ~ 1400 '-- -..~. /' ' -~ "~300"' ':'~J ~ ~ ~1600 -... .~_ ~.4go0 ,/ ..... ~ Y /¢lou~ ~ It 1500 '~ ~-~1900 ,~°u~ ' /./.-~ .... / . 670~ i 1400e ~ --- ~1700 .... . ~4X" /~700 / . f .... fsuu ~ ~ 1600 ~1800 ~"'- 2100 '~ .~, ~500~ / ~ ',500~ ~ . ~ . . ~.~.l~oo ~ 'j,soo bsoo , ~,700 ~.,~00 -.~ :~. / ~, ~ , k X. '-..~ ~ /,~00 /~ ~ ,~00;m ~soo' N2000 ', ' YlTOO / ~ '~ ~oo ' x ~2~oo · y / ~od., i ~o~ , ~ooo / ~,oo/ I .,.,~ooo,~o~ X,oo . ~oo '',X. ~19oo ~ / ,,, , .23oo '~. ' / e 2500/ .... · , , ~ ~2700 / ' / / i'~200 1900~ k2400 ' , '".2800 ~ . ', ~ ~ . ~~~~700 ~ 2200 ~ ,. ~ ~ . , 2400 ', ~ h2900 / / · , i '. ~ ~ 2500 . 000 2800 3000 3200 !. !. 3500 I 1 oo i i i i ~ i . i i i i i 200 100 0 200 300 400 East (feet) -> 100 ~ 3200 k3300 .\ 3400 3500 ~6o0 ~3700 ~ 3800 . 3.900 ', ~ ", ~)00 i i i i . i i i i i 500 800 700 '800 go0 i / 2600 I ?3000 / / ~ 2700 '/ I ~3100 /2800 . 2900 / ~3000 I I I ~ 3100 I / ,~i2°°, , 500 ,400 300 1 ooo 200 300 400 500 600 700 800 900 0 1000" 1100 1'200 I V 1300 1400 lOOO 15oo 1600 1700 1800 1900 RECEIVED DEC 19 2000, Alaska Oil & Gas. Cons. L;ommissior 'Anchorage (, Dale plottocl: 30-NAY-2000 Phillips Alaska, Inc. Structure : CD//I Well : NQ1PH Field : Alpine Field Location: North Slope. Alaska East (feet) -> 1000 800 600 400 200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 1800 2000 22OO 2400 26OO 2800 3000 ~ 3200 ..C ' .4-. 3400 0 3600 I , V 3600 4000 4200 ! % 4000 00/3200 ~3800 t% .. , ~ ., ~ 4200 /3400. ~3800 't " "~ 4400 I I 260 , \ ~3600. t4000 ,, ., , ~4600 3800 4200 ~ ,. [ % ,. 5000 4400 ~ 2600 . t 46oo "' ~54oo . 4800 . ';.-- 5600 % 3000 ,,..,~ · 5000 5800 52oo .,, ~6ooo ~ 5400 ~ 3200 , 6200 5600 %% , , 5800 ~ 3400 ", ~ 6000 " t 6200 t , " ,. ~ 5400 3600. " [,6600 .,. 6800 7000 k,, '~ 4000 '~ \ ~ 4200 4400 4600 · 4800- 5000- / ~5600 .. ~ 4000 ~ 4200 I '"~4400 / ' ~4~oo [ ,. ! 4800 '., / ', 5000 , ! 5200 ~ 5400 / 5600' /~8oo 6000 ~ i , i , i i . i , 1000 800 600 400 200 ",.'~ 6600 ,\ . ",~ 6800 . 2200 2400 2600 2800 3000 0 3200 C' 3400 ~ 3600 I v 3800 , 4000 4200 k. 4400 ,,, ~ 4600 \ · 4600 5000 .. i'" i i 0 200 400 600 800 1000 1200 1400 , 1600 1800 2000 2200 East (feet) -> RECEIV'ED DEC 19 2000 Alaska Oil & (~as Cons."Commissior Anchorage Dote plotted: 30-Nov-2~ I plot Reierenoe ;a NOt PH1 Varal'.. I Coofdkotes ora ~n feel relerence ami 129. J hue Vert~ol Depths ore relafence RKB (h~fl 19)./ Eel / ........................ 2~J)!~. ................................. 1 4800 5200 Phillips Alaska, Inc.' ..................................................................................................................... ';;;';;-';"";;;;;;;; 1 ............................. 5600 6000 6400 6800 72O0 7600 8000 ~' {..- 8400 0 tJ3 8800 I V 9200 96O0 10000 10400 10800 1.1200 116O0 <- West (feet)' East (feet) -> 3200 2800 2400 2000 1600 1200 800 400 0 400 800 1200 1800 2000 2400 2800 5200 12000, I I I I I / I I I / 6400 r~ 680,~(~/6800 700~)/i 7000 \ \ \, \. / 4400 ~ 4600 . / ,. / .,, / / / / . /' ,. / ,,, / / 4800 5200 5600 4800 ~ 5000 t~ ,. 5200 \ ~ 5.00 6oool 6 oo ; ~ ~ 6200 ~.,/ ~ ~6400 ~ .' . ~ 6600 a 6800 ~ 7000 i i i. i i i , i , , , i i , , , , i i , i i i , 1.. i i i i i ·i 3200 280q 2400 2000 1600 1200 800 400 0 400 800 1200 1600 2000 <- West (feet) ·East (feet) -> 6OO0 6400 6800 7200 7600 8000 0 C ,.~- 8400 ~, ...+. 8800 ~ I V 9200 960O 2400' 2800 3200 RECE. IVE.D 10000 , 10~00 I0800 1200 11600 12000 DEC 19 2000. Alaska Oil & Gas Cons, Commissior "Anchorage Phillips Alaska, Inc.. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 December 18, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-NQ1 (& CD1-NQ1 PH) Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD1 drilling pad. The intended spud date for this well is January 8, 2000. It is intended that Doyon Rig 19 be used to drill the well. The CD1-NQ1 PH will be drilled through to' the base of the Alpine Sand at an inclination of approximately 47.52°. This will allow evaluation of the Alpine &' Nanuq reservoir intervals. It will then be plugged back and sidetracked to enable a horizontal penetration of the. Nanuq reservoir. After setting 7" intermediate casing, the horizontal section will be drilled and the well completed with a slotted'liner. At the end of the work program, the well will be shut-in awaiting the completion of well work that will allow the well to be put. on test production. Please find attached the information required by 20 ACC 25.005 (a) and (c) for Your review. Pertinent information attached to this application' includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed pilot hole schematic. 6. Proposed completion .diagram. 7. Pressure information as.'required by 20 ACC 25.035 (d)(2). 8. CD1-NQ1 Pilot Hole Cementing Requirements. 9. Directional drilling / collision avoidance information as required by 20 ACC 25,050 (b), InformatiOn pertinent to this application that is presently on.file at th'e AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay' out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling'system. If you have any questions or require further information, please contact Scott Reynolds at 265-6255 or Chip Alvord at 265-6120. Scott D. Reynolds Drilling Engineer Attachments CC: CD1-NQ1 Well File / Sharon AIIsup Drake Chip Alvord Eric Reinbold Gracie Stefanescu Lanston Chin ATO 1530 ATO 868 ATO 856 Anadarko - Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com Date: To: Alaska State Dept of Revenue 3001 Porcupine Street Anchorage, AK Re: Filing fee for Permit to Drill Well #._ _~J- ~/C~ ~. $:L00.00 check attached. (check # 10~ ) Sharon AIIsup-Drake Engineering Aide CATO-1530) Wells/Drilling Phillips Alaska 700 G Street Anchorage, AK 9950~ RECEIVED ., DEC 7 9 2000 ' Alaska Oil & Gas Cons. Conlmission Anchorage American Express' Cash Advance Draft ' 106 .'. :.'~ '~ . ~1' . '.'. :. '..... :..'. .... ".,~ '.:._......' ..... ......' ...... ..... ..... ..... .... .'Z~' ~...'..' "... '.....~...~. "oLL^"s .:" : ".'....'. ': .'i...~'.,_~ ~ ~:' ~..: :.: ~..~..../':.: .., ..'.. '.....;...::. :......?...:.....:....'::.....: ....,.......... · . .. ~D..'FOR AMOUNT...OYER::$!I000.". '! :'..'"..' ":' ., ..' · :,,.,,.~: ..~~k.~.~ :j,.~,~ ~ t>~ ~' .' .','..'~_~ ..~.~ ::S~.~'r~. ~:~ ~:'a',~.'~':~"" '.~" ~ ." PERIOD'"ENDiNGu.,~'~'' I'~' '-:1' L. ',~"l'..'/'~" :-,~; . .'..' .': '.":L" ' '" ~;',~.'. ~:~.:~:'~Z~/'.~. ~:" ' · ":'..' 'i':":",..:' .'::':.'...'."' ':'..:"'."..'..'~..~".~::.':'"~:..~. '~'..'..:...'.'....:' ~..:'"'. . ~f.~~,. '. ~:'..'.'....i.. ~.: ..,,. ..... .'i,m,,.:., ..'.' ". .... ...'. .",.',"..,'. :.,'.....'. .... .' '.,... ' ,:,..:.! :..,.' · ,.", '.".'.., .', '... "i.".,~ .... ."":'""...'.' ' ,'"' '"?,;'.' '.'"'.. ' ..... .'". :-: .... ~d" ' · .......,..,..:l,O,.i?..I..O0't..O,O.~..'.:~,5........,,O.....ii..? 5EIO0"~i'"' :.'""' ',.:'" '"' '. '" ' ". "' / .,. :.,, .:................ .... ..'""' ....... u...' "'.. .:'""?"'"'~.. ' '":' .'" "~"'"..:.'........'"'." ..' .. :.:' '.... '.. ,;',~:"G 'O.".'&06 ' .'. ..... ". ... ",..'" '.' ' '?'.....i"'....." Text for inclusion in permit approval cover letter: In accordance with 20 AAC 25.005 (f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (CD 1-NQ 1 PH) and APl number (50-103-203 $ 8-70) from records, data and logs acquired for well CD 1-NQ 1. WELL PERMIT CHECKLIST COMPANY /~'~..///~ WELL NAMEd/O/- ,4/'~) ! PROGRAM: exp dev ~ redrll se~ wellbore sag ann. disposal para req--~'~ FIELD & POOL ~ ~/~ INIT~' --C~SS'~ ~E~ ~/~ ' Pe~it ~e affached ................. ~ ...... ADMINIST~TION 2.1' Lease number appmp~ate~.~..~~~//~-~1 N 3. Unique well name and number~.~ ................ 4. Well lo.ted in a defined pool.~ ............. 5. Well Io~ted proper dis~nce Eom drilling unit bounda~ .... 6. Well lo,ted proper distan~ from other wells .......... 7. Sufficient a=eage available' in d~lling unit ............ N 8. If deviated, is wellborn plat included ............... ~N 9. Operator only affe~ed paw ................... 10. Operator has appropriate bond in for~ ............. 11. Pe~it ~n be issued without ~nsewation order ........ N ~PPE DATE 12. Pe~it ~n.be issued without administrative approval ...... N /~ ~/..~ 13. Can pe~it be approved before l~day wait ........... N ;NGINEERING 14. Condu~or string provided ................... ~N 15. su~a~ ~sing proteus all known USDWs ........... 16. C MT vol adequate to cimulate on ~ndu~or & su~ ~g ..... 17. CMT vol adequate to ti~in long string to sud ~g ........ Y CMT wi, =, k.own proau=iw ho =on, .......... 19. Casing designs adequate for C, T, B & permafrost ....... ~N ~ · ~ ' ' ' 20. Adequate tankage or resale pit ................. ~N . ~ ' ' ' 21. If a r~dHll, has a 1~03 ~r abandonment been approved... 22. Adequate wellbore separation proposed .............. 23. If dive~r required, does it meet regulations .......... ' ~N, · . 24. DHIling fluid program schematic & equip list adequate ..... ~N .... ~ .. ; . '. . 25. BOPEs, do they meet regulation '.... ~. ~ ........ (~N ' ' · IIAP~ DATE 26. BOPE press rating appropriate; test to ~5 psig. I1~ t/~ ' 27 Choke manifold ~mplies w/APl RP'-53 (May 84) ........ {~N .... . . ' II '- . 2s; wm o ur ithout op r=tio. ,hutdown ........... ' ' ' ' ~ ~ ~ 29. Is pmsen~ of H2S gas probable ................. '. ~. aa. ~ pm~ntsd on potsntial o~m~um ~on~, ~ ...... W~ ~~~~ '~~ ~ ~ ~ , II ' 32. seismic analysis of shallow gas zones .... . ......... . ,Ap[~ DATE 33. Seabed~ndition su~ey(ifoff-shore) ....... ~~,n--'l~'''~l ~~' /~, ~-~ ~. Conta~ name/phone for weekly progress repo,s ~ ~~ on~ y] . . . ' _ .' ~ . . . · . . ' . ~ ANNU~R DISPOSAl35. With proper cementing m~rds, this plan ; ' ' . . ' , " ' ." II ; ' . ' (A) will ~ntain waste in a suitable receiving zone; ...... . . . Y N . . ApPR 'DATE (B) will not ~ntaminate freshwater; or ~use drilling waste '... Y N to su~a~;' .. (C) will not impair mechanical integH~ of the well used for disposal; Y N (D) will not damage producing formation or impair mcove~ from a Y N pool; and (E) will not cimumvent 20 ~C 25.252 or 20 ~C 25.412. Y N .ENGINEERING: , UlCIAnnular 'COMMISSION: ' Comments/Instructions: c:Vnsoffice\wordian~iana~checklist (rev. 11101//00)