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205-041
Submit to: OOPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2050410 Type Inj N Tubing 2790 3050 3070 3070 Type Test P Packer TVD 6759 BBL Pump 3.8 IA 44 2100 2025 2000 Interval 4 Test psi 1690 BBL Return 1.8 OA 61 63 63 63 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2081930 Type Inj N Tubing 1443 1443 1442 1442 Type Test P Packer TVD 6307 BBL Pump 1.5 IA 1082 2190 2160 2150 Interval 4 Test psi 1577 BBL Return 1.5 OA 16 31 31 31 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Alpine / CRU / CD3 Pad Caudle 02/11/22 Notes:Bled IA back to 600 to establish a better DP. Final T/I/O = SI 2902/600/62 Notes: CD3-110 CD3-305 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h anic al Int egrit y Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2022-0211_MIT_CRU_CD3-pad _2wells 9 9 99 -%5 CD3-110 02/11/22 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,February 20,2018 TO: Jim Regg /27(/ SUBJECT: Mechanical Integrity Tests P.I.Supervisor ��� Q J CONOCOPHILLIPS ALASKA,INC. CD3-110 FROM: Lou Laubenstein COLVILLE RIV FIORD CD3-110 Petroleum Inspector Src: Inspector Reviewed By: P.I.5upry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3-110 API Well Number 50-103-20509-00-00 Inspector Name: Lou Laubenstein Permit Number: 205-041-0 Inspection Date: 2/10/2018 ✓ Insp Num: mitLOL180212123057 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Yp gr �� Well CD3-110 T e InJ' i G 'TVD 6759 Tubtn 3829 3832 3823 3826 - PTD 2050410 Type Test SPT Test psi 1690 - IA 700 2090 - 2010 • 1990 - j BBL Pumped: 2 - BBL Returned: 2 ' OA 120 122 122 - 122 - Interval 4YRTST _ P/F P ✓ 1 Notes: SCANNED . ti „, Tuesday,February 20,2018 Page 1 of 1 ij "It t t - - -- 333 West Sevcnih Fvenue (=nV'FRNOR. STAN PARK) 1 I Anchorage, Alaska 99501 3572 'Q�c.uulllldlA I�I ry 907 ')i U 'z'');) MJ Loveland S`ANNE�D WlA r, GQ1 Well Integrity Project ConocoPhillips Alaska, Inc. �©- ✓ 0 LI-/ P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-110 Sundry Number: 314-027 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Pi -cr)-/-1/— Cathy P. Foerster Chair DATED this 17�of January, 2014. Encl. STATE OF ALASKA I .i1.-14/ A ALASKA OIL AND GAS CONSERVATION COMMISb,...N APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1 i ) 71 1--, 1.Type of Request: Abandon yp q � Plug for Redrill � Perforate New Pool� Repair well � Change Ap(�rQvejd �;�..as. Suspend E Plug Perforations E Perforate r Pull Tubing r TimeExtension E Operational r Re-enter Susp. r Stimulate r Alter casing r Other:Conductor Extension r'. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Developmen r 205-041 3.Address: 6.API Number: Stratigraphi r Service F P.O. Box 100360,Anchorage,Alaska 99510 50-103-20509-00 • 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F CD3-110• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 0372105,0372104,0364471,0364470 Colville River Field/Fiord Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): ''Junk(measured): 17991 • 6881 • Casing Length Size MD ND Burst Collapse CONDUCTOR 84 16 118' 118' SURFACE 2642 9 5/8 2680' 2430' PRODUCTION 8923 7 8959' 6999' OPEN HOLE 9032 6.125 17991' 6881' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Open hole 8959-17991 ' Open hole 6999-6881 3.5 L-80 8032 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER PREMIER PACKER • MD=7973 TVD=6759 TRMZXX-53 SSSV • • MD+2185,ND 1994 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service F • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2014 Oil r Gas r WDSPL r Suspended I- 16.Verbal Approval: Date: WINJ r GINJ r WAG F • Abandoned f l Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Martin Walters Email: n1878ta7,cop.com Printed Name MJ Loveland T e: Well Integrity Project Signature . ---49/./ j - Phone:659-7043 Date 1/11/14 rrCommission Use Only Sundry Number:31 C,' _ail Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test E Location Clearance r Other: RBDM AY U 9 2014 Spacing Exception Required? Yes 0 No / Subsequent Form Required: /O O !1 APPROVED BY Approved by: P C MIS ONER TH COMMISSION Date: I -/ 7 '/`—/ cd appy"ca ' n is vale or . months from the Edatc f approval. / Form 10-403(Revised /2012) U IG n Pith11)S 11� Submit Form and Attachments in Duplicate V` C• 1 /1 G l/i /", .1. - ' ' may WNS CD3-110 '5-- oeABsw ConocoPhillips • e.Wenss Well Attributes Max Angle&MD TD i, Alaska.IncWellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Otto(ftKB) 501032050900 FIORD NECHELIK INJ 94.50 15,882.35 17,991.0 C�,",«,;1y,,,,ps Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date weoCongo-LOS-11o.520/20111058OAM SSSV:TRDP Last W0: 42.38 2/1/2006 Schematic-Actual Annotation Depth(1KB) End Date Annotation - Last Mod...End Date Last Tag: Rev Reason:UPDATE OPEN HOLE TOP DEPTH Imosbor 5/20/2011 Casing Strings - Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd HANGER,31 ! CONDUCTOR 16 15.062 34.0 118.0 118.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.921 37.9 2,680.1 2,430.3 36.00 J-55 BTC Casing Description String 0... String ID...Top(15(B) Set Depth(f...Set Depth(TVD)...String Wt...String...Shing Top Thrd PRODUCTION 7 6.151 35.4 8,958.8 6,999.8 26.00 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd OPEN HOLE 6 1/8 8,958.8 17,991.0 6,881.4 I Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING 4.5"x3.5" 3 1/2 2.992 31.2 8,032.4 6,786.5 9.30 L-80 EUEMOD Completion Details Top Depth 9 P (11KB) Top Incl Noml). Top(ftKB) OM) (°) Rem Description Comment �ID(in) 31.2 31.2 0.00 HANGER FMC TUBING HANGER 4.500 116.1 116.1 0.10 X0 4.5x3.5 CROSSOVER 4.5 x 3.5 3.500 2,185.8 1,994.8 32.19 SAFETY VLV CAMCO 3.5"TRMAXX-53 SSSV 2.812 I 7,972.8 6,758.8 61.06 PACKER BAKER PREMIER PACKER 2.875 8,020.4 6,780.8 62.57 NIPPLE 3.5"HES'XII NIPPLE w/2.75"NO GO 2.750 8,031,9 6,786.3 62.93 WLEG WIRELINE ENTRY GUIDE. 3.000 CONDUCTOR,_„ Notes:General&Safety 34-178 End Date Annotation 10/20/2006 NOTE:PRE-PRODUCED,THEN CONVERTED TO INJECTOR I SAFETY VLV, O C. 2,183 I SURFACE,_ i 38-2,080 GAS LIFT,_ 7,885 i ii PACKER.7.973- NIPPLE,8,020 - - / WLEG,8,032 ---- -- -1 1, Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run II I Stn Top(ftKB) (ftKB) (°) Make Model (in) Sery Type Type lie) (psi) Run Date Com... 1 7,884.6 6,712.6 58.25 CAMCO KBMG 1 GAS LIFT DMY 'BK 0.000 0.0 10/20/2006 PRODUCTION, 358,959 OPEN HOLE. 8,959-17,991 TO,17,991 ConocoPhillips Alaska r . . . P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 A O - C January 10, 2014 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 • Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well CD3-110, PTD 205-041 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, MJ Lo land ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska,Inc. Alpine Well CD3-110 (PTD 205-041) SUNDRY NOTICE 10-403 APPROVAL REQUEST January 10, 2014 This application for Sundry approval for Alpine well CD3-110 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to SC. At some point during normal operations the conductor subsided about 13". With approval,the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor • • Nov C onocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 February 3, 2011 a,05--°4-1 c ,.9 3 -140 Commissioner Dan Seamount Alaska Oil & Gas Commission ---- si.- 0 ,�.,. 333 West 7 Avenue, Suite 100 D FEB 0 4 2011 . Anchorage, AK 99501 1::r *,,t,""4,, . au�S. .. WA Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped January 31, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, 4‘.....,... , 77 / 7 MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Alpine Field Date 213/2011 CD3 Pad Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal CD3 -106 50103206110000 1 2100010 i 16" I NA 16" NA 7.65 1/31/2011 CD3 -110 50103205090000 2050410 4" NA 6" NA 2.13 1/31/2011 c > CD3 -112 50103205270000 2060320 3" NA 16" NA 2.73 1/31/2011 CD3 -114 50103205440000 2070330 5" NA 14" NA 2.55 1/31/2011 CD3 -121 50103206150000 2100220 32" NA 32" NA 27.2 1/31/2011 CD3 -122 50103206090000 2091530' 74" NA _ 74" _ NA 32.2 1/31/2011 CD3 -124 50103206120000 2100080 17" NA 17" NA 5.1 1/31/2011 CD3 -301A 50103205430100 2060170 9" NA 15" NA 4.25 1/31/2011 CD3 -302A 50103205220100 2100350 5" NA _ 16" NA 3.83 1/31/2011 CD3 -304 50103205980000 2090280 18" NA 18" NA 5.9 1/31/2011 MEMORANDUM To: Jim Regg ~ i~ P.I. Supervisor ~ { ~~~~~~u FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, Apri128, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD3-110 COLVILLE RIV FIORD CD3-110 Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprv ~ Comm Well Name: COLVILLE RIV FIORD CD3-110 API Well Number: 50-103-20509-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100427183409 Permit Number: 205-041-0 Inspection Date: 4/25/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well cD3ii° Type Inj. ~' TVD ~~59 "` jA ~ 69s lsoo ' I7as 1740 P.T.D 2050410 TypeTest ~ SPT Test psi ~ lsoo pA slo s2o s2o s2o InterVal4YRTST P~I'` P ~ TUbing 2300 2300 2300 2300 _ Notes: Wednesday, April 28, 2010 Page 1 of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD /UNIT /PAD: Alpine /CRU /CD3 DATE: 04/25/10 OPERATOR REP: Colee /Phillips AES d 5 ~ ~r, AOGCC REP: Bob Noble ~ V _ Packer Depth Pretest Initial 15 Min. 30 Min. Well CD3-108 Type Inj. G TVD 6,695' Tubing 2,725 2,725 2,725 2,725 Interval 4 P.T.D. 2050330 Type test P Test psi 1,674 Casing 1,355 2,110 2,070 2,070 P/F P Notes: OA 515 525 525 525 Well CD3-110 T pe Inj. W TVD 6,759' Tubing 2,300 2,300 2,300 2,300 Interval 4 P.T.D. 2050410 Type test P Test psi 1,690' Casing 695 1,800 1,745 1,740 P/F P Notes: OA 510 520 520 520 Well CD3-305 Type Inj. G TVD 6,307' Tubing 2,500 2,500 2,500 2,500 Interval 4 P.T.D. 2081930 Type test P Test psi 1,577' Casing 570 1,900 1,870 1,860 P/F P Notes: OA 455 582 577 577 TYPEINJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differentiae Temperature Test ~~~/~ l° v'~(~~ INTERVAL Codes .,.I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, April 27, 2010 5:14 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Problem Well Supv; NSK Well Integrity Proj; ALP DS Lead and Simops Coord Subject: Alpine State Witnessed MITs Attachments: CRU CD3 Pad 04-25-10.x1s Attached for your records is the Alpine MIT form for tests witnessed by Bob Noble on 04-25-10. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 Regarding 4 year state witnesse~ITIA's on CD3 pad • ~~ ~e ~~- ~TD Zc~ ~ -~q ~ Regg, James B (DOA) g~ '' ~~ ~~ 3 ~' ~,,.,.~..~ ~~ 70.E _ a ~,3 ~~ From: Regg, James B (DOA) ~ ~~ ' o t~ Sent: Wednesday, June 10, 2009 12:51 PM 2~6 _ pt~: To: 'NSK Problem Well Supv' ~g -- v t 1 Cc: Fleckenstein, Robert J (DOA) ~ ~ _ ~~ 3 Subject: RE: Regarding 4 year state witnessed MITIA's on CD3 pad ~.- Your request to defer MITs at Colville River Unit CD3 pad until February 2010 is approved. The agreement to test in summer was driven by weather considerations and efficiency at CPAI's request. Testing the below listed wells in February 2010 will still accomplish the requirement to test at least every 4 years. We will make the necessary changes in our database to reflect a new due date of February 28. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 rnr. m~~yi..r',t~~'~ Ek`, u 2LIl, From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Tuesday, June 09, 2009 2:28 PM To: Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; ALP DS Lead and Simops Coord; Maunder, Thomas E (DOA) Subject: Regarding 4 year state witnessed MITIA's on CD3 pad Jim, By prior agreement with the Commission, Alpine CD3 pad is due for 4 year state witnessed MlTIA's in July of 2009. Due to the remote location of that pad, the only available way to perform the MIT's during July would be to use a small triplex pump. The small triplex pumps have a 3 bbl capacity of fluid on board. With 8 wells to test on that pad, that would require to refill the triplex tank several times during the testing, possibly extending the testing time from 1 day to 2 or even 3 days, pending diesel availability. ConocoPhillips requests the testing cycle of CD3 to be deferred until February of 2010 when the pad is accessible with a larger pump by ice road. In reviewing our records of test dates, CD3-108 (PTD 205-033) has the oldest test date of 09-29-06. The other wells have more recent tests than that date (see table below). All of the wells will still be in compliance in February. February would become the new test month for CD3 and 2010 would be the start of the 4 year cycle. -CD3-110 (PTD 205-041) last tested on 01/12/07 '- Ao~c~w'tne~ss ~~ I~~'"7 CD3-112 (PTD 206-032) last tested on 04/28/07 ~- ~~~- w~~h~5 ~-~~~J 7 CD3-114 (PTD 207-033) last tested on 04/02/08 ~ ~~ w~-+~ss G(Zf 2~ CD3-118 (PTD 208-025) last tested on 03/07/09 - A~x~-c'e w~~~~ 3i~(7.c7v9 CD3-302 (PTD 206-010) last tested on 07/19/07 _ c~_ w~~ ~~ ~~ ZEr/ t~l i~~ ~~ CD3-316A (PTD 208-011) last tested on 05/16/08 ~ ~6CC ~,+re~s 5~1~'Z;~DS CD3-305 (PTD 208-193) tentatively scheduled to have initial witnessed test on /13/09. Please let me know if you have any questions and if this is acceptable. Brent RogerslMartin Walters 6/10/2009 ~~-118 - 5p~ ~.~ci~~t Regarding 4 year state witnesse~V1ITIA's on CD3 pad • Page 2 of 2 r Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 6/ 10/2009 • f CRU CD3-110 PTD 205-041 6/9/2009 TIO Pressures T11/0 Plot -CD3-110 2500 2000 a 1500 1000 500 0 L .....................t................................/...........~....1....................................................../...........1......... ................ ~...,r-`J.......... ~.............................~........................................................................... ~:' 01-Apr-09 01-May-09 Date 01-Jun-09 200 150 a E as 100 0 t v 50 0 ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri16, 2009 Mr. Tom Maunder "`~~~~~~~. ~~~ 'r- ~ ~~' Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~ _ a,~ APP ~~ 200 ~S~IaO? ~~~r ass - o ~-~~ ~ „~~-<<D ~_ Enclosed please fmd a spreadsheet with a list of wells from the Coville River Unit (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped Apri15~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Date 4/6/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al CD3-301 206-020 9" NA 9" NA 0.85 4/5/2009 CD3-302 206-010 5" NA 5" NA 0.43 4/5/2009 CD3-303 208-013 9" NA 9" NA 1.70 4/5/2009 CD3-305 208-193 8" NA 8" NA 0.85 4/5/2009 CD3-316A 208-011 26" NA 26" NA 8.93 4/5/2009 CD3-107 206-189 34" NA 34" NA 11.05 4/5/2009 CD3-108 205-033 10" NA 10" NA 1.26 4/5/2009 CD3-109 205-059 9" NA 9" NA 2.13 4/5/2009 CD3-110 205-041 4" NA 4" NA 0.43 4/5/2009 CD3-111 206-030 5" NA 5" NA 0.85 4/5/2009 CD3-112 206-032 3" NA 3" NA 0.43 4/5/2009 CD3-113 207-004 14" NA 14" NA 1.28 4/5/2009 CD3-114 207-033 5" NA 5" NA 0.85 4/5/2009 CD3-115 209-006 8" NA 8" NA 1.28 4/5/2009 CD3-117 209-026 6" NA 6" NA 0.43 4/5/2009 CD3-118 208-025 8" NA 8" NA 0.85 4/5/2009 1 t'~-~-- DATA SUBMITTAL COMPLIANCE REPORT 5/12/2008 Permit to Drill 2050410 WeII Name/No. COLVILLE RIV FIORD CD3-110 Operator CONOCOPHILLIPS ALASKA INC MD 17991 TVD 6881 Completion Date 2/1/2006 Completion Status WAGIN Current Status WAGIN REQUIRED INFORMATION API No. 50-103-20509-00-00 UIC Y Mud Log No DATA INFORMATI ON Types Electric or Other Logs Run: GR/RES, DENS/Neu Well Log Informat ion: Log/ Electr Data Digital Dataset Type ed/Frmt Number Name D Asc Q~o Directional Survey Cement E al ati n g v u o t~t~ D Lis 13881 Induction/Resistivity '~ 13881 LIS Verification R 15531 LIS Verification `-ED C Lis 15531 t~~ ~r.~,~,.w~~~ 'Q~~, ~~,~ Well Cores/Samples Information: Interval Name Start Stop ADDITIONAL INFORMATION Well Cored? Y~V Chips Received? ^r.: ".,:_. Analysis Y / Received? Comments: Samples No Directional Survey,(~r/_ (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 36 17991 Open 4/17/2006 5 Blu 1 6850 8250 Case Memory Cement Bond Log GR/CCL/TEMP/SCMT 19- Jan.-2006 0 0 Open 5/10/2006 GR EWR4 ABI CNP SLD ROP ACAL PWD Geopilot 0 0 Open 5/10/2006 2668 17940 Open 10/12/2007 LIS Veri, RPS, FET, GR, ~ NPHI, NCNT, RHOB, DRHO, FCNT, ROP 2668 17940 Open 10/12/2007 LIS Veri, RPS, FET, GR, NPHI, NCNT, RHOS, DRHO, FCNT, ROP w/PDF and TIF Graphics Sample Set Sent Received Number Comments Daily History Received? Formation Tops ~ N DATA SUBMITTAL COMPLIANCE REPORT 5/12/2008 Permit to Drill 2050410 Well Name/No. COLVILLE RIV FIORD CD3-110 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20509-00-00 MD 17991 ND 6881 Completion Date 2/1/2006 Completion Status WAGIN Current Status WAGIN UIC Y ___ Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To: State of Alaska October 4, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-110 REDO AK-MW-3649155 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20509-00 :~ ~ ~ ~~ ~' ~ `~il~ .~, ,~ Uzi ~oS=o`!l ~ ~ SS3 l • • Page 1 of 1 Maunder, Thomas E (DOA) From: Barreda, Brian B [Brian.B.Barreda@conocophillips.com] Sent: Thursday, July 26, 2007 3:46 PM To: Maunder, Thomas E (DOA) Subject: RE: CD3-110 Tom, that is correct we started injection 11107/06. Let me know if you need anything else. bb From: Maunder, Thomas E (DOA) [mailto:fiom.maunder@alaska.gov] Sent: Thursday, ]uly 26, 2007 3:01 PM To: Barreda, Brian B Subject: RE: CD3-110 Brian, Thanks Brian. When did injection first begin? Was the well inactive for a while similar to others? Thanks again, Tom Maunder, PE AOGCC From: Barreda, Brian B [mailto:Brian.B.Barreda@conocophillips.com] Sent: Thursday, ]uly 26, 2007 12:54 PM To: Maunder, Thomas E (DOA) Subject: CD3-110 Tom, the CD3-110 well was converted to a seawater injector 10/18/06 Brian Barreda ConocoPhillips Alaska Inc. Alpine Production Engineer ATO - 1738 Office: (907) 265 - 6036 Cell: (907) 830 - 0284 7/26/2007 ~Gln.~~ V Cl.~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JUL 1 3 7007 Alaska Ui1 & Gas ~rrnsw ~~tnmission ~i?Clii~C'"r~t%? 1. Operations Performed: Abandon ^ Repair Welt ^ Plug Perforations ^ Stimulate ^ Other ^/ After Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConOCOPhillips AI2Ska, InC. Development ^~ ~ Exploratory ^ 205-041 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20509-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 36.6' ~ CD3-110 r 8. Property Designation: 10. Field/Pool(s): ADL 372105, 372104, 364471, 364470 Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 17991' feet true vertical 6881' , feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 114' 16" 114' 114' SURFACE 2630' 9-5/8" 2680' 2430' PRODUCTION 8908' 7" 8958' 6999' OPEN HOLE 9033' 6-1/8" 17991' 8881' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8032' MD. Packers &SSSV (type & measured depth) Baker Premier Packer Packer- 7973' SSSV= Camco TRMAXX-5E SSSV= 2186' 12. Stimulation or cement squeeze summary: Intervals treated (measured) i?T"L JUL 3 0 ?DD9 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation Subsequent to operation 8088 1435 828 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations _ 16. Well Status after proposed work: Oil^ Gas^ WAGQ GINJ^ WINJ ^ WDSPL^ 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: 306-347 contact Brian Barreda Printed Name an Barr Title Production Engineer %'~%.x/0 Signature Phone 7 263-6036 Date Pre ared b Jeanne Haas 263-4470 Form 10-404 Revis 04/2004 Q ~ 1 ~ ~ ~ A ~ /~~~~~~j,~~mit Original Only MEMORANDUM /~ TO: Jim Re;g r-~ ~~~ r ~`~~~ ~ P.I. Supervisor ~~~ FRO;[: Job Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 17, 2007 StiBJECT: Mechanical Inte;rity Tests CONOCOPHII.LIPS ALASKA I1JC CDC-110 COLVILLE RIV FIORD CD3-I 10 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: COLVILLE RIV FIORD CD3-110 API Well Number ~0-103-3009-00-00 Inspector Name: John Crisp Insp Num: mit1Cr070 1 1 7053 634 permit Number: 205-041-0 Inspection Date: 1~LI/2007 Rel Insp Num Packer Depth Pretest Initial IS Min. 30 Min. 45 Min. 60 Min. -- - Well cis-i 10 'T a In'. w ~ TVD 6~ss I IA ', goo 2s3o '~ zaas zoos YP J P.T. ~, zosoalo 'TYPeTest sPT'~ Test psi ' I6a9 r OA rb ss~ sss ~~ ss~ '. Interval ~`'IT~- P/F P ~ Tubing, 19aa ~ ~9aa 19aa t9aa- - NOtes 2 bbl's pumped for test No problems. Wednesday, January t?, 2007 Paoe 1 of i LL110.11 Ut.".,. i~,ll 1 LL~V I~VJ V L' iL'V / .AIJ, IVII L \-L\V VL`t V 1-1G-V /..l lJ J Subject: Emaiiing: iVIIT CRU CD3 01-12-07.x1s, MIT CRU CD4 01-12-07.x1s lirom: NSK Problem Well Supv ~n1617~ci~conocophillips.com> Date: Sun, 14 Jan 2007 10:30:08 -0900 To: bob_fleckenstein a~admin.state.ak.us, jim_regg@admin.state.ak.us, Thofnas E Maunder atom mat~nder~adinin.state.ak.us? MIT CRU CD3 01-12-07.x1s» Ge « MIT CRU CD4 01-12-07.x1s» ntlemen, Enclosed are the initial MITIA results for CD3-110, CD4-319, and CD4-321. '+7 ~oS-p ~ 1 Regarding the T X IA communication in CD4-321 PTD # 206-142, reported 12/23/06, the CMD was found to be in the open position. Slick Line closed the sleeve. After passing the witnessed initial MITIA I removed CD4-321 from the monthly failed MITIA report. Let me know if you have any questions. Sincerely, Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 Content-Description: MIT CRU CD3 O1-12-07.x1s MIT CRU CD3 01-12-07.x1s' Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT CRU CD4 01-12-07.x1s MIT CRU CD4 O1-12-07.x1s Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 1' 1612007 4:03 Pbt ~~ -0~-~ ~ r~C:LgNICAL INTEGRITY REPORT `. U D D '. _ _ : ~ c' ~ b~ PER ~ FIELD ~~ ~ ~. '' ~;~~ ~~C~ -. _ G c ._ ..:. ~ ~ ~ ~ ~~ ~ ~~ is ALL N ITMB E R ~~ ~ ' ~ ~ ~~~p~s~~ ~'1" cs~s°~~po~~~ H ~ LL DAT_ ~_ TD : ~~_i~. S°~TVD ; ?BTD : ?-ID TVD C a s i ^ g : `'1~`~ Shoe : _~~t-II) ~ofi4 ~TVD ; D V : ~ ~ ?~ T~`Di ..:,e.: 1J~ Shoe : '~ '?-`JD ; .CP : ?•~D ~';D o - e . 3~)~ a a c is e r ~ "~ ~ T VD ; Set e t ~6~ `~ 2, _o1e S_ce ~ ~~ end ~~ ; Perfs to t~ ~Ch~<~4 o~er~o\ ~ ~~~ -1'55 '~Cc=~?d_C~.T, TNTEGR?TY - P Q.RT # 1 Cor.~ents 1 S Cain ~ 0 min i '•C~'CH~NIC~..L INTEGRIT`~ - PA~'.T #2 y~hh~s r~ 0 r~~ L ~ l~cti-©~ Cement Bond Log (Yes or No) ~« In AOGCC File ~~S ~ ©r.~ ~ L ~5~ ~ 1©OC~' ~^ C3L Evaluation, gone e~ove perfs ~ ~ ' csS e+~<'+'~`~ bySvS ~s +~cc- ~or~~-`coc~~io~ ~~s5v~ ~o.SS S°~i~s.~s ~..csc-~t r~Gt t+~FQ~e~~ Pm-o~v~~®~. oE~-~ ~~s ,-~~~~~icct~~ ~~~ o~~~e.~,va.'~~~cv-~~.~u.`cco~'ror~. Production-Log: Type CONCLJS?OI1S ?art i1; ~nnuius Press Test: =P Cement Vol~nes : Amt. L iner ~v(~ Cs~ a3~$u DV ~~ Cmt -rol to cover oer~s _ ~ ~ ~~o~ ~\ ~~~s ~o Co~C.'C'- ~~ ~aC~~.'~'~~t ~ _ .~eoretical TCC C 30~o`~S `~~jL '1~~~ ?ar~ r2: Evaluation ~~~~~~~ ~~ ~ Y ~ ~ ~ ) CV ~ i 2 F ~ ~ ~ ~ ~ ~ ~ . - 11~T~~fft'I~A7CIIlZ~ C~ ;~5~'iIl~l`T Jack Walker Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 • }' 1 r` Re: Colville River Field, Fiord Oil Pool, CD3-110 Sundry Number: 306-347 Dear Mr. Walker: FRANK H. MURKOWSKl, GOVERNOR 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cv~ . /'~~ 2. r~ti. Cathy P. Foerster Commissioner DATED this day of October, 2006 Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Y _ / ~~ 4„,r~ V ~~ (ACT 1 9 1006 Alaska Gil «Gas Cans. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATInN FnR Sl1NI~RY APPRnVAI S 1(l-4(l3 (fir use w/NSK & A/ninal 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ LL A- ~IAatrT Change approved program Q Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number ~p• ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 205-041 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20509-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS ^ NO ^~ CD3-110 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 372105,372104, 364471, 364470 RKB 36.6' Fiord Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17991' 6881' Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' 114' SURFACE 2630° 9-5/8" 2680' 2430' PRODUCTION 8908' 7" 8958' 6999' OPEN HOLE 9033' 6-1/8" 17991' 6881' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3-1/2" L-80 8032' Packers and SSSV Type: Packers and SSSV MD (ft) Baker Premier Packer Packer= 7973' SSSV= Camco TRMAXX-5E SSSV= 2186' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: August 1, 2006 Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Walker @ 265-6268 Printed Name Jack Walker - Title: Production Engineer G%'~ ~0 ' Cr Signature Phone 265-6268 Date ~ ~ U(o Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: ~ ~~>~~~~ ,~~ ~_ e~,~~ G ~~,~ ~Q , Subsequent Form Required: 1 ~1<'1L` `-~`J "1` APPROVED BY ~ (} Approved by: COMMISSIONER THE COMMISSION Date: ~ ~ f ~~: Form_10-403 Revised 06/2006 ~~ S ~F~ oc~ 2 ~ 2a0s :pL ~D •~~•nb ~~~~~ Submit in Duplicate ConocoPhillips October 19, 2006 Jack Walker Staff Production Engineer ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Phone: 907.276.1215 ~~~~~~ flCT Y 9 2006 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Re: Report of Sundry Well Operations for Sundry No. 306-248 And Request for Sundry Approvals Colville River Field, Fiord Oil Pool, Well CD3-110 Dear Chairman Norman: Alaska Di! ~ Gas Cons. Commission Anchorage ConocoPhillips Alaska, Inc. (CPAI) as operator of the Colville River Unit requested and received approval to temporarily produce the well CD3-110 originally permitted as a service well intended for WAG injector in the Fiord Oil Pool. The production period has been concluded for CD3-110. Enclosed is a 10-404 report for the CD3-110 pre-production. Approximately 254,000 STBO were produced from CD3-110 from August 9, through October 16, 2006. Also enclosed is a 10-403 form for conversion of CD3-110 from production back to its originally permitted service as a WAG injector. A cement quality log run in CD3-110 on January 19, 2006 indicated injection fluids will be isolated in the approved injection interval, and CD3-110 passed a preliminary mechanical integrity test. - Please call me at 265-6268 if you have questions. Very truly yours, ack Walker Staff Production Engineer ConocoPhillips Alaska, Inc. C, Attachment .~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~~EIV~p ~ ~ T 1 9 2006 :Alaska Oil ~ Gay Cons. C~mmissioi ~r~cMora~e 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^~ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 205-041 / 3. Address: Strati ra hic g p ^ Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20509-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 36.6' CD3-110 8. Property Designation: 10. Field/Pool(s): ADL 372105, 372104, 364471, 364470 Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 17991' feet true vertical 6881' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 114' 16" 114' 114' SURFACE 2630' 9-5/8" 2680' 2430' PRODUCTION 8908' 7" 8958' 6999' OPEN HOLE 9033' 6-1/8" 17991' 6881' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8032' MD. Packers &SSSV (type & measured depth) Baker Premier Packer Packer= 7973' SSSV= Camco TRMAXX-5E SSSV= 2186' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation NIA N/A N!A N/A N/A Subsequent to operation 3730 ~ 2214 - 10 1513 275 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _ 16. Well Status after proposed work: Pressure survey to be sent with annual report Oil Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 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: 306-248 contact Jack Walker @ 265-6268 Printed Name Jack Walker Title Production Engineer Signature ~+~ I p ~ v Phone 2/~ C -,~ 2 ~o r~ Date iU/ ~9~~So ( (/ Pre ared b Jean a Haas 263-4470 Form 10-404 Revised 04/2004 ~~T a~ Submi iginal nl lttt G~j ~ ~~~ ~ _ '~ ~` ~~ ~ ~ RANK H. MURKOWSKI, GOVERNOR ~S~ 0~ ~ ~S COI~TSF'.R,P2l,I`IOI~T CUMriIISSi®1~T j_/ 333 W. 7T" AVENUE, SUITE 100 1~-7 1~. 1` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jack Walker Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 ~~A~1~~~ .)UN ~ 4 20Q~ Anchorage, AK 95510-0360 Re: Colville River Field, Fiord Oil Pool, CD3-110 Sundry Number: 306-248 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 been requested. DATED this day of July, 2006 Encl. ~~~~ ~~l STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ~~'~ ~ ~ ~~~a 20 AAC 25.280 $~~ i >; . ~~ (,~ .~~~~ Gt1l~rnis~~An ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 10-403 (for use w/ NSK & Alpine) 1. Type of Request: Abandon ^ Siispend ^ Operafional Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended V~~ell ^ 2. Operator Name: 4. Current Well Class 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. oevelopment ^ Exploratory ^ 205-041 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20509-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership chang es: __. __ Spacing Exception Requires? Y85 ^ NO 0 CD3-110 9. Property Designation: 10. KB Elevation (ft): 11. FieldlPool(s): " ADL 372105, 372104, 364471, 364470 RKB 36.6' Fiord Proposed 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17991' 6881' Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' 114' - SURFACE 2630' 9-5/8" 2680'' 2430' PRODUCTION 8908' 7" 8958' 6999' OPEN HOLE 9033' ~.~ 5~4fz'-~ 17991' 6881' t Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3-1/2" L-80 8032' Packers and SSSV Type: Packers and SSSV MD (ft) Baker Premier Packer Packer= 7973' SSSV= Camco TRMAXX-5E SSSV= 2186' 13. Attachments Description Summary of Proposal ~ 14. Well Class after propos ed work ~y ,'.,~ - 1 Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ /~ ' 7 /Cl~ Sernce 15. Estimated Date for. 16 Well Stat after proposed work. Commencing Operations. August 1, 2006 Oil ~ Gas ^ Plugged ^ Abandoned 17. VerbaLApproval Date' WAG GINJ ^ WINJ ^ WDSPL ^ ' ~ Commission Representative ~ ~l 18; I hereby certify that the foregoing is true and correct to fhe best of my knowledge. Contact: Jack Walker @ 265-6268 Printed Name .lack Walker Title Production Engineer Signature ~ -Phone 265-6268 Date' ~y/p(~;~ Commission Use Only ~ Sundry Number, L Conditions of approval: Notify Commission so that a representative may witness V Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ `^\ Other: ~ I Subsequent Form Required: y~t-- ''t1 ~ C~~\ ~% '1 d\~~C-~ C` V \ C,.~ ~~ ~ APPROVED BY /1~ Approved by: COM ONER THE COMMISSION Date: ~V Form 10-403 Revised 06/2006 v 9UP~~CATE ®INS AFL JUL ~ 7 2006 / / Submit in Duplicate ~= ~,, Supplemental Information for 10-403 Application for Sundry Approval for CD3-110 API 50-103-20509-00 Permit to Drill No. 205-041 July 17, 2006 CD3-110 was permitted as a service well because its ultimate service will be injection of water alternating with enriched gas. It was drilled and completed as planned with a surface-controlled subsurface safety valve. Avery short flowback was completed after drilling and completion earlier this year. This sundry application seeks approval to temporarily produce CD3-110 to provide additional clean up before injection and to provide additional early production to stakeholders. Injection into CD3-110 is planned after 45 days to 6 months of production, and after issuance of an area injection order covering the CD3-110 well. Static pressure measurements are planned before starting production and before starting injection. Reservoir simulation shows no effect on ultimate recovery by producing CD3-110 before injection. The future CD3-110 injection profile maybe improved due to increased mud cake clean up from the formation face. ,~, Review of Sundry Applications 306-244 and 306-248 ConocoPhillips Alaska, Inc. Wells CD3-112 and CD3-110 AOGCC Permits 206-032 and 205-041 Requested Action: ConocoPhillips Alaska, Inc. (CPAI) proposes to pre-produce these MWAG injection wells in the Fiord Oil Pool. Production would be for between 45 days and six months pre CPAI's request. Recommendation: I recommend approval of these Sundry Applications to allow CPAI to pre-produce the wells for up to 6 months. Discussion: CPAI proposes to pre-produce the subject wells prior to conversion to MWAG injection wells in order to provide additional well cleanup prior to injection and to "provide additional early production to stakeholders." While providing additional benefits to the stakeholders is not a compelling reason to allow this activity there is some merit in providing an additional opportunity for well cleanup, which should improve future injectability in these wells. CPAI states that reservoir simulation shows that the proposed activity will not harm ultimate recovery. I talked with Mr. Jack Walker on July 21st and 25th, 2006, to discuss the proposed operations. Mr. Walker stated that their reservoir simulation model indicates a total volume, from all producing wells in the pool not just the two subject wells, of approximately 4 mmbo will be produced. There will be water and gas injection occurring in the pool during the pre-production period in well CD3-108, and the wo subject wells will also be converted to injection during this period. The injection totals are estimated at 1.6 bcfg and 1.7 mmbw during this six-month period. The original oil in place for the pool is estimated to be between 80 and 190 mmstb. The amount of oil produced during the pre-production period will therefore represent about 2 to 5 percent of the oil in place. Taking into account the total injection volumes also net voidage is reduced to 1 to 2 percent of the original oil in place. Maintaining the reservoir pressure above the minimum miscibility pressure is vital to ensure that the miscible injectant will provide the anticipated benefits. The initial reservoir pressure for the pool is approximately 3,200 psi and the minimum miscibility pressure (MMP) is estimated to be 2,935 psi. Based on the worst-case estimate of a 5 percent voidage the estimated pressure drop would be approximately 150 to 200 psi. The resulting average reservoir pressure would be in the range of 3,000 to 3,050 psi, which is t~ above the MMP. This is the worst-case estimate and does not account for the voidage replacement that will also be occurring. The reservoir pressure in the areas immediately adjacent to the pre-produced injection wells will be drawn below the MMP. However, this will represent a small area of the pool and Mr. Walker indicated that the reservoir pressure in this area would be increased to above the MMP through water injection prior to the commencement of the MI injection. Conclusion: CPAI's proposed activities will cause a localized reduction in reservoir pressure to below the MMP, but I believe that average reservoir pressure will remain above MMP and that CPAI is proposing the proper actions to avoid possible harm to the ultimate recovery. Therefore, I recommend approving their request. D.S. Rob ~=®" ~. Reservoir Engineer July 25, 2006 ConocoPhillips May 30, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD3-110 (APD 205-041) Dear Commissioner: ~;, .:,m. , .5. , ~;~' ,.~-~, ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD3-110. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ,~ `' ~ ~~'~ G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 GCA/skad ay~~ sn ?l STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT a;,- ~;, i. L~~iJ AND LOC ~,~. 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other 1b. Well Class: Development ^ Exploratory ^ Service ~ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., oraband.: February 1, 2006 ~ 12. Permit to Drill Number: 205-041 / • 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: April 12, 2005 13. API Number: 50-103-20509-00 . 4a. Location of Well (Governmental Section): Surface: 1339' FSL, 855' FEL, Sec. 5, T12N, R5E, UM 7. Date TD Reached: January 30, 2006 14. Well Name and Number: CD3-110 At Top Productive Horizon: 496' FSL, 2244' FWL, Sec. 32, T13N, R5E, UM 8. KB Elevation (ft): 36.6' RKB 15. Field/Pool(s): Colville River Field Total Depth: a 8PL '~~~~,~ 2575' F L, 3015' FEL, Sec. 30, T13N, R5E, UM 9. Plug Back Depth (MD + TVD): 17991' MD / 6881' TVD Fiord Oil Pool 4b. Location of Well (State ase Plane Coordinates): Surface: x- 388188 + y- 6003833 ~ Zone- 4 10. Total Depth (MD + TVD): .17991' MD / 6881' TVD 16. Property Designation: ADL 372105, 372104, 364471, 364470 TPI: x- 388703 y- 6008263 Zone- 4 Total Depth: x- 383533 • - 6015832 ' Zone- 4 11. Depth where SSSV set: 2186' 17. Land Use Permit: LAS21122 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1292' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE C AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RE ORD PULLED 16" 62.5# H-40 36.6' 118' 36.6' 118' 42" 1 o cu yds Portland Type III 9-5/8" 36# J-55 36.6' 2680' 36.6' 2439' 12.25" 458 sx AS Lite, 239 sx Class G 7" 26# L-80 36.6' 8959' 36.6' 6999' 8.5" 237 sx Class G 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" x 3.5" 116' / 8032' 7973' open hole completion ' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Injection flowback Method of Operation (Flowing, gas lift, etc.) pre-produced injector Date of Test Hours Tested Production for Test Period --> OIL-BBL 2558 GAS-MCF 737 WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. 669 psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Briet description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". NONE ~e~ ~F~. J~1N ~ ~ 2006 s ~_-/_:.~~; Form 10-407 Revised 12/2003 nK~iNAL CONTINUED ON REVERSE y~~ ~D C•Z•?oG ~`~`~~ ~~ ~ 6~>'~~' 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD3-110 Nechelik 8809' 6989' r N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Mechanical Integrity Test 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name C i ~ v rd Title: Alpine Area Drilling Team Leader Si nature ~~~ Phone ~ D t ~ C ~ ~' I ~ ~' g ~ ~ ~ ~ ~ ~ ~ a e 5- INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ConocoPhiilips,Ahska Operations Summary Report Legal Well Name: CD3-110 Common Well Name: CD3-110 Event Name: ROT -DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To 'Hours Code Sub Code 4/11/2005 14:00 - 15:30 ( 1.50 MOVE RURD 15:30 - 19:00 3.50 MOVE MOVE 19:00 - 20:00 ! 1.00 MOVE RURD 20:00 - 00:00 4.00 DRILL i RIRD 4/12/2005 00:00 - 01:30 I 1.501 WELCTL BOPE 01:30 - 03:00 1.50 RIGMNT RSRV 03:00 - 03:30 0.50 DRILL PULD 03:30 - 04:00 0.50 DRILL SFTY 04:00 - 05:00 1.00 , DRILL DRLG 05:00 - 08:00 3.00 ~ DRILL PULD 08:00 - 12:00 4.00 i DRILL DRLG 12:00 - 21:00 I 9.00 I DRILL I DRLG 21:00 - 22:00 I 1.00 RIGMNT RGRP 22:00 - 00:00. 2.00 DRILL DRLG 4/13/2005 100:00 - 10:45 I 10.75 I DRILL (DRLG Page 1 of 7 Spud Date: 4/12/2005 Start: 4/11/2005 End: 4/20/2005 Rig Release: 4/20/2005 Group: Rig Number: 19 Phase Description of Operations MOVE PJSM -Ready rig for move MOVE Move rig f/ CD3-108 to CD3-110 - (1/2 hrs. set diverter) MOVE RU service lines (elect, air,steam,& water) SURFAC Accepted rig @ 2000 hrs. -Nipple riser to Hydril -Take on spud mud - manually test knife valve RIGUP j RIH with 1 stand hwdp, tagged ice plug @ 45'. Perform Diverter and iAccumulatortests. stand back hwdp RIGUP j Slip and cut drilling line -service top drive. RIGUP i MU bit, motor and 1 stand hwdp. RIGUP j Held pre-Spud meeting with rig team and crew. RIGUP Clean out Conductor from 45' to 118' -blow down top drive -stand back hwdp SURFAC MU BHA #1 -motor @ 1.5 degrees -unload LWD -pulse test tools. SURFAC Spud well @ 0800 hrs -Drill from 118' to 422' MD 421.5' TVD ADT - 1.51 hrs. ART 0.8 AST 0.71 WOB 10/25 k RPM 80 GPM 450 @ 880 psi String wt. PU 95 SO 95 Rot 95 Torque on/off btm. - 4,500/4,000 ft. lbs. Took Gyro surveys @ 169', 258', 348' SURFAC Drilled from 422' to 1290' MD 1242' TVD ADT - 5.98 hrs. ART 0.15 AST 5.83 WOB 10/25 k RPM 60 GPM 450 @ 1160 psi String wt. PU 120 SO 115 Rot 120 Torque on/off btm. - 5,500/4,000 ft. lbs. SURFAC Set back one stand and changed out swivel packing. SURFAC Drilled from 1290' to 1449' MD 1259' TVD ADT - 1.37 hrs. ART 1.37 AST 0 WOB 10/25 k RPM 60 GPM 550 @ 1480 psi String wt. PU 125 SO 120 Rot 125 Torque on/off btm. - 7,000/4,000 ft. lbs. SURFAC Drill from 1449' to 2690' MD 2439' TVD ADT - 6.53 hrs. ART 4.84 AST 1.69 WOB 15/25 k RPM 60 GPM 650 @ 2230 psi ~ String wt. PU 150 SO 135 Rot 135 ;Torque on/off btm. - 8,000/5,000 ft. lbs. 10:45 - 11:30 0.751 DRILL I CIRC j SURFAC 11:30 - 13:15 j 1.751 DRILL WIPR j SURFAC 13:15 - 14:15 1.001 RIGMNT RGRP SURFAC 14:15 - 15:45 1.50 i DRILL WIPR SURFAC 15:45 - 17:30 I 1.751 DRILL I WIPR I SURFAC 17:30 - 19:00 1.501 DRILL CIRC SURFAC 19:00 - 19:15 0.25 ~ DRILL OBSV SURFAC 19:15 - 22:00 j 2.75 DRILL TRIP SURFAC 22:00 - 00:00 i 2.00 DRILL PULD SURFAC 4/14/2005 00:00 - 01:00 ~ 1.00 DRILL PULD SURFAC 01:00 - 02:30 1.50 CASE RURD SURFAC 02:30 - 02:45 0.25 CASE SFTY SURFAC 02:45 - 05:30 2.75 CASE , RUNC SURFAC Circ and cond mud 650 gpm / 2180 psi / 80 rpm Monitor well, static. Wipe hole from 2690' to 2019' - 605 gpm / 2060 psi / 80 rpm heavy cuttings load across shakers. Work on Top Drive grabber and IBOP. Continue to wipe hole from 2019' to 976' - 650 gpm ! 2000 psi / 80 rpm Reduced rate to 500 gpm / 1320 psi from 1353'. Flow check well, static. RIH from 976' to 2591' -flow check well, static. Precautionary wash and ream from 2591' to 2690'. CBU X 3 to clean hole for casing. Raised MW to 9.7 PPG. Monitored well, Blew down TD. POOH on TT. POOH and laid down BHA. Lay down motor -clear tools from floor -cleaned out drains from drip pans. Rig up to run 9 5/8" casing. Held safety and Opts meeting with crew. Run 9 5/8" casing: FS - 2 jts. 9 5/8" 36# J-55 BTC - FC -2 jts. 9 5/8" 36# J-55 BTC (BakerLoc first 4 connections -pump pipe volume to check Printed: 3/14/2006 4:07:08 PM Con©coPhillips Alaska Page 2 of 7 Opera#ions Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD3-110 CD3-110 Spud Date: 4/12/2005 ROT -DRILLING Start: 4/11/2005 End: 4/20/2005 doyon1@ppco.com Rig Release: 4/20/2005 Group: Doyon 19 Rig Number: 19 Date 'From - To Hours ' Code Code', Phase 4/14/2005 (02:45 - 05:30 ~ 2.75 CASE RUNC ~ SURFAC 05:30 - 06:00 I 0.50 CASE ~ CIRC (SURFAC 06:00 - 07:30. 1.50 I CASE I RUNC j SURFAC 07:30 - 08:00 ' 0.50 CEMENl? PULD SURFAC 08:00 - 10:00 2.00; CEMENT}CIRC SURFAC 10:00 - 12:15 I 2.251 CEMENT PUMP I SURFAC 12:15 - 13:00 ( 0.75 CASE ~ DEQT i SURFAC 13:00 - 14:00 I 1.00 CEMEN ( RURD ; SURFAC 14:00 - 17:00 i 3.00 WELCTL NUND SURFAC 17:00 - 19:30 1 2.50 WELCTL NUND SURFAC 19:30 - 00:00 ~ 4.50 WELCTL) ROPE SURFAC 4/15/2005 00:00 - 01:00 1.00 i RIGMNT RGRP SURFAC 01:00 - 05:00 4.00 WELCTL BOPE SURFAC 05:00 - 06:30 1.50 WELCTL BOPE SURFAC 06:30 - 07:00 0.50 WELCT NUND SURFAC 07:00 - 07:30 ~ 0.50 DRILL PULD SURFAC 07:30 - 09:30 j 2.00 DRILL PULD SURFAC 09:30 - 11:00 1.50 DRILL PULD ~ SURFAC 11:00 - 12:00 1.00 DRILL ~ PULD ~ SURFAC 12:00 - 12:30 0.50; DRILL ~ PULD SURFAC 12:30 - 14:30 ~ 2.00 DRILL TRIP SURFAC 14:30 - 15:15 I 0.75 DRILL REAM SURFAC 15:15 - 18:45 i 3.50 CEMEN~DSHO SURFAC 18:45 - 19:15 I 0.50 DRILL DRLG SURFAC 19:15 - 19:30 ~I 0.25 DRILL CIRC SURFAC Description of Operations floats) 32 jts. 9 5/8" 36# J-55 BTC -36 jts. total (1507') Washed down one joint from 963' to 1005' Circ one casing volume @ 4 bpm / 220 psi PUW 115K SOW 110K Run casing from 1507' to 2640' 27 jts. (63 jts. total) - PU hanger & landing jt. -Land casing on landing ring w/ FMC fluted mandrel hanger w/shoe @ 2680' FC @ 2592' Lay down fill up tool -Blow down Top Drive - MU cement head Stage pumps up to 7.0 bpm -circ and cond mud for cementing - Reciprocated pipe PUW 155K SOW 132K FCP @ 350 psi PJSM for cement job. Cement 9 5/8" casing as follows: Pumped 40 bbls. biozan water w/ nut plug - 6 bpm @ 200 psi w/ rig pump -Switch to Dowell -Pumped 5 bbls water -test cement lines to 2700 psi -Dropped btm plug -Mixed i;< pumped 50 bbls Mudpush XL spacer @ 10.5 ppg - 5.5 bpm @ 176 psi - Mixed & pumped lead slurry (ASL "G" w/ 30% D-53, 0.6% D046, 1.5% D079, 1.5% S001, 43.1 % D124, 9% BWOW D44, 0.5% D-65) @ 10.7 ppg - 7.5 bpm @ 175-330 psi -Observed nut plug marker @ shakers w! 343 bbls lead pumped -cut off lead & pump down surge can - 363 bbls total lead slurry pumped -switched to tail slurry ("G" w/ 0.2% D46, 0.3% D65, 2% S001) @ 15.8 ppg - 4.5 bpm @ 229-171 psi Dropped top plug & pumped 20 bbls water w/ Dowell -Switch to rig pumps - Displaced w/ 9.6 ppg mud @ 8 bpm 500 to 690 psi for first 171 bbls - slowed to 3.5 bpm @ 590 to 630 psi for last 10 bbls. -Bumped plug to 1000 psi - CIP @ 1205 hrs. Full returns during job wt 133 bbls cement retu~ne tib surface - recripcated pipe (mt~ last 100 t of d~placement Test casing to 2500 psi for 30 minutes -final pressure 2480 psi. Rigged down cement head and bales. Nippled down diverter. Dug gravel out of adapter to release. Nippled up wellhead and BOP. Set test plug RU and test BOP. Choke valves 10 & 13 Retested. Slow leak. Trouble shoot leak on BOP test to top pipe rams Test BOPE 250 / 5000 psi, Annular preventor 250 / 3500 psi. Change out top pipe rams from VBR to 4" pipe rams -test top pipe rams to 250/ 5000 psi. BOP tests witnessed by Lou Grimaldi (AOGCC) Pull test plug and install wear bushing -blow down lines Install drilling bails on top drive - pu 5" elevators MU BHA #2 -GeoPilot Rotary steerable assembly - RU GeoSpan skid Initialise MWD/LWD -PJSM Load source RIH w/flex collars and 1 stand hwdp to 286' -Shallow test tools -GeoPilot not communicating with DM. Pull up and sevice I-L-S Stab /flex pony DM connection -RIH to 286' - shallow test tools, ok. Pressure test GeoSpan skid to 3000 psi. RIH from 286' to 2468' -break circ -change elevators to 4". Wash down from 2468', clean out firm cement from 2680' to wiper plugs @ 2689'. Drilled out shoe track and cleaned out rathole to 2690'. Drilled from 2690' to 2710'.-ART .5 Hr. CBU. Printed: 3/14/2006 4:07:08 PM ConocoPhillips Alaska Operations Summary Report Page 3 of 7 Legal Well Name: CD3-110 Common Well Name: CD3-110 Spud Date: 4/12/2005 Event Name: ROT -DRILLING Start: 4/11/2005 End: 4/20/2005 Contractor Name: doyon1@ppco.com Rig Release: 4/20/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To Hours ' Code 'Sub '; Phase ! Description of Operations 4/15/2005 4/16/2005 19:30 - 20:15 20:15 - 22:15 22:15 - 00:00 00:00 - 01:00 01:00 - 02:00 02:00 - 03:30 03:30 - 12:00 12:00 - 00:00 4/17/2005 100:00 - 09:30 09:30 - 10:00 10:00 - 12:00 12:00 - 00:00 4/18/2005 00:00 - 02:00 02:00 - 02:30 02:30 - 09:00 09:00 - 10:15 10:15 - 14:30 14:30 - 16:30 Code 0.75 CEMENl ~ F1T SURFAC Rig up andperform FfT t0 16.4 Pt'G EMW. 2.00 DRILL ; TRIP INTRM1 ' POOH to change out LWD. Would not pulse. 1.75 DRILL PULD INTRM1 POOH BHA and trouble shoot LWD tools. 1.00 DRILL PULD INTRM1 Picked up LWD and uploaded. 1.00 DRILL DEOT INTRM1 RIH with BHA and tested LWD. 1.50 DRILL TRIP INTRMI RIH to 2656' and washed to 2710'. 8.50 DRILL DRLG INTRMI ; Drill from 2710' to 3797' MD 3414' TVD ~ ADT - 5.23 hrs. WOB 15/20 k RPM 150 GPM 650 @ 2180 psi String wt. PU 165 SO 125 Rot 145 Torque on/off btm. - 9,000/8,000 ft. lbs. Changed out mud to 9.8 PPG LSND while drilling. 12.00. DRILL DRLG INTRMI Drill from 3797' to 5228' MD 4611' TVD j ; ADT - 7.07 hrs. WOB 10/18 k RPM 160 GPM 650 @ 2820 psi ' String wt. PU 195 SO 137 Rot 160 Torque on/off btm. - 11,500/9,000 ft. lbs. 9.501 DRILL I DRLG I INTRM1 I Drill from 5228' to 6577 MD 5768' TVD ~ ~ Changed out valve 2.00 DRILL DRLG INTRM1 Drill from 6577' to 6850' MD 5988' TVD ADT - 7.42 hrs. since midnight WOB 10/20 k RPM 160 GPM 650 @ 3280 psi String wt. PU 220 SO 155 Rot 175 Torque on/off btm. - 12,000/11,000 ft. lbs. ~ ~ ECD 11.0 - 11.25 ppg 12.00 DRILL DRLG INTRM1 Drill from 6850' to 8134' MD 6830' TVD ADT - 7.55 hrs. WOB 12/26 k RPM 160 GPM 655 @ 3880 psi String wt. PU 210 SO 160 Rot 186 i Torque on/off btm. - 12,500/11,500 ft. lbs. j ~ ~ ECD 11.3 - 11.9 ppg 0.50' DRILL i OTHR ' INTRM1 j Needle valve on Geo Skid washed out. Bypass skid, circ and work pipe 2.00 DRILL ' DRLG INTRMI ~ 0.50 RIGMNT RGRP INTRMI 6.50 DRILL DRLG INTRM1 1.251 DRILL ICIRC IINTRM1 4.251 DRILL iWIPR iINTRM1 2.001 DRILL LCIRC I INTRM1 16:30 - 18:45 2.251 DRILL TRIP I INTRM1 Drill from 8134' to 8378'. Broke fitting on air line to Top Drive IBOP valve -repair same Drill from 8378' to 8969' MD 6999.7' TVD ADT - 5.66 hrs. since midnight WOB 12/22 k RPM 160 GPM 640 @ 3900 psi String wt. PU 215 SO 153 Rot 180 Torque on/off btm. - 14,500/12,000 ft. lbs. ECD 11.2 - 11.1 ppg Pumped 35 bbls high vis sweep -circ hole clean 640 gpm / 3890 psi / 160 rpm Flow check well static Wipe hole from 8969' to 7168' 550 gpm / 2940 psi / 130 rpm RIH to 8887', no problems Precautionary wash and ream from 8887' to 8969'. Pumped 35 bbls high vis sweep -circulate and condition mud 600 gpm / 3650 psi / 160 rpm Flow check well, static. Spot casing tube pill in drill pipe. Pump out from 8969' to 7232' spotting tube pill in hole. Printed: 3/14/2006 4:07:08 PM ConocoPt~illips Alaska Operations Summary Report Legal Well Name: CD3-110 Common Well Name: CD3-110 Event Name: ROT -DRILLING Contractor Name: doyon1@ppco.com Rig Name: Doyon 19 Date :From - To ', Hours Code '' Code Phase 4/18/2005 18:45 - 19:15 0.501 DRILL ~ TRIP INTRMI 19:15 - 19:30 0.25 ~ DRILL ~ CIRC INTRM1 i 19:30 - 00:00 4.50 DRILL !TRIP INTRM1 4/19/2005 ; 00:00 - 02:30 2.50 DRILL TRIP INTRM1 i 02:30 - 04:30 2.00 CASE RURD i INTRM1 04:30 - 06:00 1.50 CASE RURD INTRMI 06:00 - 17:15 11.25 CASE RUNC INTRM1 i 17:15- 17:45 i 0.501 CEMENl~RURD INTRM1 17:45 - 20:00 i 2.25 (CEMENTCtRC INTRMI 20:00 - 20:30 I 0.501 CEMENIi PUMP I INTRM1 20:30 - 21:45 1.25 CEMEN DISP INTRM1 21:45 - 22:30 0.75 ~ CASE ~ MIT ( INTRM1 22:30 - 23:30 1.00 CASE RURD ~ INTRM1 23:30 - 00:00 0.50 CASE RURD ~ INTRM1 4!20/2005 1 00:00 - 01:30 1.50 CASE RURD INTRMI 01:30 - 03:00 1.50 CASE RURD INTRM1 03:00 - 05:00 2.00 CASE RURD INTRM1 05:00 - 06:00 1.00 CASE MIT INTRMI 1 06:00 - 08:00 2.00 WELCT NUND SUSPEN 08:00 - 09:30 1.50' DRILL ' OTHR i SUSPEN 09:30 - 12:30 3.00 CMPLTN TRIP ~ SUSPEN 12:30 - 13:30 1.00 WELCT NUND SUSPEN 13:30 - 16:45 3.25 CMPLTN FRZP SUSPEN j 16:45 - 17:45 17:45 - 18:45 1/20/2006 00:00 - 12:00 ;12:00-00:00 1.00 j CMPLTN FRZP SUSPEN i 1.00 i CMPLTN NUND SUSPEN ~i 12.00 MOVE ~ MOVE ~ MOVE i 12.00 MOVE ~ MOVE ;MOVE Page 4 of 7 Spud Date: 4/12/2005 Start: 4/11/2005 End: 4/20/2005 Rig Release: 4/20/2005 Group: Rig Number: 19 Description of Operations Continue POOH on TT to 6755'. Pumped dry job and blew down top drive. POOH to 197' laid down Boast reamer and stood back HWDP. Finish POOH, PJSM Remove RA Sources, Down load & Lay down BHA. Change top pipe rams to 7", Test rams to 250/5000 psi, Set thin wall wear bush. PJSM, Rig to run 7" casing. Ran 7" 26# L-80 MBTC as follows: Float shoe (Ray Oil tool Silver bullet) 2 jts. -float collar( Weatherford) 2 jts.(first 4 connections made up w/ BakerLoc) filled pipe & checked floats, Ran total of 210 jts. Broke circ @ 2664', 5604', 7223', Make up FMC Hanger & land csg @ 8959'. Rig down Frank's fill up tool, Make up Dowell cement head. Circ & cond mud f/ cement, Stage rate up to 6 bpm @ 630 psi, UP 285K, DN 165K, Held PJSM for cmt job. Cement 7" casing as follows: Pumped 5 bbl CW-100 -Test lines to 3500 psi -pump 15 bbls CW-100 @ 4.2 BPM @ 400 psi -Drop btm plug -Mix & pump 30 bbls MudPush XL @ 12.5 ppg - 4.7 BPM @ 475 psi -Mix 8~ pump 49.1 bbl Lead slurry (Class G w! .2% D046, .3% D065, .07% 6155, .4% D167) @ 15.8 ppg - 4.5 BPM @ 275 psi Drop top plug -Pumped 20 bbls water w/ Dowell -Switch to rig pumps & displaced w/ 318.5 bbls 9.6 ppg brine @ 6.0 BPM @ 340 to 1050 psi - slowed rate to 3.0 BPM for last 10.0 bbls - 790 psi -bumped plug w/ 1400 psi -check floats - OK - CIP @ 21:45 hrs. F~1-etlKrts throughout job, Workdd ding 12' ua~1-19.7 P t~rrtit stove -then pipe became tight. Rig & test 7" casing to 3500 psi for 30 min. Cement head & Rig down csg. equip. Attempt to lay down 7" landing jt., Trouble backing out same. Attempt to back out 7" landing joint. Open BOP lower ram door to trouble shoot landing joint, Nipple down BOP from DSA. Raise BOP, Remove centralizer blade from landing joint, Back out and lay down landing joint. Pull thin wall wear bushing, Set 7" pack off & test same to 5000 psi, Rig down casing equip. Change upper pipe rams to 3-1 /2" X 6", Nipple down & remove BOPE. Note Operational decision to move to CD3-109 to drill surface and intermediate hole,~rior to end of ice road season. Change saver sub & grabbers on top drive. _~ Rig & run 40 joints 4-1/2" Kill string & land @ 1695', Set & test hanger to 5000 psi. Install & test FMC Tree to 5000 psi, Pull 2 way check. Rig Dowell lines to 7" x 9-5/8" annulus, Perform infectivity to 15.6 ppg, Flush annulus w/ 300 bbls fresh water, Freeze protect annulus w/ 50 bbls diesel, Rig down lines. Rig 8~ displace well over to diesel down 4-1/2" X 7" annulus and up 4-1/2" tubing @ 1695', Rig down lines. Install BPV, Remove outside annulus valve, Install blank Hang, Secure well, Release rig @ 18:45 hrs 4/20/05. Rigged down and pulled rig off well. Moving pits and motors to CD3-110. Moving pits and motors to CD3-110. Moving Sub to CD-3. Printed: 3/14/2006 4:07:08 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: CD3-110 Common Well Name: CD3-110 Event Name: ROT -DRILLING Contractor Name: doyon1@ppco.com Rig Name: Doyon 19 Date 1/21!2006 1 /22/2006 1 /23/2006 1 /24/2006 From - To ' Hours '! Code Sub Code 00:00 - 12:00 12.00 MOVE MOVE 12:00 - 00:00 ~ 12.00 MOVE RURD 00:00 - 03:001 3.00 MOVE MOVE 03:00 - 08:30 ' 5.50 08:30 - 09:00 0.50 09:00 - 10:15 1.25 10:15 - 14:30 ~ 4.25 14:30 - 16:15 ': 1.75 16:15 - 19:30 I 3.25 19:30 - 00:00 ~'~, 4.50 00:00 - 01:15 01:15 - 01:45 01:45 - 04:30 04:30 - 06:15 Phase MOVE MOVE MOVE MOVE RURD MOVE DRILL j SFTY DECOMP DRILL ; OTHR DECOMP WELCTL NUND j DECOMP DRILL ~ OTHR i DECOMP DRILL ~ OTHR DECOMP WELCT BOPE INTRM1 1.251 WELCTLI BOPE I INTRM1 0.50 2.75 DRILL OTHR INTRM1 DRILL OTHR INTRM1 1.75; DRILL (PULD IINTRM1 06:15 - 14:30 14:30 - 16:00 16:00 - 18:00 18:00 - 18:30 18:30 - 21:00 21:00 - 21:45 21:45 - 22:30 22:30 - 00:00 00:00 - 06:45 06:45 - 07:00 07:00 - 11:15 111:15 - 18:30 18:30 - 23:30 23:30 - 00:00 ', 1/25/2006 00:00 - 01:15 j 01:15 - 03:00 103:00 - 12:00 8.25' DRILL .TRIP INTRM1 1.50 RIGMNT ~RSRV INTRM1 2.00 CEMENT DSHO INTRM1 0.50 DRILL DRLG i ~ INTRMI 2.50 DRILL CIRC INTRM1 0.75 CEMEN LOT (INTRMI 0.75 DRILL CIRC PROD 1.50 DRILL TRIP PROD 6.75 DRILL TRIP PROD 0.251 DRILL PULD PROD 4.251 DRILL PULD PROD 7.25 j DRILL PULD PROD 5.00 i RIGMNTi RGRP PROD 0.501 RIGMNT~ RSRV PROD 1.25 DRILL PULD PROD 1.75 1 DRILL i CIRC PROD 9.00 I DRILL I DRLH I PROD Page 5 of 7 Spud Date: 4/12/2005 Start: 4/11/2005 End: 4/20/2005 Rig Release: 4/20/2005 Group: Rig Number: 19 Description of Operations ~ Moved sub and Ball mill. Moved Pipe shed and Shop. Continue Rig move and Spot Sub over well. Jack rig into drill position on subbase -Spot up Pits and Motors complexes - RU service lines, electric, steam, water and air. Accepted rig @ 0300 hours. Pull BPV with FMC lubricator - tbg. & annulus pressure, zero. RU circulating lines for displacing freeze protection diesel from well. Load 140 bbls of 9.6 ppg brine in mud pits -Rig up. Held Prejob safety and Ots meeting with crew and support personell. PT lines to 1500 psi -Displace diesel from well into open top tank - pumped 85 bbls of 9.6 ppg brine @ 4 bpm - ICP=210 psi, FCP=320 psi. !Blow down and rig down lines. Install BPV - ND tree - NU BOP stack, riser and flow line RU to LD 4 1/2" kill string -Engage hanger with LJb -BOLDS -Pull tubing hanger to rig floor -pull BPV and lay down hanger POOH -lay down 40 joints of 4 1/2" tubing - RD running tools RU, set test plug & test BOPE to 250 psi low & 5000 psi high, Hydril to 250 psi low & 3500 psi high, Test waived by AOGCC by John Spaulding. Test BOPE: (BOP, lower pipe & blind rams 250!5000 psi Pull test plug and blow down lines Install wear busing - PU 4" elevators Measure 4" drill pipe -RIH picking up 48 jts of 4" drill pipe -POOH standing back drill pipe MU BHA #4 - PDC bit/ bs/ stab/ 3 flex collars/ xo/ 3 jts hwdp/jars/ 2 jts ~hwdp j RIH picking up 4" drill pipe to 8764' (267 jts) ;Slip and cut drilling line -adjust brakes on drawworks !Washed from 8800' to 8869' (14' high by strap.) Drilled out shoe track j to 8959' and cleaned out rathole to 8969'. Drilled 20' of new hole to 8989' ADT .5 Hrs. Circulated sweep around. POOH to shoe and rigged up to do FIT. Performed LOT to 12.4 PPG EMW. Circulated bottoms up. POOH SLM on trip tank. POH on trip tank from 8286' to 287'. Flow check well. Stand back HWP and jars. Std back 1 std flex collars. LD stab, bit sub and bit. MU BHA #5. Install pulser and upload MWD. Shallow test MWD at 374'. Down link Geospan and test lines to 3500 psi. PU and RIH w/ 4" DP from 374' to 7,874'. 1 Repaired broken chain in Drawworks. i Serviced rig. ~! PU and RIH w/ 4" DP from 7874' to 8957. !Break circ. Wash to 8989'. Displace out 9.6 ppg brine with 9.2 ppg 'flo-pro. Check flow. Had small flow out annulus. Start increase mud wt to 9.3 PP9~ '~ Drill 6 1 /8" horizontal hole f/ 8989' to 9548' MD 7016' TVD II ADT - 6.76 hrs. WOB 8/10k RPM 120 GPM 220 @ 1470 psi 'I String wt. PU 195 SO 155 Rot 178 ~, Torque on/off btm. - 10,500 / 8,500 ft. lbs. Printed: 3/14/2006 4:07:08 PM ConocoPhillips Alaska Page s of 7 Opera#ions Summary Report Legal Well Name: CD3-110 Common Well Name: CD3-110 Spud Date: 4/12/2005 Event Name: ROT -DRILLING Start: 4/11/2005 End: 4/20/2005 Contractor Name: doyon1@ppco.com Rig Release: 4/20/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date From - To ', Hours Code Code Phase '', Description of Operations - --- - 1/25/2006 03:00 - 12:00 I 9.00 ~ DRILL DRLH PROD ~ ECD 10.0 - 10.5 No flow on connections 12:00 - 00:00 12.00 DRILL DRLH PROD Drill 6 1/8" horizontal hole f/ 9548' to 10445' MD 6546' TVD ADT - 9.47 hrs. WOB 5/10k RPM 120 GPM 220 @ 1550 psi String wt. PU 196 SO 150 Rot 174 Torque on/off btm. - 10,500 / 9,000 ft. lbs.. ~ ECD 10.0-11.2 j j No flow on connections 1/26/2006 00:00- 12:00 12.00 DRILL I j j i i i 12:00 - 00:00 12.00 DRILL I 1/27/2006 , 00:00 - 12:00 12.00 DRILL DRLH ;PROD Drill 6 1/8" horizontal hole f/ 10,445' to 11,3105' MD 6976' TVD j ADT - 9.8 hrs. ! WOB 8/12k RPM 120 GPM 220 @ 1770 psi String wt. PU 197 SO 148 Rot 172 Torque on/off btm. - 11,500 / 10,500 ft. lbs. ECD 10.6 - 11.3 DRLH PROD Drill 6 1/8" horizontal hole f/ 11,305' to 12,350' MD 6951' TVD ADT - 8.87 hrs. WOB 6/12k RPM 140 GPM 220 @ 1800 psi String wt. PU 206 SO 140 Rot 170 ! Torque on/off btm. - 12,000 / 11,000 ft. lbs. ECD 10.8 - 11.3 i, DRLH ~ PROD ; Dril16 1 /8" horizontal hole f/ 12,350' to 13,440' MD 6964' TVD i ADT - 9.01 hrs. WOB 8/12k RPM 130 GPM 220 @ 2020 psi String wt. PU 205 SO 135 Rot 170 I Torque on/off btm. - 13,000 / 11,000 ft. lbs. ~ECD11.0-11.5 12:00 - 00:00 12.001 DRILL DRLH PROD Drill 6 1/8" horizontal hole f/ 13,440' to 14,490' MD 6929' TVD ADT - 9.1 hrs. WOB 9/12k RPM 130 GPM 220 @ 2170 psi String wt. PU 210 SO 125 Rot 170 Torque on/off btm. - 12,500 / 11,000 ft. lbs. ECD 11.0 - 11.4 1/28/2006 00:00 - 12:00 12.00 DRILL ! 12:00 - 00:00 '~, 12.00 DRILL j 1/29/2006 , 00:00 - 12:00 ~ 12.00 DRILL DRLH PROD Drill 6 1/8" horizontal hole f/ 14,490' to 15,445' MD 6918' TVD ( ADT - 8.52 hrs. WOB 9/12k RPM 130 GPM 220 @ 2240 psi j i String wt. PU 215 SO 117 Rot 168 j (Torque on/off btm. - 14,000 / 12,500 ft. lbs. ;ECD 11.1 - 11.6 DRLH PROD ;Drill 6 1/8" horizontal hole f/ 15,445' to 16,304' MD 6894' TVD I, ADT - 9.36 hrs. ! WOB 8/11 k RPM 130 GPM 200 @ 2140 psi String wt. PU 218 SO 112 Rot 168 Torque on/off btm. - 15,500 / 13,500 ft. lbs. ECD 11.1 - 11.5 Losing 60 to 28 BPH. 480 BtNs. Lost DRLH PROD Drill 6 1/8" horizontal hole f/ 16,304' to 17,115' MD 6906' TVD ADT - 9.48 hrs. WOB 8/11k RPM 130 GPM 200 @ 1960 psi String wt. PU 217 SO 120 Rot 170 Torque on/off btm. - 14,500 / 13,000 ft. lbs. ECD 10.9 - 11.3 Lasing 0 to 40 BPH. 254 E3blstost.S2 Hrs. 12:00 - 00:00 'i 12.00 ~ DRILL DRLH PROD ~ Dril16 178" horizontal hole f/ 17,115' to 17,960' MD 6885' TVD Printed: 3/14/2006 4:07:08 PM ConocaPhillips Alaska Page i of ~ Operations Summary Rep©rt Legal Well Name: CD3-110 Common Well Name: CD3-110 Spud Date: 4/12/2005 Event Name: ROT -DRILLING Start: 4/11/2005 End: 4/20/2005 Contractor Name: doyon1@ppco.com Rig Release: 4/20/2005 Group: Rig Name: Doyon 19 Rig Number: 19 Date 1 /29/2006 !From - To 'Hours Code Sub ', Phase Code ____ 12:00 - 00:00 ~ 12.00 ~ DRILL ~ DRLH ~ PROD 1 /30/2006 00:00 - 01:30 101:30 - 05:45 I 05:45 - 08:30 08:30 - 16:30 16:30 - 17:00 17:00 - 19:00 19:00 - 23:30 23:30 - 00:00 1131 /2006 00:00 - 02:15 02:15 - 02:45 02:45 - 03:15 03:15 - 03:30 03:30 - 09:30 09:30 - 10:15 10:15 - 14:30 14:30 - 15:30 15:30 - 16:30 16:30 - 21:00 21:00 - 00:00 2/1/2006 100:00 - 03:15 03:15 - 04:30 1.501 DRILL I DRLH I PROD 4.251 DRILL I CIRC I PROD 2.75 i DRILL I CIRC I PROD 8.00 DRILL TRIP PROD 0.50 WELCT OBSV PROD 2.00 DRILL TRIP PROD 4.50 DRILL (. PULD PROD 0.50 DRILL ~ TRIP PROD 2.25 DRILL i PULD PROD 0.50 DRILL OTHR PROD 0.50 CMPLTN RURD PROD 0.25 CMPLTN SFTY PROD 6.001 CMPLTN RUNT PROD 0.75 ~ CMPLTN PULD PROD 4.25 ~ CMPLTN RUNT PROD 1.001 CMPLTNI RUNT I PROD 1.00 I CMPLTNI RUNT I PROD 4.50 CMPLTN NUND (PROD 3.00 CMPLTN FRZP ,PROD 3.251 CMPLTNI DEQT I PROD 1.25 I CMPLTNI OTHR I PROD Description of Operations ADT - 8.83 hrs. WOB 8/13k RPM 120 GPM 200 @ 2310 psi String wt. PU 220 SO 110 Rot 167 Torque onloff btm. - 14,500 / 13,000 ft. lbs. ECD 10.9 - 11.3 Losing 0 to 40 BPH. 443 SbHs Last 12`hirs. [ltrilMd iota shad, no directional control. Drill 6 1/8" horizontal hole f/ 17,960' to 17,991' MD 6884' TVD ADT - 1.75 hrs. WOB 11/14k RPM 120 GPM 190 @ 2090 psi String wt. PU 225 SO 110 Rot 165 Torque on/off btm. - 14,500 / 13,000 ft. lbs. ECD 11.1 - 11.3 CBU at 190 gpm - 2100 psi - 100 rpms. Stand back 1 std to 17,927'. Circ and condition mud while filling pits and tanks with brine. Pump 20 hi via pill and displaced well with 9.4 ppg brine water. Spotted 40 bbl hi vis pill in annulus at 13,400' while displacing. Monitor. -12 bph flrrtd rasa. POH on trip tank from 17,927' to 8,957'. Observed well for flow or losses. We~lht~cing .14 BPH. POOH on TT to 5,904'. POOH laying down 4" DP on TT to 374'. Function tested BOP. POOH with BHA. Finish LD BHA #5. Clear floor. LD Geospan unit. Note: Laid out 15 jts 4" DP with hardband wear below min. Pull wear bushing. RU 3 1/2" tbg equipment. PJSM on running 3 1/2" completion equipment. RIH w/ 3 1/2" completion equipment and 188 jts 3 1/2" 9.3# L-80 EUE 8rd mod tbg to 5846'. MU Camco TRMAXX-5E SSSV. Attach control line and test to 5800 psi. Continue running 3 1/2" completion attaching control line 67 jts.(255 jts. total) to 7915' - MU XO & 2 jts. 4 1/2" 12.6# L-80 IBTM tbg to 7997.45' MU FMC tbg hanger & landing jt. -Land tbg w/ tail @ 8032' - XN nipple @ 8020' -Packer @ 7972.78' - GLM @ 7884.55 -SSSV @ 2185.84' LD landing A -set TWC - MU landing jt. B -test hanger seals to 5000 psi ND ROPE & C/O junk sub to 4 1/2" IF - NU & test tree to 5000 psi RU hard lines to tbg & annulus & RU squeeze manifold -PJSM - Displace w/ 170 bbls 9.4 inhibited brine followed by 112 bbls diesel for freeze protect Drop ball and rod. Test lines to 5000 psi. Presaare tbg-to 4800 psi to set pkr. Test tbg to 4500. psi / 30 min. OK. Bi®ed tbg to 7(M3 psi. Pressure annulus to 350Q psi / 30 min. OK. FHxsh and brow down lines. RD same. Set BPV w/ lubricator. Secure tree. ~ Release rig at 0430 hours Printed: 3/14/2006 4:07:08 PM Halliburton Company Global Report ('omp:~u~~: ConocoPhillips Alaska Ina, Date: 2/10/2006 Time: 14:37:58 Patic: t Field: Colville River Unit Co-ordinatclNE) Refe rence: 'N/elh CD3-110, Tr ue North' tiirc: Alpine CD3 Vertical ('TVD) Reference: CD3-110: 49.7 Well: CD3-110 ticction (VS) Referenc e: Well (O.OON,O.OOE,339.12Azi) Wellpath- CD?-110 5urvc}~ Calculation M ethod: Minimum Curvatu re • Db: Oracle Survey: Company: Start Date: Engineer: ~ Tool: Tied-to: ~ _ Survey vID Inc! ~iiw '' TVD Sys TVD NlS E/W MapN MapE Tool ft deg deg -- _ ft _ ft ft ft ft ft _ _ - 36.42 0.00 0.00 36.42 -13.30 0.00 0.00 6003833.74 388188.40 TIE LINE 114.00 0.00 0.00 114.00 64.28 0.00 0.00 6003833.74 388188.40 CB-GYRO-SS 169.30 0.25 70.00 169.30 119.58 0.04 0.11 6003833.78 388188.51 CB-GYRO-SS 258.50 0.50 111.00 258.50 208.78 -0.03 0.66 6003833.70 388189.06 CB-GYRO-SS 348.50 1.50 73.00 348.48 298.76 0.17 2.15 6003833.88 388190.55 CB-GYRO-SS ~ 438.70 2.25 44.00 438.64 388.92 1.79 4.51 6003835.46 388192.93 CB-GYRO-SS 564.10 5.22 24.92 563.76 514.04 8.74 8.63 6003842.34 388197.15 MWD+IFR-AK-CAZ-SC 653.83 8.48 22.37 652.84 603.12 18.56 12.87 6003852.10 388201.54 MWD+IFR-AK-CAZ-SC 744.24 11.01 21.06 741.94 692.22 32.78 18.51 6003866.24 388207.39 MWD+IFR-AK-CAZ-SC 832.58 14.57 25.20 828.07 778.35 50.72 26.27 6003884.05 388215.42 MWD+IFR-AK-CAZ-SC 923.91 18.71 25.17 915.56 865.84 74.38 37.40 6003907.54 388226.90 MWD+IFR-AK-CAZ-SC ~ 1019.75 24.90 24.53 1004.50 954.78 106.68 52.33 6003939.61 388242.31 MWD+IFR-AK-CAZ-SC 'I 1114.54 28.04 24.91 1089.34 1039.62 145.05 70.00 6003977.71 388260.55 MWD+IFR-AK-CAZ-SC 1210.09 30.12 22.54 1172.84 1123.12 187.56 88.65 6004019.94 388279.84 MWD+IFR-AK-CAZ-SC 1304.80 30.66 20.32 1254.54 1204.82 232.16 106.15 6004064.26 388298.00 MWD+IFR-AK-CAZ-SC 1400.90 31.66 21.19 1336.78 1287.06 278.65 123.77 6004110.48 388316.32 MWD+IFR-AK-CAZ-SC ~~ 1496.02 32.00 21.53 1591.34 32.34 22.31 1417.59 1498.28 1367.87 1448.56 325.37 142.04 372.46 160.99 6004156.92 388335.29 6004203.71 388354.94 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2005 ~ Site: Alpine CD3 j Site Position: Northing: 6003886.80 ft Latitude: 70 25 10.481 N From: Map Easting: 388488.10 ft Longitude: 150 54 30.391 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0_00 ft Grid Convergence: 0.00 deg Well: CD3-110 Slot Name: Well Position: +N/-S -57.54 ft Northing: 6003833.74 ft ~ Latitude: 70 25 9.915 N +E/-W -298.90 ft Easting : 388188.40 ft Longitude: 150 54 39.156 W Position Uncertainty: 0.00 ft ~ Wellpath: CD3-110 Drilled From: Well Ref. Point 501032050900 Tie-on Depth: 36.42 ft Current Datum: CD3-110: Height 49.72 ft Above System Datum: Mean Sea Level Magnetic Data: 1/12/2006 Declination: 23.55 deg Field Strength: 57513 nT Mag Dip Angle: 80.72 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ~ ft ft ft deg ~_ 36.42 0.00 0.00 339.12 Survey Program for Definitive Wellpath Date: 1/17!2006 Validated: No Version: 11 Actual From To Survey Toolcode Tool Name ~ ft ft j 1 014 0 438.70 CD3-110 gyro (114.00-438.70) CB-GYRO-SS Camera based gyro single shot -{ - 564.10 17950.47 CD3-110 (564.10 17950.47) - - - MWD+IFR AK CAZ SC MWD+IFR AK CAZ SCC '; ' ' . Halliburton Company Global Report Company: ''CanocoPhillips Alaska Inc. Date: 2/1U/2006 Iimc: 14 :37'58 Page: Field: Coiv iile River U nlt (~u -ord inalc(NE) Reference. Well: CD3-110 , Tru e North Site: Alpin e CD3 ~"crtic al Il ~"D) Reference. CC?'- 110: 49.7 Well: CD3-110 Se ction (~'SI Referen ce: Wel{ (O.OON,O OOE 339.12Azi) Wellpath: C4? -110 Survey Calculation ~bictirod: Minimum Curv ature Db: Oracle Sur~~ce )lll lncl ~ziui 1W'D' ' Sys111~ ~!ti EfW Mapr~' N1apF: fni>1 ft deg deg ft ft ft ft ft ft 1686 .53 33.19 20. 99 1578 .33 1528.61 420. 34 179.99 6004251.30 388374. 65 MWD+IFR-AK-CAZ-SC 1781 .44 33.58 21. 67 1657 .57 1607.85 468. 98 198.99 6004299.65 388394. 37 MWD+IFR-AK-CAZ-SC 1876 .91 33.41 20. 33 1737 .19 1687.47 518. 17 217.87 6004348.54 388413. 98 MWD+IFR-AK-CAZ-SC 1972. 20 33.87 19. 39 1816 .52 1766.80 567. 82 235.80 6004397.91 388432. 65 MWD+IFR-AK-CAZ-SC 2067 .64 34.48 18. 90 1895 .48 1845.76 618. 46 253.38 6004448.28 388450. 99 MWD+IFR-AK-CAZ-SC , 2162 .47 32.89 16. 56 1974 .39 1924.67 668. 54 269.42 6004498.11 388467. 77 MWD+IFR-AK-CAZ-SC 2257 .79 30.12 16. 45 2055 .65 2005.93 716. 30 283.57 6004545.65 388482. 64 MWD+IFR-AK-CAZ-SC 2352 .90 27.38 19. 14 2139 .03 2089.31 759. 85 297.50 6004588.99 388497. 22 MWD+IFR-AK-CAZ-SC 2446 .70 26.65 21. 98 2222 .60 2172.88 799. 74 312.44 6004628.64 388512. 76 MWD+IFR-AK-CAZ-SC 2543. 73 26.50 30. 82 2309 .42 2259.70 838. 52 331.69 6004667.13 388532. 58 MWD+IFR-AK-CAZ-SC 2638 .94 28.09 28. 56 2394 .02 2344.30 876. 46 353.29 6004704.73 388554. 74 MWD+IFR-AK-CAZ-SC 2721 .19 28.11 28. 49 2466 .58 2416.86 910. 50 371.79 6004738.49 388573. 75 MWD+IFR-AK-CAZ-SC 2816 .78 27.53 29. 45 2551 .12 2501.40 949. 52 393.39 6004777.18 388595. 93 MWD+IFR-AK-CAZ-SC 2912. 21 27.30 29. 40 2635 .83 2586.11 987. 80 414.98 6004815.12 388618. 09 MWD+IFR-AK-CAZ-SC 3007 .77 26.73 29. 72 2720 .97 2671.25 1025. 55 436.39 6004852.55 388640. 06 MWD+IFR-AK-CAZ-SC 3103 .27 26.16 29. 96 2806 .47 2756.75 1062. 44 457.55 6004889.12 388661. 77 MWD+IFR-AK-CAZ-SC 3198 .87 26.06 31. 29 2892 .32 2842.60 1098. 65 478.98 6004924.99 388683. 74 MWD+IFR-AK-CAZ-SC 3294 .64 26.86 29. 79 2978 .06 2928.34 1135. 40 500.66 6004961.42 388705. 96 MWD+IFR-AK-CAZ-SC 3389 .98 27.22 29. 74 3062 .97 3013.25 1173. 02 522.18 6004998.71 388728. 04 MWD+IFR-AK-CAZ-SC 3485 .55 27.82 30. 04 3147 .73 3098.01 1211. 31 544.18 6005036.66 388750. 61 MWD+IFR-AK-CAZ-SC 3580 .99 28.98 30. 65 3231 .68 3181.96 1250. 48 567.12 6005075.48 388774. 13 MWD+IFR-AK-CAZ-SC 3675 .00 29.78 29. 33 3313 .60 3263.88 1290. 43 590.17 6005115.07 388797. 77 MWD+IFR-AK-CAZ-SC 3770 .50 32.42 26. 59 3395 .37 3345.65 1334. 00 613.25 6005158.30 388821. 50 MWD+IFR-AK-CAZ-SC 3865. 91 33.03 23. 28 3475 .64 3425.92 1380. 77 634.97 6005204.72 388843. 92 MWD+IFR-AK-CAZ-SC 3961 .24 33.97 18. 29 3555 .15 3505.43 1429. 93 653.60 6005253.60 388863. 29 MWD+IFR-AK-CAZ-SC 4056 .85 35.97 16. 10 3633 .50 3583.78 1482. 28 669.78 6005305.69 388880. 24 MWD+IFR-AK-CAZ-SC 4152 .25 36.43 14. 96 3710 .49 3660.77 1536. 56 684.86 6005359.74 388896. 13 MWD+IFR-AK-CAZ-SC 4247 .68 36.13 11. 80 3787 .42 3737.70 1591. 48 697.93 6005414.45 388910. 02 MWD+IFR-AK-CAZ-SC i 4343 .37 35.45 8. 11 3865 .05 3815.33 1646. 57 707.61 6005469.39 388920. 53 MWD+IFR-AK-CAZ-SC 4438 .92 34.65 7. 67 3943 .27 3893.55 1700. 93 715.15 6005523.62 388928. 88 MWD+IFR-AK-CAZ-SC 4534 .60 34.51 7. 31 4022 .05 3972.33 1754. 77 722.23 6005577.34 388936. 76 MWD+IFR-AK-CAZ-SC 4629 .54 34.52 7. 56 4100 .28 4050.56 1808. 11 729.19 6005630.57 388944. 52 MWD+IFR-AK-CAZ-SC 4725 .29 32.97 7. 46 4179 .89 4130.17 1860. 84 736.14 6005683.19 388952. 26 MWD+IFR-AK-CAZ-SC j 4820. 70 30.13 6. 51 4261 .19 4211.47 1910. 38 742.23 6005732.63 388959. 09 MWD+IFR-AK-CAZ-SC i i ! 4916. 44 30.69 7. 51 4343 .76 4294.04 1958. 48 748.14 6005780.63 388965. 72 MWD+IFR-AK-CAZ-SC 5011 .68 31.01 7. 84 4425 .53 4375.81 2006. 88 754.67 6005828.92 388972. 97 MWD+IFR-AK-CAZ-SC 5106 .97 31.62 7. 61 4506 .93 4457.21 2055. 96 761.32 6005877.89 388980. 36 MWD+IFR-AK-CAZ-SC 5202 .38 31.70 7. 82 4588 .14 4538.42 2105. 58 768.05 6005927.40 388987. 83 MWD+IFR-AK-CAZ-SC 5297. 80 31.58 7. 79 4669 .38 4619.66 2155. 18 774.84 6005976.88 388995. 37 MWD+IFR-AK-CAZ-SC ~ ~ 5393. 02 31.45 7. 50 4750 .56 4700.84 2204. 51 781.47 6006026.11 389002. 72 MWD+IFR-AK-CAZ-SC 5487 .73 31.17 7. 92 4831 .47 4781.75 2253. 28 788.07 6006074.77 389010. 06 MWD+IFR-AK-CAZ-SC 5583 .46 30.48 7. 57 4913 .68 4863.96 2301. 89 794.68 6006123.27 389017. 39 MWD+IFR-AK-CAZ-SC 5678 .77 30.90 7. 09 4995 .64 4945.92 2350. 13 800.88 6006171.41 389024. 32 MWD+IFR-AK-CAZ-SC 5774 .48 31.59 8. 44 5077 .47 5027.75 2399. 32 807.60 6006220.49 389031. 77 MWD+IFR-AK-CAZ-SC 5869 .81 31.54 9. 23 5158 .70 5108.98 2448. 63 815.26 6006269.67 389040. 17 MWD+IFR-AK-CAZ-SC 5965 .34 31.13 11. 58 5240 .29 5190.57 2497. 48 824.23 6006318.38 389049. 87 MWD+IFR-AK-CAZ-SC 6061 .17 30.41 10. 88 5322 .63 5272.91 2545. 57 833.78 6006366.32 389060. 13 MWD+IFR-AK-CAZ-SC 6156 .33 30.30 13. 77 5404 .75 5355.03 2592. 54 844.04 6006413.12 389071. 10 MWD+IFR-AK-CAZ-SC I 6252 .02 29.41 14. 57 5487 .74 5438.02 2638. 72 855.69 6006459.12 389083. 44 MWD+IFR-AK-CAZ-SC j 6346 .54 29.65 14. 44 5569 .99 5520.27 2683. 83 867.36 6006504.04 389095. 78 MWD+IFR-AK-CAZ-SC 6441 .79 . 30.26 13. 03 5652 .51 5602.79 2730. 02 878.65 6006550.06 389107. 76 MWD+IFR-AK-CAZ-SC 6537 .27 30.78 11. 80 5734 .76 5685.04 2777. 38 889.07 6006597.25 389118. 89 MWD+IFR-AK-CAZ-SC ~ -- -- -- - Halliburton Company Global Report Comp.in. : ConocoPhiilips Alaska Inc. Dafe: 2/10/2006 'Time: 14 37:58 Page: 3 ficl~l: Co lville River U nit Co-ordinate(NE) Iicfcrcncc: Well: CD3-110, True North tine: AlpineC~3 ~'crtical(TYD)RcFcmnce: CD3- 110:.49.7 ~1eIL• CD3-110 Section (VS) Refer~ ncc: WeA ( O.OON,Q OOE,339.12Azi) ~~~cllpath: CD3-110 Survey Calculation 1Vlethu~l: Minirr rum Curv ature ' llb: Oracle S u rve~ __ iVID Incl lzim 1WD SysTVD N/S FJW t11ap~ MapF __ ,. "fool ft deg deg ft ft ft ft ft ft ~ 6632. 62 31. 42 11. 75 5816 .41 5766. 69 2825.59 899.12 6006645.31 389129. 66 MWD+IFR-AK-CAZ-SC 6727. 94 33. 87 12. 09 5896. 66 5846. 94 2875.90 909.74 6006695.44 389141. 03 MWD+IFR-AK-CAZ-SC 6823 .33 36. 27 10. 00 5974. 73 5925. 01 2929.68 920.21 6006749.06 389152. 30 MWD+IFR-AK-CAZ-SC 6918 .95 35. 44 6. 61 6052 .24 6002. 52 2985.08 928.32 6006804.33 389161. 24 MWD+IFR-AK-CAZ-SC 7014 .32 36. 72 4. 30 6129 .32 6079. 60 3040.99 933.64 6006860.14 389167. 39 MWD+IFR-AK-CAZ-SC 7109 .68 43. 76 358. 77 6202 .09 6152. 37 3102.48 935.07 6006921.60 389169. 75 MWD+IFR-AK-CAZ-SC 7204. 95 43. 21 358. 94 6271. 21 6221. 49 3168.03 933.76 6006987.16 389169. 42 MWD+IFR-AK-CAZ-SC 7300. 42 41. 90 358. 56 6341. 54 6291. 82 3232.58 932.35 6007051.71 389168. 98 MWD+IFR-AK-CAZ-SC i 7395. 89 45. 49 355. 47 6410 .56 6360. 84 3298.41 928.86 6007117.59 389166. 47 MWD+IFR-AK-CAZ-SC i 7491. 44 48. 23 354. 27 6475 .89 6426. 17 3367.84 922.61 6007187.10 389161. 27 MWD+IFR-AK-CAZ-SC 7587 .07 50. 33 352. 09 6538 .28 6488. 56 3439.79 913.98 6007259.16 389153. 72 MWD+IFR-AK-CAZ-SC 7682 .31 52. 13 350. 12 6597 .92 6548. 20 3513.14 902.49 6007332.67 389143. 32 MWD+IFR-AK-CAZ-SC 7777. 96 54. 67 346. 57 6654. 96 6605. 24 3588.32 886.94 6007408.06 389128. 91 MWD+IFR-AK-CAZ-SC 7873. 77 57. 64 343. 89 6708. 32 6658. 60 3665.23 866.63 6007485.27 389109. 75 MWD+IFR-AK-CAZ-SC i 7967. 84 60. 90 341. 46 6756. 39 6706. 67 3742.40 842.53 6007562.78 389086. 81 MWD+IFR-AK-CAZ-SC j 8064. 80 63. 98 338. 76 6801 .25 6751. 53 3823.20 813.26 6007644.00 389058. 76 MWD+IFR-AK-CAZ-SC 8160 .33 68. 21 335. 95 6839 ,96 6790. 24 3903.76 779.62 6007725.05 389026. 33 MWD+IFR-AK-CAZ-SC 8256 .02 70. 92 332. 82 6873 .37 6823. 65 3984.58 740.84 6007806.44 388988. 77 MWD+IFR-AK-CAZ-SC 8350. 87 73. 53 329. 96 6902. 33 6852. 61 4063.85 697.59 6007886.34 388946. 71 MWD+IFR-AK-CAZ-SC 8447. 57 75. 16 327. 82 6928. 43 6878. 71 4143.56 649.48 6007966.75 388899. 80 MWD+IFR-AK-CAZ-SC ~ ~ 8541. 80 78. 03 326. 04 6950 .27 6900. 55 4220.36 599.46 6008044.29 388850. 95 MWD+IFR-AK-CAZ-SC 8636 .54 80. 52 325. 68 6967 .90 6918. 18 4297.40 547.22 6008122.09 388799. 87 MWD+IFR-AK-CAZ-SC 8732 .08 83. 95 325. 00 6980 .81 6931. 09 4375.25 493.39 6008200.73 388747. 22 MWD+IFR-AK-CAZ-SC 8827 .26 84. 36 322. 21 6990 .50 6940. 78 4451.46 437.22 6008277.77 388692. 20 MWD+IFR-AK-CAZ-SC 8923. 08 86. 78 321. 99 6997 .90 6948. 18 4526.83 378.54 6008354.01 388634. 66 MWD+IFR-AK-CAZ-SC 8940. 38 88. 04 322. 37 6998 .68 6948. 96 4540.49 367.94 6008367.82 388624. 27 MWD+IFR-AK-CAZ-SC 9013. 53 89. 38 322. 69 7000 .33 6950. 61 4598.53 323.45 6008426.51 388580. 66 MWD+IFR-AK-CAZ-SC 9108 .98 89. 26 324. 26 7001 .46 6951. 74 4675.22 266.65 6008504.04 388525. 01 MWD+IFR-AK-CAZ-SC 9204 .77 89. 99 324. 53 7002 .09 6952. 37 4753.10 210.88 6008582.74 388470. 42 MWD+IFR-AK-CAZ-SC 9300 .05 88. 32 324. 20 7003 .49 6953. 77 4830.53 155.38 6008660.99 388416. 09 MWD+IFR-AK-CAZ-SC 9394. 94 87. 76 324. 20 7006 .74 6957. 02 4907.45 99.90 6008738.72 388361. 78 MWD+IFR-AK-CAZ-SC 9490. 88 87. 27 324. 68 7010 .90 6961. 18 4985.42 44.16 6008817.51 388307. 22 MWD+IFR-AK-CAZ-SC I 9585. 96 88. 50 324. 94 7014 .41 6964. 69 5063.07 -10.59 6008895.96 388253. 63 MWD+IFR-AK-CAZ-SC ~ 9681. 18 91. 22 325. 97 7014 .64 6964. 92 5141.49 -64.58 6008975.18 388200. 83 MWD+IFR-AK-CAZ-SC 9776 .74 92. 08 327. 34 7011 .89 6962. 17 5221.28 -117.09 6009055.74 388149. 53 MWD+IFR-AK-CAZ-SC 9872. 18 91. 40 327. 14 7008 .99 6959. 27 5301.51 -168.71 6009136.72 388099. 12 MWD+IFR-AK-CAZ-SC 9967. 01 93. 13 326. 82 7005 .24 6955. 52 5380.95 -220.34 6009216.93 388048. 69 MWD+IFR-AK-CAZ-SC ~ 10062. 60 93. 50 324. 73 6999 .72 6950. 00 5459.86 -274.01 6009296.62 387996. 21 MWD+IFR-AK-CAZ-SC i i 10157. 58 93. 38 322. 46 6994 .02 6944. 30 5536.16 -330.28 6009373.75 387941. 10 MWD+IFR-AK-CAZ-SC 10253. 39 92. 70 322. 97 6988 .94 6939. 22 5612.28 -388.23 6009450.72 387884. 30 MWD+IFR-AK-CAZ-SC ~' 10346 .05 90. 29 322. 86 6986 .52 6936. 80 5686.17 -444.08 6009525.43 387829. 56 MWD+IFR-AK-CAZ-SC 10443. 84 89. 68 320. 87 6986 .54 6936. 82 5763.08 -504.47 6009603.23 387770. 34 MWD+IFR-AK-CAZ-SC 10539. 37 90. 60 323. 76 6986 .31 6936. 59 5838.67 -562.86 6009679.68 387713. 09 MWD+IFR-AK-CAZ-SC 10634. 68 91. 59 325. 69 6984 .49 6934. 77 5916.46 -617.89 6009758.28 387659. 24 MWD+IFR-AK-CAZ-SC 10730 .14 91. 10 326. 02 6982 .25 6932. 53 5995.44 -671.45 6009838.05 387606. 87 MWD+IFR-AK-CAZ-SC i 10825 .40 91. 40 325. 82 6980 .17 6930. 45 6074.33 -724.82 6009917.72 387554. 70 MWD+IFR-AK-CAZ-SC 10920 .69 91. 96 325. 80 6977 .38 6927. 66 6153.11 -778.34 6009997.29 387502. 36 MWD+IFR-AK-CAZ-SC 11016. 28 89. 74 324. 63 6975 .96 6926. 24 6231.61 -832.87 6010076.59 387449. 02 MWD+IFR-AK-CAZ-SC 11111 .61 90. 54 321. 10 6975 .73 6926. 01 6307.59 -890.41 6010153.42 387392. 63 MWD+IFR-AK-CAZ-SC 11206. 97 90. 48 318. 48 6974 .88 6925. 16 6380.41 -951.96 6010227.14 387332. 18 MWD+IFR-AK-CAZ-SC 11301 .70 89. 18 317. 50 6975 .16 6925. 44 6450.79 -1015.36 6010298.46 387269. 85 MWD+IFR-AK-CAZ-SC j 11397 .89 90. 29 317. 86 6975 .60 6925. 88 6521.91 -1080.12 6010370.54 387206. 17 MWD+IFR-AK-CAZ-SC 11492 .96 91. 77 318. 33 6973 .89 6924. 17 6592.65 -1143.61 6010442.22 387143. 76 MWD+IFR-AK-CAZ Halliburton Company Global Report Company: ConocoPhillips Alaska Inc. Darr. 2/10/2006 7inic 14 .37.58 Yagc: a Field: Co lville River U nit Caord4nate(NE) Reference: Weli:- CD3-110, True North Sire: Alpine CD3 Vertical(TV~) Reference: C:D3- 110: 49.7 Well: CD3-110 Se ction (~~.ti1Reference: Well (O.OON,O.OOE,339.12Azi) Wellpa~h: C03-1.10 Survey Calculation Method: Minimum Curvature '' Db: Oracle Surrey MD Intl :1zim fVD_ . Sys TVD \'S L;l~ __ MapN hlapE "foul ft deg deg ft -- ft ft - - ft __ ft _ _ ___ ft 11588.92 89.74 318.42 6972 .63 6922. 91 6664. 38 -1207.34 6010514.88 387081.11 MWD+IFR-AK-CAZ-SC 11684.32 89.62 321.82 6973 .16 6923. 44 6737. 57 -1268.50 6010588.98 387021.06 MWD+IFR-AK-CAZ-SC 11779.38 91.04 324.72 6972 .61 6922 .89 6813. 75 -1325.34 6010665.99 386965.37 MWD+IFR-AK-CAZ-SC 11873.71 93.07 325.51 6969 .23 6919 .51 6891. 07 -1379.25 6010744.10 386912.63 MWD+IFR-AK-CAZ-SC ~ 11969.35 93.13 325.96 6964 .06 6914 .34 6970. 00 -1433.02 6010823.82 386860.05 MWD+IFR-AK-CAZ-SC 12064.70 90.29 327.03 6961 .21 6911. 49 7049. 46 -1485.62 6010904.05 386808.65 MWD+IFR-AK-CAZ-SC 12160.16 92.76 325.87 6958 .67 6908. 95 7128. 98 -1538.36 6010984.35 386757.11 MWD+IFR-AK-CAZ-SC 12255.48 93.13 325.58 6953 .78 6904. 06 7207. 64 -1591.97 6011063.80 386704.69 MWD+IFR-AK-CAZ-SC 12351.25 90.48 324.98 6950 .76 6901. 04 7286. 31 -1646.48 6011143.27 386651.37 MWD+IFR-AK-CAZ-SC , 12446.81 89.68 325.22 6950 .63 6900 .91 7364. 69 -1701.16 6011222.45 386597.88 MWD+IFR-AK-CAZ-SC 12542.57 88.44 324.92 6952 .20 6902 .48 7443. 18 -1755.98 6011301.75 386544.24 MWD+IFR-AK-CAZ-SC 12638.23 90.48 325.75 6953 .10 6903 .38 7521. 86 -1810.38 6011381.22 386491.03 MWD+IFR-AK-CAZ-SC 12733.46 88.38 326.67 6954 .05 6904. 33 7600. 99 -1863.34 6011461.13 386439.27 MWD+IFR-AK-CAZ-SC 12829.13 88.07 326.19 6957 .01 6907. 29 7680. 67 -1916.21 6011541.58 386387.60 MWD+IFR-AK-CAZ-SC 12924.60 89.93 326.98 6958 .68 6908. 96 7760. 34 -1968.78 6011622.03 386336.24 MWD+IFR-AK-CAZ-SC 13019.99 90.05 327.45 6958 .69 6908 .97 7840. 53 -2020.43 6011702.98 386285.79 MWD+IFR-AK-CAZ-SC 13115.40 90.60 327.83 6958 .15 6908 .43 7921. 12 -2071.50 6011784.32 386235.95 MWD+IFR-AK-CAZ-SC I 13210.94 90.60 328.12 6957 .15 6907. 43 8002. 12 -2122.16 6011866:06 386186.51 MWD+IFR-AK-CAZ-SC 13306.39 89.18 328.28 6957 .33 6907. 61 8083. 24 -2172.45 6011947.92 386137.44 MWD+IFR-AK-CAZ-SC 13401.67 88.38 327.00 6959 .36 6909. 64 8163. 70 -2223.44 6012029.13 386087.67 MWD+IFR-AK-CAZ-SC , 13497.37 89.31 326.80 6961 .29 6911 .57 8243. 86 -2275.69 6012110.05 386036.63 MWD+IFR-AK-CAZ-SC 13592.86 91.35 325.61 6960 .74 6911 .02 8323. 20 -2328.80 6012190.17 385984.72 MWD+IFR-AK-CAZ-SC 13688.33 90.11 324.82 6959 .53 6909 .81 8401. 60 -2383.26 6012269.37 385931.44 MWD+IFR-AK-CAZ-SC 13783.84 89.92 323.51 6959 .50 6909 .78 8479. 03 -2439.17 6012347.63 385876.70 MWD+IFR-AK-CAZ-SC 13878.62 92.02 323.13 6957 .90 6908. 18 8555. 03 -2495.78 6012424.46 385821.24 MWD+IFR-AK-CAZ-SC 13973.96 91.28 325.04 6955 .15 6905 .43 8632. 21 -2551.68 6012502.46 385766.51 MWD+IFR-AK-CAZ-SC 14069.59 91.65 326.99 6952 .71 6902 .99 8711. 47 -2605.11 6012582.51 385714.27 MWD+IFR-AK-CAZ-SC 14164.88 93.32 327.25 6948 .57 6898 .85 8791. 42 -2656.79 6012663.21 385663.80 MWD+IFR-AK-CAZ-SC ~ 14260.28 91.84 327.53 6944 .28 6894 .56 8871. 70 -2708.15 6012744.24 385613.65 MWD+IFR-AK-CAZ-SC 14355.48 93.88 327.15 6939 .53 6889 .81 8951. 74 -2759.46 6012825.04 385563.55 MWD+IFR-AK-CAZ-SC 14451.05 91.46 327.42 6935 .08 6885 .36 9032. 06 -2811.05 6012906.11 385513.18 MWD+IFR-AK-CAZ-SC 14546.33 90.66 326.04 6933 .32 6883 .60 9111. 71 -2863.31 6012986.52 385462.12 MWD+IFR-AK-CAZ-SC 14641.70 91.59 326.62 6931 .44 6881 .72 9191. 06 -2916.17 6013066.66 385410.46 MWD+IFR-AK-CAZ-SC 14737.03 92.02 327.00 6928 .44 6878 .72 9270. 80 -2968.33 6013147.16 385359.50 MWD+IFR-AK-CAZ-SC 14832.41 89.98 325.53 6926 .78 6877 .06 9350. 10 -3021.29 6013227.24 385307.74 MWD+IFR-AK-CAZ-SC 14927.79 89.80 326.00 6926 .96 6877 .24 9428. 95 -3074.95 6013306.88 385255.28 MWD+IFR-AK-CAZ-SC j 15024.15 90.79 326.22 6926 .46 6876 .74 9508. 94 -3128.68 6013387.65 385202.75 MWD+IFR-AK-CAZ-SC 15120.91 91.71 326.77 6924 .35 6874 .63 9589. 60 -3182.08 6013469.10 385150.57 MWD+IFR-AK-CAZ-SC 15215.06 92.46 325.49 6920 .93 6871 .21 9667. 72 -3234.51 6013547.99 385099.32 MWD+IFR-AK-CAZ-SC ~ 15310.37 91.47 324.11 6917 .66 6867 .94 9745. 55 -3289.42 6013626.63 385045.59 MWD+IFR-AK-CAZ-SC 15406.12 89.37 324.40 6916 .96 6867 .24 9823. 26 -3345.35 6013705.16 384990.84 MWD+IFR-AK-CAZ-SC 15501.06 90.29 325.77 6917 .24 6867 .52 9901. 11 -3399.68 6013783.80 384937.67 MWD+IFR-AK-CAZ-SC i 15596.11 92.95 327.44 6914 .55 6864 .83 9980. 42 -3451.97 6013863.89 384886.58 MWD+IFR-AK-CAZ-SC 15691.74 93.81 327.58 6908 .91 6859 .19 10060. 94 -3503.25 6013945.16 384836.52 MWD+IFR-AK-CAZ-SC 15787.17 94.12 327.14 6902 .31 6852 .59 10141. 11 -3554.60 6014026.08 384786.38 MWD+IFR-AK-CAZ-SC 15882.36 94.50 323.46 6895 .16 6845 .44 10219. 14 -3608.63 6014104.90 384733.54 MWD+IFR-AK-CAZ-SC 15977.72 93.82 318.28 6888 .24 6838 .52 10292. 89 -3668.63 6014179.53 384674.65 MWD+IFR-AK-CAZ-SC 16073.05 89.92 319.19 6885 .13 6835 .41 10364. 49 -3731.46 6014252.06 384612.91 MWD+IFR-AK-CAZ-SC J 16168.49 88.44 316.00 6886 .49 6836 .77 10434. 95 -3795.80 6014323.47 384549.63 MWD+IFR-AK-CAZ-SC 16263.82 89.18 318.34 6888 .47 6838 .75 10504. 84 -3860.59 6014394.32 384485.90 MWD+IFR-AK-CAZ-SC 16360.88 88.07 318.30 6890 .80 6841 .08 10577. 31 -3925.11 6014467,74 384422.48 MWD+IFR-AK-CAZ-SC 16456.30 87.39 321.77 6894 .58 6844 .86 10650. 37 -3986.34 6014541,71 384362.35 MWD+IFR-AK-CAZ-SC , ~ - - Halliburton Company • Global Report Comp:~ny: ConocoPhillips Alaska Inc. D:~te: ' 2/10/2006 Time: 14:37:5° Pag_ c: Field: Colville River Unit Co-ordioate(NE) Reference: Well: CD3-110, True North Site: Alpine CD3 ~ci`tical (TVD) Reference: CD3-110: 49.7 Well: CD3-110 Section (~"Sl Rcferin ee: Well (O.OON,O:OOE,339.12Azi) Wellpath: CD3-ii0 Survey C~al.uiatiuu~fethad: Minimum Curvature llb: Oracle Survey ~~111 Incl Azim 11~D ties Tl'I) V!S F/W Map; Mapl~: Tao! ft deg deg ft ft ft ft ft ft 16551.98 88.50 322.67 6898.01 6848.29 10725.94 -4044.92 6014618.14 384304.92 MWD+IFR-AK-CAZ-SC 16647.87 92.21 324.02 6897.42 6847.70 10802.85 -4102.15 6014695.89 384248.85 MWD+IFR-AK-CAZ-SC 16742.95 88.81 322.76 6896.57 6846.85 10879.16 -4158.85 6014773.03 384193.31 MWD+IFR-AK-CAZ-SC 16838.61 91.28 325.69 6896.50 6846.78 10956.76 -4214.76 6014851.45 384138.57 MWD+IFR-AK-CAZ-SC 16934.18 89.18 324.68 6896.11 6846.39 11035.21 -4269.32 6014930.71 384085.20 MWD+IFR-AK-CAZ-SC 17029.15 87.52 323.95 6898.85 6849.13 11112.32 -4324.69 6015008.63 384030.99 MWD+IFR-AK-CAZ-SC 17124.76 87.46 325.27 6903.04 6853.32 11190.18 -4380.01 6015087.31 383976.85 MWD+IFR-AK-CAZ-SC 17220.28 92.83 328.11 6902.79 6853.07 11269.97 -4432.44 6015167.87 383925.63 MWD+IFR-AK-CAZ-SC 17315.85 92.27 328.64 6898.54 6848.82 11351.27 -4482.50 6015249.90 383876.79 MWD+IFR-AK-CAZ-SC 17411.43 90.54 327.72 6896.20 6846.48 11432.46 -4532.88 6015331.82 383827.64 MWD+IFR-AK-CAZ-SC 17507.29 89.92 327.95 6895.81 6846.09 11513.60 -4583.91 6015413.72 383777.83 MWD+IFR-AK-CAZ-SC 17601.43 90.42 327.96 6895.53 6845.81 11593.40 -4633.86 6015494.24 383729.09 MWD+IFR-AK-CAZ-SC 17697.88 91.71 327.61 6893.74 6844.02 11674.98 -4685.27 6015576.58 383678.91 MWD+IFR-AK-CAZ-SC 17793.62 93.01 328.35 6889.80 6840.08 11756.09 -4735.99 6015658.43 383629.42 MWD+IFR-AK-CAZ-SC 17887.81 92.33 329.29 6885.41 6835.69 11836.58 -4784.70 6015739.64 383581.92 MWD+IFR-AK-CAZ-SC 17950.47 92.21 331.83 6882.93 6833.21 11891.10 -4815.47 6015794.61 383551.98 MWD+IFR-AK-CAZ-SC 17991.00 92.21 331.83 6881.37. 6831.65 11926.81 -4834.59 6015830.59• 383533.39. PROJECTED to TD I • t3 ~ aos- 6y/ WELL LOG TRANSMITTAL To: State of Alaska Apri127, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-110, AK-MW-3649155 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention o£ Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API# : 5 0-103 -205 09-00. 5~/s lob C-~ 0'20 =C~!/ t 84sis1 • 22-Feb-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD3-110 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 36.42' MD Window /Kickoff Survey 17,950.47' MD (if applicable) Projected Survey: 17,991.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date L ~ ~ ~ ~ Signed O Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) Schlumberger ;,, _~ ~ ~~ . ~ NO. 3695 Schlumberger-DCS ... ~.,. s,e 2525 Gambell Street, Suite 400 ~;~,:.« _.. ,;, ~~„ vtli9S, :~ixi tl3liJ;;iUi; Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ;~ ~~~ Attn: Helen Warman Attn: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Prints CD s CD2-11 REDO 11133210 SCMT ~- )j 12/14/05 1 CD3-110 11133217 SCMT - 1 01/19/06 1 CD2-60 11133216 MEMO BL ~Cj - 01/15!06 1 CD2-60 11133216 PRESSURE & TEMPERATURE LOG 01/15/06 1 SIGNED: DATE: ~I ~'~~~P Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. 02/21 /06 ~- ! STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert~admin.state.ak.us; Bob_Fleckenstein(d~admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc Colville River /Alpine /CD3 02/01/06 Don Mickey /Donald Lutrick Not witnessed Packer Depth Pretest Initial 15 Min. 30 Min. Well CD3-110 Type Inj. W TVD 6,760' Tubing 2,500 2,900 2,900 2,900 Interval I P.T.D. 205-041 Type test M Test psi 3500 Casing 3,511 3,479 3,465 P/F P Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waist G =Gas 1 =Industrial Waistewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1105 CD3-110 MIT.xIs STATE OF ALASKA 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: dim re~~~adr~r:in.state.ak.~~~~ aogc~ p~~d~oe b:v~ad:~n.stae.ulv.~s brl~ e~ke#~~#ef1;:`~Ja~n':i~3.stut~.~i?i.ll~~ Contractor: Doyon Rig No.: 19 DATE: 1/23/2006 Rig Rep.: Krupa/Lupton Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Burley/Hill Field/Unit & Well No.: Colville Rv CD3-110 PTD # 2Ei5-b41 Operation: Drlg: x Workover: Explor.: Test: Initial: x Weekly: Bi-Weekly Test Pressure: Rams: 250/5000 Annular: 250/3500 Valves: 250/5000 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 1 P Housekeeping: P Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP 1 FP BOP STACK: Quantity Size Test Result CHOKE MANIFOLD: Annular Preventer 1 13-5/8 P Quantity Test Result Pipe Rams 1 3-1/2x 6 P No. Valves 16 P Lower Pipe Rams 1 3-1/2x 6 P Manual Chokes 1 P Blind Rams 1 blinds P Hydraulic Chokes 1 P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P ACCUMULATOR SYSTEM: Kill Line Valves 1 3-1/8 P Time/Pressure Test Result Check Valve 0 NA System Pressure 2950 P Pressure After Closure 1500 P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 30 P Trip Tank P P Full Pressure Attained 2 min 38 sec P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): 4@ 2150 psi Meth Gas Detector P P HZS Gas Detector P P Test Results Number of Failures: 1 Test Time: 6.25 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confi rmation to Superviser at: dim reg~ ~adrr:i:~.stUte.ak.u~~ Remarks: Initial test on inside BOP floor valve failed- tested spare-good-rest of test was excellent 24 HOUR NOTICE GIVEN YES X NO Waived By John Spaulding Date 01/20/06 Time 15:30 Witness Lupton/Hilt Test start 19:30pm Finish 1:45am BOP Test (for rigs) BFL 11/09/04 Doyon19 1-23-06 CD3-110-1.xls • ~~r10CC~~~11~f ~ Casing Detail 9 5/8" Surface Casin_g ~ aos-c~ti ~ Well: CD3-110 Date: 4/14/2005 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 37.86 FMC Gen V Hanger 2.20 37.86 Jts 3 to 63 61 Jts 9-5/8" 36# J-55 BTC Csg 2552.43 40.06 Weatherford Float Collar 1.50 2592.49 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 83.80 2593.99 Ray Oil Tools "Silver Bullet" Float Shoe 2.30 2677.79 2680.09 TD 12 1{4" Surface Hale 2690.09 9-5l8" Shae ~ 2680' MD / 2439' TVD RUN TOTAL 36 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - 12 (stop ring on Jt #1 & 2 } and over collars n jts 14, 16, 18, 20, 225 24, 26, 28, 30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 5®, 52, 54, 56, 58, 6t), Ct2 64 67 joints in the pipe shed. Run &3 joints - 4 joints stay out 1 < ~ ~ rG h. v~ r, ld\~, ~ L i t Use Best-o-Life 2000 i e do e MU targue °- 8600 fttlbs Remarks: Up Wt - 155k Dn Wt-135k Block Wt - 75k Supervisor: D. Burley / L. Hill • • ConocoPhillips Alaska Page ~ of s Cementing Report Legal Well Name: CD3-110 Spud Date: 4/12/2005 Common Well Name: CD3-110 Report #: 1 Report Date: 4/14/2005 Event Name: ROT -DRILLING Start: 4/11/2005 End: 4/20/2005 Cement Job Type: Prima S ueeze O en Hole S ueeze Casing Plug Hole Size: Hole Size: Hole Size: Hole Size: TMD Set: 2,680 (ft) SO TMD: (ft) TMD Set: Top Set: (ft) Date Set: 4/14/2005 SO Date: Date Set: BTM set: (ft) Csg Type: Surface Casing SO Type: Csg Type: Plug Oate: Csg Size: SO TMD: Plug Type: SO Date: Drilled Out: Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Jim Thompson Pipe Movement: Pipe'Movement Rot Time Start: Time End: RPM: Init Torque: (ft-Ibf) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Rec Time Start:08:05 Time End: 11:53 SPM: 1 Stroke Length: 20.0 (ft) Drag Up: 155 (Ibs) Drag Down: 132 (Ibs) Stage No: 1 of 1 Type: Cement Casing Start Mix Cmt: 10:32 Disp Avg Rate: 7.50 (bbl/min) Returns: 100 Volume Excess %: 174.00 Start Slurry Displ : 10:33 Disp Max Rate: 8.00 (bbl/min) Total Mud Lost: (bbl) Meas. From: 133 Start Displ: 11:35 Bump Plug: Y Cmt Vol to Surf: 133.00 (bbl) + Time Circ Prior End Pumping: 12:05 Press Prior: 630 (psi) ~~~.., To Cementing: 2.00 End Pump Date: 4/14/2005 Press Bumped: 1,000 (psi) Ann Flow After: N Mud Circ Rate: 294 (gpm) Top Plug: Y Press Held: 2 (min) Mixing Method: Mud Circ Press: 350 (psi) Bottom Plug: Y Float Held: Y Density Meas By: Densiomete Mud Data Type: Spud Mud Density: 9.6 (ppg) Visc: 53 (s/qt) PV/YP: 16 (cp)/18 (Ib/100ftz) Gels 10 sec: 6 (Ib/100ftz) Gels 10 min: 14 (Ib/100ft2) Bottom Hole Circulating Temperature: ('F) Bottom Hole Static Temperature: (°F) Displacement Fluid Type:Mud Density: 9.7 (ppg) Volume: 201.00 (bbl) Stage No 1 Slurry No: 1 of 4 Slurry Data Fluid Type: FLUSH Description: Biozan water w/ nut plug Class: Purpose: Flush Slurry Interval: (ft) To: (ft) Cmt Vol: (bbl) Density: 8.30 (ppg) Yield: (ft'/sk) Mix Water: (gal) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: Q Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Printed: 1 /11 /2006 11:21:00 AM • :~ ConocoPhillips Alaska Page 2 of 3 Cementing- Report Legal Well Name: CD3-110 Spud D ate: 4/12/2005 Common Well Name: CD3-110 Report #: 1 Report Date: 4/14/2005 Event Name: ROT -DRILLING Start: 4/11/20 05 End: 4/20/2005 Stage.No:1 SlurryNo:2of4 Slurry Data Fluid Type: FLUSH Description: MUDPUSH XL Class: Purpose: SPACER Slurry Interval: (ft) To: (ft) Cmt Vol: 50.0 (bbl) Density: 10.50 (ppg) Yield: (ft'/sk) Mix Water: (gal) Water Source: Lake Slurry Vol: (sk) Water Vo1:50.0 (bbl) Other Vol: () Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Stage No:`1 Slurry No: 3 of 4 Slurry Data Fluid Type: LEAD Description: ASLite Class: G Purpose: PRIMARY Slurry Interval: 2,180.00 (ft)fo: 38.00 (ft) Cmt Vol: 363.0 (bbl) Density: 10.70 (ppg) Yield: 4.45 (ft°/sk) Mix Water: 20.15 (gal) Water Source: Lake Slurry Vo1:458 (sk) Water Vol: 219.7 (bbl) Other Vol: (~- r-'~ Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Stage No: 1 Slurry No: 3 of 4 -Additives - Trade Name - T e Concentration'. Units Li uiq d Cpnc_ ! Units D-53 GYPSUM 30.0 D-46 DEFOAMER 0.6 D-79 EXTENDER 1.5 S1 ACCELERATOR 1.5 D-124 FILLITE 43.0 D-44 ACCELERATOR 9.0 %BWOW D-65 DISPERSANT 0.5 Stage No: 1 Slurry No; 4 of 4 Slurry Data Fluid Type: TAIL Description: Class: G Purpose: PRIMARY Slurry Interval: 2,680.00 (ftjfo: 2,180.00 (ft)Cmt Vol: 48.0 (bbl) Density: 15.80 (ppg) Yield: 1.17 f'sk) Mix Water: 5.10 (gal) Water Source: Lake Slurry Vo1239 (sk) Water Vo1:29.5 (bbl) Other Vol: () Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Printed: 1/11/2006 11:21:00 AM • ConocoPhillips Alaska Page 3 of 3 Cementing Report Legal Well Name: CD3-110 Spud Date: 4/12/2005 Common Well Name: CD3-110 Report #: 1 Report Date: 4/14/2005 Event Name: ROT -DRILLING Start: 4/11/2005 End: 4/20/2005 Stage No: 1 Slurry No: 4 of 4 -Additives Trade Name T e Concentration Units Li uid Conc. Units D-46 DEFOAMER 0.2 D-65 DISPERSANT 0.3 S1 ACCELERATOR 2.0 Casing Test Shoe Test Liner Top Test Test Press: 2,500 (psi) Pressure: 16.40 (ppge) Liner Lap: For: 30 (min) Tool: N Pos Test: (ppge) Tool: N Cement Found between Open Hole: (ft) Neg Test: (ppge) Tool: N Shoe and Collar: Y ~ Hrs Before Test: Hrs Before Test: j Cement Found on Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Cement Top: (ft) Under Pressure: (psi) How Determined: Bond Quality: TOC Sufficient: N Cet Run: N Job Rating: Bond Quality: If Unsuccessful Detection Indicator: Temp Survey: N Remedial Cementing Required: N Hrs Prior to Log: Number of Remedial Squeezes: Remarks Cement 9 5/8" casing as follows: Pumped 40 bbls. biozan water w/ nut plug - 6 bpm @ 200 psi w/ rig pump -Switch to Dowell -Pumped 5 bbls water -test cement lines to 2700 psi Dropped btm plug -Mixed & pumped 50 bbls Mudpush XL spacer @ 10.5 ppg - 5.5 bpm @ 176 psi -Mixed & pumped lead slurry (ASL "G" w/ 30% D-53, 0.6% D046, 1.5% D079, 1.5% S001, 43.1% D124, 9% BWOW D44, 0.5% D-65) @ 10.7 ppg - 7.5 bpm @ 175 psi - Observed nut plug marker @ shakers w/ 343 bbls lead pumped -cut off lead & pump down surge can - 363 bbls total lead slurry pumped - switched to tail slurry ("G" w/ 0.2% D46, 0.3% D65, 2% S001) @ 15.8 ppg - 4.5 bpm @ 450 psi Dropped top plug & pumped 20 bbls water w! Dowell -Switch to rig pumps -Displaced w/ 9.6 ppg mud @ 8 bpm 500 to 690 psi for first 171 bbls -slowed to 3.5 bpm @ 590 to 630 psi for last 10 bbls. -Bumped plug to 1000 psi - CIP @ 1205 hrs. Full returns during job w/ 133 bbls cement returns to surface - recripcated pipe until last 100 bbls of displacement Printed: 1 /11 /2006 11:21:00 AM :7 Page 1 of 2 C'onocoPhillips Alaska, Inc. Daily Drilling Report WELL NAME JOB NUMBER EVENT CODE 24 HRS PROG TMD TVD DFS REPT NO. DATE CD3-110 ODR 2,690.0 2,439.0 2.66 4 4/14/2005 SUPERVISOR RIG NAME 8. NO. FIELD NAME / OCS NO. AUTH MD DAILY TANG CUM. TANG D. Burle / L. Hill do on1 co.com 19 Fiord 17,021.0 0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT W/O MUD CUM INTANG W/ MUD Testin u er i e rams. 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST W/MUD PU BHA & RIH. Drill ST + 20'. FIT. Dis lace to LSND. Drill. 4/11/2005 335,409 693,469 LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF AFE AUTH. CLAYSTONE 10069675 LAST SURVEY: DATE TMD INC AZIM LAST CASING NEXT CASING LAST BOP PRES TEST 4/13/2005 2,638.94 28.090 28.560 16.000 in 114.0 ft 9.625 in 2,650.0 ft DENSITY(ppg) 9.70 PP ECD' MUD DATA. DAILY COST 0 CUM COST 0 FV PV/YP `GELS. WL/HTHP FC/T.SOL OILNVAT %Sand/MBT Ph/pM Pf/Mf CI Ca H2S LIME 8S -- - 300 29/45 72/31 8.4/ 3/ / 0.3/ 8.9/ / OPERATIONS SUMMARY ___ __ - FROM TO HOURS. CODE TROUBLE .SUB PHASE DESCRIPTION 00:00 01:00 1.00 DRILL P PULD SURFAC Lay down motor -clear tools from floor -cleaned out drains from drip pans. 01:00 02:30 1.50 CASE P RURD SURFAC Rig up to run 9 5/8" casing. 02:30 02:45 0.25 CASE P SFTY SURFAC Held safety and Opts meeting with crew. 02:45 05:30 2.75 CASE P RUNC SURFAC Run 9 5/8" casing: FS - 2 jts. 9 5/8" 36# J-55 BTC - FC -2 jts. 9 5/8" 36# J-55 BTC (BakerLoc first 4 connections -pump pipe volume to check floats) 32 jts. 9 5/8" 36# J-55 BTC -36 jts. total (1507') Washed down one joint from 963' to 1005' 05:30 06:00 0.50 CASE P CIRC SURFAC Circ one casing volume @ 4 bpm / 220 psi PUW 115K SOW 110K 06:00 07:30 1.50 CASE P RUNC SURFAC Run casing from 1507' to 2640' 27 jts. (63 jts. total) - PU hanger & landing jt. - Land casing on landing ring w/ FMC fluted mandrel hanger w/ shoe @ 2680' FC @ 2592' 07:30 08:00 0.50 CEMENT PULD SURFAC Lay down fill up tool -Blow down Top Drive - MU cement head 08:00 10:00 2.00 CEMENT CIRC SURFAC Stage pumps up to 7.0 bpm - circ and cond mud for cementing -Reciprocated pipe PUW 155K SOW 132K FCP @ 350 psi PJSM for cement job. 10:00 12:15 2.25 CEMENT PUMP SURFAC Cement 9 5/8" casing as follows: Pumped 40 bbls. biozan water w/ nut plug - 6 bpm @ 200 psi w/ rig pump -Switch to Dowell -Pumped 5 bbls water -test cement lines to 2700 psi -Dropped btm plug -Mixed & pumped 50 bbls Mudpush XL spacer @ 10.5 ppg - 5.5 bpm @ 176 psi -Mixed & pumped lead slurry (ASL "G" w/ 30% D-53, 0.6% D046, 1.5% D079, 1.5% S001, 43.1% D124, 9% BWOW D44, 0.5% D-65) @ 10.7 ppg - 7.5 bpm @ 175-330 psi - Observed nut plug marker @ shakers w/ 343 bbls lead pumped -cut off lead pump down surge can - 363 bbls total lead slurry pumped -switched to tail slurry ("G" w/ 0.2% D46, 0.3% D65, 2% S001) @ 15.8 ppg - 4.5 bpm @ 229-171 psi Dropped top plug & pumped 20 bbls water w/ Dowell -Switch to rig pumps -Displaced w/ 9.6 ppg mud @ 8 bpm 500 to 690 psi for first 171 bbls -slowed to 3.5 bpm @ 590 to 630 psi for last 10 bbls. -Bumped plug to 1000 psi - CIP @ 1205 hrs. Full returns during job w/ 133 bbls cement returns to surface - recripcated pipe until last 100 bbls of displacement 12:15 13:00 0.75 CASE P DEQT SURFAC Test casing to 2500 psi for 30 minutes -final pressure 2480 psi. 13:00 14:00 1.00 CEMENT RURD SURFAC Rigged down cement head and bales. 14:00 17:00 3.00 WELCTL NUND SURFAC Nippled down diverter. Dug gravel out of adapter to release. 17:00 19:30 2.50 WELCTL NUND SURFAC Nippled up wellhead and BOP. Printed: 1/11/2006 11:17:34 AM • ConocoPhill'ips Alaska, Inc. Daily Drilling. Report Page 2 of 2 WELL NAME CD3-110 JOB NUMBER EVENT CODE ODR 24 HRS PROG TMD 2,690.0 TVD 2,439.0 DFS 2.66 REPT NO. 4 DATE 4/14/2005 __ OPERATIONS SUMMARY -- FROM' TO 1 ___ HOURS CODE TROUBLE SUB PHASE _- DESCRIPTION 19:30 00:00 4.50 WELCTL BOPE SURFAC Set test plug RU and test BOP. Choke valves 10 & 13 Retested. Slow leak. 24 HR SUMMARY: LD BHA. RU a nd ran 9 5/8" casing. Circulated and cemented casing. ND Diverter. NU BOP. Testing BOP. PERSON NEL DATA COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS ConocoPhillips Company 1 M-I Drilling Fluids 3 Fairweather E&P Service 1 Swaco 4 Doyon Drilling Inc 25 Dowell 2 ACI -Arctic Catering 5 Alaska Clean Seas 2 Halliburton -Sperry-Sun 2 FMC Corporation Wellhe Halliburton -Sperry-Sun 2 ITEM UNITS Fuel gals MATERIALS / CONSUMPTION USAGE ON HAND ITEM' 3,332 4,016 Water, Potable ~ UNITS USAGE ON HAND bbls 120 720 Water, Drilling bbls 600 1,150 Fuel Camp gals 1,120 RESERVOIR AND INTERVAL DATA --~-__- RESERVOIR NAME I ZONE TOP BASE CD1-19A CD3-110 1675 0 COMMENTS Printed: 1/11/2006 11:17:34 AM PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-110 Rig: Doyon 19 Date: 4/14/2005 Volume Input Volume/Stroke Pum Rate: Drilling Supervisor: Burley /Hill Pump used: ~ #2 Mud Pump ~ S P i d ' ~ ~ trokes I ~ 0.1000 i3bls/Strk II ~ 8.00 Strk/min ~ Type of Test: Casing Shce Test LoT/Frr ~ annulus and DP. ump ng own Casing Test Pressure In tegrit Test Hole Size: 8-tR" ~ Casing Shoe Depth Hole Depth Pumpin Shut-in Pum ing Shut-in RKB-CHF: 35 4 Ft 2680.0 Ft-MD 2430.0 Ft-TVD 2710.0 Ft-MD 2457.0 Ft-TVD Strks psi Min psi Strks psi Min si Casing Size and Description: 9-5/8" 36#/Ft J-55 BTC ~ 0 0 0 2500 0 0 0.00 1000 Casin Test Pressure Int e rit Test 2 150 1 2500 2 50 0.25 900 Mud Weight: 9.6 ppg Mud Weight: 9.7 ppg 4 380 2 2490 4 200 0.50 825 Mud 10 min Gel: 14.0 Lb/100 Ft2 Mud 10 min Gel: 14.0 Lb/100 Ft2 6 640 3 2490 6 450 1.00 790 Test Pressure: 2500.0 psi Rotating Weight: ##~## Lbs 8 890 4 2490 8 625 1.50 7 Rotating Weight: 75000.0 Lbs Blocks/Top Drive Weight: 75000 0 Lbs 10 1050 5 2490 10 775 2.00 t, Blocks/Top Drive Weight 75000 0 Lbs Desired PIT EMW: 18 G ppg 12 1220 6 2490 12 890 2.50 720 Estimates for Test: 2 bbls Estimates for Test: 1049 psi 0.7 bbls 14 1400 7 2490 14 950 3.00 700 _ ~ ~ 16 1590 8 2490 16 980 3.50 700 EMW =Leak-off Pressure + Mud Weight = 890 PIT 15 Second 18 1810 9 2490 18 1010 4.00 695 + 9 7 0.052 x TVD 0.052 x 2430 Shut-in Pressure, si 20 2030 10 2490 4.50 690 EMW at 2680 Ft-MD (2430 Ft-TVD) = 16.7 900 22 2260 15 2480 5.00 690 sooo - - Lost 20 ps i durin g test, held ~ , 20 2480 5.50 690 - - 99.2 % of t est pre ssure . 25 2480 6 00 690 . - - ~ ~ ~ 30 2480 6.50 690 o _ . - _ zso - - - _ ~ ~ 7.00 685 - - 7.50 680 _ - 8 00 80 - - . 6 2000 - - _ 8 50 675 w - - - . ~ - 9 00 675 . _ 9.50 670 ~ X500 _ w _ 10.00 ~ -_ a -- - - = -- - -- ~ o00 - - _ - -- - o o ~ z s o s , o , e z o z e s o tCASING TEST Barrels tL EAK-OFF TEST S hut-I O P n tim IT Poi e, M nt inute s Volume Pum ed Volume Bled Back Volume Pum ed Volume Bled Back s s s s Comments: Performed casing test after bumping plugs on cement job ~..ur i iv aurracC uasny rr i Summary • ConocoPhilli s p Casing Detail 7" Casin_a • Well: CD3-110 Date: 4/19/2005 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 35.40 FMC Gen V Hanger 2.52 35.40 Jts 3 to 210 208 Jts 7" 26# L-80 BTCM Csg 8830.55 37.92 Davis Lynch Float Collar 1.32 8868.47 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 86.89 8869.79 Ray Oil Tools "Silver Bullet" Float Shoe 2.13 8956.68 8958.81 TD 8 1 /2" Hole 8969.00 8-1/2" Hole TD @ 8969' MD / 6999.67' TVD 7" Shoe @ 8958.81' MD / 6999.32' TVD Total Centralizers: 45 Straight blade centralizer one per jt on jts # 1-14 Straight blade centralizer one per jt on jts. # 149,150,151 Straight blade centralizer one per jt on every other joint Joints # 153 thru 207 215 joints in shed - 210 total jts. to run Last 5 jts. out Use Best-o-Life 2000 i e do e Remarks: Up Wt - 285k Dn Wt - 165k Block Wt - 75k Supervisor: L. Hill / M. Thornton • C7 ConocoPhi4lips Alaska Page 1 of 3 Cementing Report Legal Well Name: CD3-110. Spud Date: 4/12/2005 Common Well Name: CD3-110 Report #: 2 Report Date: 4/19/2005 Event Name: ROT -DRILLING Start: 4/11/2005 End: 4/20/2005 Cement Job Type: Primary Prima _~ueeze Open Hole S ueeze Casing Plu Hole Size: 8.500 (in) Hole Size: Hole Size: Hole Size: TMD Set: 8,959 (ft) SQ TMD: (ft) TMD Set: Top Set: (ft) Date Set: 4/19/2005 SQ Date: Date Set: BTM set: (ft) Csg Type: Intermediate Casing/Li SQ Type: Csg Type: Plug Date: Csg Size: 7.000 (in.) SO TMD: Plug Type: SQ Date: Drilled Out: Cmtd. Csg: Intermediate Casing/Li Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: James Thompson Pipe Movement: Reciproc irf~ Pipe Movement Rot Time Start: Time End: RPM: Init Torque: (ft-Ibf) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Rec Time Start:17:45 Time End: 21:30 SPM: 1 Stroke Length: 12.0 (ft) Drag Up: 285, 000 (Ibs) Drag Down: 165,000 (Ibs) Stage No: 1 of 1 Type: Cement Casing Start Mix Cmt: 20:26 Disp Avg Rate: 6.00 (bbl/min) Returns: Full Volume Excess %: 40.00 Start Slurry Displ : 20:26 Disp Max Rate: 6.00 (bbl/min) Total Mud Lost: (bbl) Meas. From: Start Displ: 20:37 Bump Plug: Y Cmt Vol to Surf: (bbl) Time Circ Prior End Pumping: 21:45 Press Prior: 790 (psi) To Cementing: 2.25 End Pump Date: 4/19/2005 Press Bumped: 1,400 (psi) Ann Flow After: N Mud Circ Rate: 252 (gpm) Top Plug: Y Press Held: 5 (min) Mixing Method: Batch Mud Circ Press: 630 (psi) Bottom Plug: Y Float Held: Y Density Meas By: Densometer Mud Data Type: KCI Density: 10.0 (ppg) Visc: 38 (s/qt) PV/YP: 11 (cp)/23 (Ib/100ft2) Gels 10 sec: 11 (Ib/100ft~) Gels 10 min: 13 (Ib/100ft2) Bottom Hole Circulating Temperature: (°F) Bottom Hole Static Temperature: (°F) Displacement Fluid Type:Brine Density: 9.6 (ppg) Volume: 338.50 (bbl) Stage No: 1 Slurry'No: 1 of 4 Slurry Data Fluid Type: FLUSH Description: CW100 Class: Purpose: SPACER Slurry Interval: 5,356.00 (ft)fo: 6,241.00 (ft) Cmt Vol: 20.0 (bbl) Density: 8.30 (ppg) Yield: (ft'/sk) Mix Water: (gal) Water Source: Lake Slurry Vol: (sk) Water Vol: 20.0 (bbl) Other Vol: Q Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fiuid Loss Pressure: (°F) Printed: 1 /11 /2006 11:21:08 AM • ConocoPhillips Alaska Page 2 of 3 Cementing Report Legal Well Name: CD3-110 Spud Date: 4/12/2005 Common Well Name: CD3-110 Report #: 2 Report Date: 4/19/2005 Event Name: ROT -DRILLING Start: 4/11/2005 End: 4/20/2005 Stage N'o: 1 Slurry No: 2 of 4 Slurry Data Fluid Type: FLUSH Description: MUDPUSH XL Class: Purpose: SPACER Slurry Interval: 6,241.00 (ft)fo: 7,569.00 (ft) Cmt Vol: 30.0 (bbl) Density: 12.50 (ppg) Yield: (ft'/s k) Mix Water: (gal) Water Source: Slurry Vol: (sk) Water Vol: 30.0 (bbl) Other Vol: Q Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Stage No:-1; Slurry No: 3 of 4 Slurry Data Fluid Type: Description: Class: Purpose: Slurry Interval: (ft) To: (ft) Cmt Vol: (bbl) Density: (ppg) Yield: (ft°/s k) Mix Water: (gal) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: Q Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Stage No: 1 Slurry No: 4 of 4 Slurry Data Fluid Type: TAIL Description: Class: G Purpose: PRIMARY Slurry Interval: 7,569.00 (ftjfo: 8,959.00 (ft) Cmt Vol: 49.1 (bbl) Density: 15.80 (ppg) Yield: 1.16 (ft°/sk) Mix Water: 5.10 (gal) Water Source: lake water Slurry Vo1237 (sk) Water Vo1:28.8 (bbl) Other Vol: () Foam Job: N Test Data Time Temp Pressure Thickening Time: 4.00 Temperature:70 (°F) Compressive Strength 1: (°F) (psi) Free Water: (%) Temperature: (°F) Compressive Strength 2: (°F) (psi) Fluid Loss: (cc) Temperature: (°F) Fluid Loss Pressure: (°F) Stage No: 1 Slurry No: 4 of 4 -Additives Trade Name T e Concentration Units Li uid Conc. Units D-46 DEFOAMER 0.2 %BWOC D-65 DISPERSANT 0.3 %BWOC B-155 0.0 %BWOC D167 %BWOC Printed: 1 /11 /2006 11:21:08 AM • ConocoPhillips Alaska Page 3 of 3 Cementing Report Legal Well Name: CD3-110 Spud Date: 4/12/2005 Common Well Name: CD3-110 Report #: 2 Report Date: 4/19/2005 Event Name: ROT -DRILLING Start: 4/11/2005 End: 4/20/2005 Casing Testa Shoe. Test Liner Top Test Test Press: 3,500 (psi) Pressure: (ppge) Liner Lap: For: 30 (min) Tool: N Pos Test: (ppge) Tool: N Cement Found between Open Hole: (ft) Neg Test: (ppge) Tool: N Shoe and Collar: N Hrs Before Test: Hrs Before Test: Cement Found on Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Cement Top: (ft) Under Pressure: (psi) How Determined: Bond Quality: TOC Sufficient: N Cet Run: N Job Rating: Bond Quality: If Unsuccessful Detection Indicator: Temp Survey: N Remedial Cementing Required: N Hrs Prior to Log: Number of Remedial Squeezes: Remarks Circ & cond mud f/ cement, Stage rate up to 6 bpm @ 630 psi, UP 285K, DN 165K, Held PJSM for cmt job. Cement 7" casing as follows: Pumped 5 bbl CW-100 -Test lines to 3500 psi -pump 15 bbls CW-100 @ 4.2 BPM @ 400 psi -Drop btm plug -Mix & pump 30 bbls MudPush XL @ 12.5 ppg - 4.7 BPM @ 475 psi -Mix & pump 49.1 bbl Lead slurry (Class G w/ .2% D046, .3% D065, .07% 8155, .4% D167) @ 15.8 ppg - 4.5 BPM @ 275 psi Drop top plug -Pumped 20 bbls water w/ Dowell -Switch to rig pumps & displaced w/ 318.5 bbls 9.6 ppg mud @ 6.0 BPM @ 340 to 1050 psi -slowed rate to 3.0 BPM for last 10.0 bbls - 790 psi -bumped plug w/ 1400 psi -check floats - OK - CIP @ 21:45 hrs. Full returns throughout job, Worked casing 12' until 19.7 bbls cement around shoe -then pipe became tight. Rig & test 7" casing to 3500 psi for 30 min. Printed: 1/11/2006 11:21:08 AM • • Page 1 of 2 ConocoPhillips Alaska, Inc. Daily Drilling Report WELL NAME CD3-110 JOB NUMBER EVENT CODE ODR 24 HRS PROG TMD 8,969.0 TVD 7,000.0 DFS 7.66 REPT NO. 9 DATE 4/19/2005 SUPERVISOR L. Hill / M. Thornton RIG NAME 8 NO. do on1 co.com 19 FIELD NAME / OCS NO. Fiord AUTH MD 17,021.0 DAILY TANG 0 CUM. TANG 0 CURRENT STATUS Ni le u BOPE. ACCIDENTS LAST 24 HRS.? DAILY INT W/O MUD 0 CUM INTANG W/ MUD 0 24 HR FORECAST RIH kill strin . ND BOP/NU tree, Frz Protect. DATE OF LAST SAFETY MEETING 4/19/2005 DAILY TOTAL 134,141 CUM COST WI MUD 1,507,586 LITHOLOGY FINE SAND JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF 16.36 AFE 10069675 AUTH. LAST SURVEY: DATE TMD INC AZIM 4/17/2005 8,064.80 63.980 338.760 LAST CASING 7.000 in 8,959.0 ft NEXT CASING in ft LAST BOP PRES TEST 4/15/2005 DENSITY(ppg) 10.00 PP ECD MUD DATA'. DAILY COST 0 CUM COST 0 FV PV/YP GELS WL/HTHP FC/T.SOL OIUWAT %Sand/MBT Ph/pM -Pf/Mf ~ CI ~Ca H2S LIME ES --- - - 38 11/23 11/13 3.4/8.0 1/ / 0.1/20.0 9.5/ 0.05/ - t3HANO. 3 BHA/HOLE CONDITIONS BiTNO: 2RR1 BHA WT. BELOW JARS STRING WT. UP "STRING WT. DN' STRING WT. ROT TORQUE /UNITS BHA LENGTH - J _ __ _ 2,465.75 ITEM DESCRIPTION NO JTS LENGTH O.D. LD. CONN SIZE CONN TYPE _ Bit 1 1.60 8.500 _. 3.000 Geo Pilot 1 20.10 6.750 4.681 DM Flex -NonMag 1 9.20 6.688 1.920 Smart Stabilizer -NonMag 1 2.16 6.625 1.900 MWD - Gr/Res 1 20.75 6.750 1.900 Smart Stabilizer -NonMag 1 2.14 6.625 1.900 MWD - HCIM 1 6.97 6.750 1.900 LWD - NIL6 1 28.04 6.750 1.920 TM HOC 1 10.00 6.700 3.325 Sub -Float 1 1.45 6.688 2.500 Flex Joint -NonMag 1 30.84 6.438 2.813 Flex Joint -NonMag 1 31.05 6.438 2.813 Flex Joint -NonMag 1 30.57 6.250 2.813 Drill Pipe -Heavy Wgt 3 89.86 5.000 3.000 Jars - Up/Down Jars 1 32.80 6.125 2.250 Drill Pipe -Heavy Wgt 14 418.27 5.000 3.000 Drill Pipe 3 95.46 5.000 4.276 Stabilizer -Ghost 1 6.97 6.500 2.875 Drill Pipe 33 1,047.30 5.000 4.276 Stabilizer -Ghost 1 6.95 6.500 2.875 Drill Pipe 31 571.62 5.000 4.276 Crossover 1 1.65 6.563 2.500 - - .BITS __ -- BIT /RUN SIZE 'MANUF. TYPE' SERIAL NO. JETS OR TFA DEPTH IN DATE IN I-O-D-L-B-G-O-R' -- - 2RR1 / 3 8.500 DBS FSF2463 10699015 16/16/16/16/16/ 2,710.0 4/16/200 1-1-WT-A-D-I-NO-TD BIT OPERATIONS BIT /RUN WOB RPM GPM PRESS P BIT ~ ..HRS 24Hr DIST [ 24Hr RO C HRS CUM DEPTH CUM ROP - -- -_ OPERATIONS SUMMARY__ FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 02:30 2.50 DRILL P TRIP INTRM1 Finish POOH, PJSM Remove RA Sources, Down load & Lay down BHA. 02:30 04:30 2.00 CASE P RURD INTRM1 Change top pipe rams to 7", Test rams to 250/5000 psi, Set thin wall wear Printed: 1/11/2006 11:20:37 AM C, Page2of2 ConocoPhlllips Alaska, Inc. Daily Drilling Report WELL NAME CD3-110 JOB NUMBER E VENT CODE ODR 24 HRS PROG TMD 8,969.0 TVD 7,000.0 DFS 7.66 REPT NO. 9 DATE 4/19/2005 __ FROM TO HOURS OPERATIONS SUMMARY ' _ _ __ CODE TROUBLE SUB PHASE DESCRIPTION 02:30 04:30 2.00 CASE P RURD INTRM1 bush. 04:30 06:00 1.50 CASE P RURD INTRM1 PJSM, Rig to run 7" casing. 06:00 17:15 11.25 CASE P RUNC INTRM1 Ran 7" 26# L-80 MBTC as follows: Float shoe (Ray Oil tool Silver bullet) 2 jts. float collar( Weatherford) 2 jts.(first 4 connections made up w/ BakerLoc) filled pipe & checked floats, Ran total of 210 jts. Broke circ @ 2664', 5604', 7223', Make up FMC Hanger & land csg @ 8959'. 17:15 17:45 0.50 CEMENT RURD INTRM1 Rig down Frank's fill up tool, Make up Dowell cement head. 17:45 20:00 2.25 CEMENT CIRC INTRM1 Circ & cond mud f/ cement, Stage rate up to 6 bpm @ 630 psi, UP 285K, DN 165K, Held PJSM for cmt job. 20:00 20:30 0.50 CEMENT PUMP INTRM1 Cement 7" casing as follows: Pumped 5 bbl CW-100 -Test lines to 3500 psi - pump 15 bbls CW-100 @ 4.2 BPM @ 400 psi -Drop btm plug -Mix & pump 30 bbls MudPush XL @ 12.5 ppg - 4.7 BPM @ 475 psi -Mix & pump 49.1 bbl Lead slurry (Class G w/ .2% D046, .3% D065, .07% 6155, .4% D167) @ 15.8 ppg - 4.5 BPM @ 275 psi 20:30 21:45 1.25 CEMENT DISP INTRM1 Drop top plug -Pumped 20 bbls water w/ Dowell -Switch to rig pumps & displaced w/ 318.5 bbls 9.6 ppg mud @ 6.0 BPM @ 340 to 1050 psi -slowed rate to 3.0 BPM for last 10.0 bbls - 790 psi -bumped plug w/ 1400 psi -check floats - OK - CIP @ 21:45 hrs. Full returns throughout job, Worked casing 12' until 19.7 bbls cement around shoe -then pipe became tight. 21:45 22:30 0.75 CASE P MIT INTRMI Rig & test 7" casing to 3500 psi for 30 min. 22:30 23:30 1.00 CASE P RURD INTRMI Cement head & Rig down csg. equip. 23:30 00:00 0.50 CASE T EQIP RURD INTRMI Attempt to lay down 7" landing jt., Trouble backing out same. 24 HR SUMMARY: POOH, UD BHA, Rig & Run 7" Csg to 8959', Circ & Cond. mud, Cement 7" Csg & bump plug, Test 7" Csg to 3500 psi f/ 30 min., Rig down Csg equip. PERSON NEL"DATA COMPANY SERVICE NO. HOURS ,` COMPANY SERVICE NO. HOURS ConocoPhillips Company 1 M-I Drilling Fluids 3 Fairweather E&P Service 1 Swaco 4 Doyon Drilling Inc 26 Dowell 2 ACI -Arctic Catering 5 Alaska Clean Seas 2 Halliburton -Sperry-Sun 2 Quadco / Totco 1 Halliburton -Sperry-Sun 2 MATERIALS /CONSUMPTION ITEM ~ UNITS USAGE ON HAND ITEM UNITS USAGE ON HAND Fuel gals 3,230 9,586 Water, Potable bbls 510 Water, Drilling bbls 990 90 Fuel Camp gals 1,120 RESERVOIR AND INTERVAL DATA RESERVOIR-NAME ZONE TOP BASE COMMENTS CD1-19A CD3-110 560 0 Printed: 1/11/2006 11:20:37 AM • • ' O ~- O V' N M 00 N (O N ~' N N N N N N N O N 0 0 0 m N 00 ~ M f~ Cfl (O (O •y ~ V ~ ~ V ~ ~ ~ ~ ~ ~ d' [Y V '~ V ~ ~ ~ V V d' Y d V ~ tl/ . 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CO i V1 ~ C fl- Y ~ l6 y Ca ~ ~ m t ~ •C O ~ N M ~ ln (p l~ 00 0 0 ~ ~ O N lL') N 'p ; d ~ ~ m C a c ' V •~ a ~ ~ N m _ ~ ° ~ ~ v ~ ~ > a . o > m ~ ~ ~ ~ , ~_ tp o ~ tV ~n j . ~ a ~ - W ~ ° - ' L r _ ON ~ l.L a O C V C 7 'j' ~ ~' Y ~ ° yy o `, ~ ., ~ to v a ~ Q ~ ' a~ ~ n~ aC. ~ ~ ~~ m c W ~ y~ E c ~ ~ m d F- 0 o 0 ti O ui N H C ~ a ~ + ~£~ o "~ a a , v o ~ ~ r c a Z J ~° ~ ; ~ o ` a: N aP ~ t O W _ ~ d ~ 5 s° ~ m i N ~ a ~ ~ rn0 y ~ N ~ ' a ' ~ Z ° a a ~~ d + ~ W Q O a~ ~ « la o ~ ~ (~ °>, ' ~ C ~ `~ ~ M ~ v a o oy N~ ~ ~ ~m 0 W ~ xu d ~ O ~ M in ~ N ~..~ N 0 ~ i ~ ~ d ~ r, N O O ~ p ~ t ~ ~ ~ Q W ~ ~ ~ I J O> O Q M ~ _ ; I.L o N L ^ •~ M + c L ~ - 2 ~ V ° ~ ~ ~ `~ a N~ ~ ~ ° ~ E °' ~ E °' ~ ~, ~~ a w ~ C O N V U .N •y Z ~~ i - C f9 fC C7 C ~ C ' 'I d ~ ~ ~ v H ~ ~ . ._ U U d ~ ~--- ~ - ' ~ l0 CO ~ O , 7 w ~ yLt 3 LL, ~ i m c~ a'O, J " '~ V ~ Q to o p N • ~ O ~ ~ 3 ~ m ~ O U ~ LC f- ~' fn ~ O D v. LL H ~ O h o0 + N w J U ~ ~ ~ ~ O ~ ~ o ~ y N ~ = O a+ ~, ~' ~0 ~ o c Q CO M C C C ~ N N -0 ~ m 7~ ~ N w C dl i L O ~ L N e0 Q N d K~ r N - U ~ Q N N d N O w fC c.o~Oo a ~ C . NG O ~ d OD N •m ffl N O W ~ 0 H LL d V .U '-' N~ O O ,~ O = C C to •N N' Y 4/ 7 O. ~, ai V Ob R L ~ N y A o ] ~ N ~ C 4f ~ ° ~ o a~ in w -~ S w £ ~ ~ ~ (n ~ U U w 4? N ~ N II N Z 3anss3ad _ ~ d _ ~ ~ w ~ w o 3 0 = 1 ~ 3 7 ~ PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-110 Rig: Doyon 19 Date: 4/20/2005 Volume Input Pum Rate: Drilling Supervisor: Hill/Thornton Pump used: Cement Unit ~ -_ - -- _--- --- -, Barrels ~ Bbls/Strk ~ 0.80Ny1 in I ~ Type of Test: ~ Annulus Leak Off Test for Disposal Adequacy ~~ ~ Pumping down annulus. ~ Casing Test Pre re Integrit Test Hole Size: j 8-1/2" ~ ~ Casing Shoe Depth Hole De th Pumping Shut-in ,- um in Shut-in RKB-CHF: 36.1 Ft 2680.0 Ft-MD 2439.0 Ft-TVD 7559.0 Ft-MD 6528.0 Ft-TVD Bbls psi Min psi. Bbls si Min si Casing Size and Description: 9-5/8" 36#/Ft J-55 BTC ~ 0.00 510 Chan es for Annular Ade uac Test Pressure Int e rit Test 1 0 5 160 0.25 440 Enter outer casing shoe test results in comments Mud Weight: 10.0 ppg 2 1 254 0.50 432 Casing description references outer casing string. Inner casing OD: 7 0 In. 3 1.5 380 1.00 428 Hole Size is that drilled below outer casing. 4 2 440 1.50 ~' Use estimated TOC for Hole Depth. 5 2 5 570 2.00 4 Enter inner casing OD at right. Desired PIT EMW: 15 0 ppg 6 3 675 2.50 422 - Estimates for Test: 634 ~ ~ bb= 7 3.5 740 3.00 422 _ I - ~ 8 4 544 3.50 421 EMW =Leak-0ff Pressure + Mud Weight = 740 1 P 5 Second 9 4.5 540 4.00 421 + 0 0.052 x TVD 0.052 x 2439 ~ t-in Pressure, si 10 5 545 4.50 420 EMW at 2680 Ft-MD (2439 Ft-ND) = 15. Q'~-' ~0 15 5.5 520 5.00 419 - " ~ ' 20 6 550 5 50 419 loco ~ . 25 r~ `~ 6.00 419 - - -. -- - 6.50 419 7.00 418 7.50 418 8 00 418 . w 8.50 417 ~ - - - -- 9.00 416 9.50 416 N soo - - _ - - -- 10.00 a _- - - 0 0 1 2 3 a 5 6 7 0 5 1 0 tC ASING TE Ba ST rrels (LEAK -OFF TES T Shut-In tim O PIT Poi e, Minutes nt Volume Pum ed Volume Bled Back Volume Pum ed Volume Bled Back S S S 5 Comments: 9 5!8" shoe L OT n; 16.7 ppg ~,va- i i v r~i a iuiai ~.v ~ Summary Re: CD3-110 Completion • Subject: Re: CD3-110 Completion From: Thomas Maunder <tom_maunder@admin.state.ak.us> ` Date: Thu, 05 Jan 2006 16:05:47 -0900 '~ ~ ~ - ®~ To: "Galiunas, Elizabeth C" <Elizabeth.C.Galiunas@conocophillips.com> CC: Sharon Allsup-Drake <Sharon.K.Allsup-Drake@conocophillips.com> Hi Liz, Thanks for the update. I will put this information in the file. Nothing further should be needed. Sharon, this is one of those wells that we have been messaging about. It is permitted as an injector (which it will ultimately be) however based on the length of the production period that Liz mentions, the 407 should say 1-OIL. When it is time to convert to injector, a 403 will be needed. Call or message with any questions. Tom Maunder, PE AOGCC Galiunas, Elizabeth C wrote, On 1/5/2006 3:45 PM: Tom, ~~ I wanted to update you on our recent changes to the completion. We are planning on pre-producing this well for 3-6 months after start up and to prevent slugging, 3-1/2" tubing will be used instead of 4-1/2". Attached is a new schematic for your files. «Untitted Extract Pages.pdf» Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-265-6247 Cell: (907)-441-4871 ~~' ~ • • ConocoPh i I I ~ ps 10. CD3-110 Completion Schematic ~ ~ ~ - ~ ~ ~ Updated 12/6/05 16" Conductor to 114' Sperry Sun Directional Plan WP06 3-'/:" x 4-'/z' cross-over, 2 jts below 4-'/z" hanger 3-1/2" Camco TRMAXX-5E SSSV w/ DS Profile (Min ID 2.812") at 2000' ND = 2192' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2680' MD / 2430' ND cemented to surface 3-1/2" 9.3 ppf EUE 8rd M tubing run with Jet Lube Run'n'Seal pipe dope Completion 1~ ~ 1) Tubing Hanger 32' 32' 2) 4 Yz", 12.6#/ft, IBT-Mod Tubing 3) Crossover 4) 3-'/i' 9.3#/ft, EUE 8rd Mod tubing 5) Camco TRMAXX-5E SSSV (2.812" ID) 2192' 2000' 6) 3-Y:" 9.3#lft, EUE 8rd Mod tubing 7) Camco KBMG- GLM (2.867" ID) 7787' 6661' 8) 3-'/2' 9.3#/ft, EUE 8rd Mod tubing 9) Baker Premier Packer 7987 6766' 10) 3-'/i' 9.3#/ft, EUE Srd Mod tubing (1) 11) HES "XN" (2.750") w! RHC plug - 63° 8037' 6790' 12) 3-'/z' 9.3#/ft, EUE Srd Mod 10' pup joint 13) WEG 8049' 6795' Camco KBMG GLM (2.867" DRIFT ID) w/ dummy TOC Calculated @ +/- 7409.6' MD / 6420' TVD (659' MD above top Kuparuk C) Top Kuparuk C at 8068' MD / 6803' Top Nechelik at 8807' MD / 6990' ND Baker Premier Packer +/-7987' MD/ 6766' TVD < 250' ND from top of Nechelik Well TD at 18954' MD / 6871 TVD 7" 26 ppf L-80 BTC Mod Casing @ 8959' / 7001' ND @+/- 81° CD3-110 Page 10 of 10 Draft Drilling Program Version l.2 (01/05/2006) RE: CD3-110 Subject: RE: CD3-I1O From: "Galiunas, Elizabeth C" <Elisabeth.C.Galiu~risrc~eonoeophillips.~om- Date: Sat, I ? Dcc Z~)O5 10:48:37 -09~~0 To: ~I'honu~ ~~lau~~der ~tc~m n~aundcr~u?adnlin.statc.~~k.u5=~- Hi, Tom, a bond log has not been run on CD3-110. It will be added in the procedure. Thanks, Liz From: Thomas Maunder [mailto:tam maunder@admin.state,ak.us] Sent: Wed 12/14/2005 10:21 AM To: Galiunas, Elizabeth C Subject: CD3-110 Hi Liz, On CD3-110, has the bond log already been run?? If not, one will need to be accomplished since this well is an injector. Thanks, Tom Maunder, PE AOGCC 1 of 1 1/9/2006 8:27 AM ,~ ~ ~~ ~ ~ ~ FRANK H. MURKOWSK/, GOVERNOR ~~~~ ~~~~++ ~1~~ ~t ~~+ 1~iI[1•a78A OIL t'>•1«1 V[va7 ;~ 333 W. T" AVENUE. SUITE 100 CO~SERQAilO1s COr~TISSIO~ ' ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Chip Alvord FAx (so7) 27s-7sa2 Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: CRU CD3-110 ConocoPhillips Alaska, Inc. Permit No: 205-041 Surface Location: 3941' FNL, 855' FEL, Sec. 5, T12N, R5E, UM Bottomhole Location: 1794' FNL, 3596' FEL, Sec. 30, T13N, R5E, UM .~__ Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. This permit supercedes and replaces the permit previously issued on March 24, 2005, as permit to drill number 205-041. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). DATED this lJ day of December, 2005 cc: Department of Fish Sv Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. Chairman ..F f~ STATE OF ALASKA AL_. OIL AND GAS CONSERVATION COMM~N PERMIT TO DRILL 20 AAC 25.005 EVE ~~~ ~ ~~ E C ~ 3 2005 ~IalakS Ot( CSf COBS. COttN1nISSiE,f1{ 1a. Type of Work: Drill Q Redrill ~ 1b. Current Well Class: Exploratory ~ elopment Oil Multi Re-entry ~ Stratigraphic Test ~ Service ~~~D velopment Gas ~ Single Zone Q 2. Operator Name: 5. Bond: Blanket ~ Single Well ~ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ' CD3-110 3. Address: 6. Proposed Depth: ~ 12. Field/Pool(s): PO Box 100360, Anchorage AK 99510-0360 MD: 18954 ~ ND: 6871 Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Fiord Oil Pool Surface: 3941' FNL, '855 FEL, Sec. 5, T12N, R5E, UM ~ 372105, 372104, 364471, 364470 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4667' FNL, 3126' FEL, Sec. 32, T13N, R5E, UM LAS21122 15-Jan-06 Total Depth: 9. Acres in Property: 14. Distance to Nearest w yyfap'frasi.. 1794' FNL, 3596' FEL, Sec. 30, T13N, R5E, UM ~ 2560 Property: 3800' FNL ADL38s5o8 C~~` 4b. Location of WeII (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well /z• i~ Surface:x- 388188 y- 6003833 Zone- ~ 4 (Height above GL): 36.7 feet Within Pool: CD3-109 @ 2516' i£ CD3-108 @ 4109' Q(peviated wells: Kickoff depth: 300 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: 3168 Surface: 2422 asing Program: Setting Depth Quantity of Cement Size Specifications Top Bottom c.f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 16" 62.5# H-40 Weld 77 37 37 114 114 Portland Cement 12.25" 9.625" 36# J-55 BTC-M 2643 37 37 2680 2439 458 Sx AS Lite & 239 sx Litecrete 8.75" 7" 26# L80 BTC-M 8922 37 37 8959 7001 237 Sx 15.8 ppg class G 6.125" 4.5" 12.6# L80 EUE-M 8017 32 32 8049 6795 Tubing 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry O perations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth ND (ft): Junk (measured): Casing Length Size Cement Volume MD ND Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ~ BOP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard lysis Property Plat ~ Diverter Sketch ~ Seabed Report ~ Drilling Fluid Program ~ 20 AAC 25.050 requi~ents 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact L. Galiunas 265-6247 Printed Name Chip Alvord Title Alpine Drilling Team Leader Signature '(.,_ (~[~ Phone 907-265-6120 Date 12-Dec-05 l2.-~~2 J9~ ~ Commission Use Only Permit to Drill e~ , / API Number: Permit Approv I ~ See cover letter for other Number: Z~S~ V7 ~ 50-~D3~ ~~09~~~ Date: °~ ° ~ requirements. Conditions of approval : /2. /~(. b,s- ~j~~'j~ S ~ ,~~ ;~ ~ ~~ ~y..,` ~ ~~~ Sa ples equired Yes ~] No ~ Mud log required Yes ~ No ydro ulfide measures Yes ~ No ® Directional survey required Yes ~ No Other: c . 0 ~~'Z fd'r S v ~ cs ~ ~ ~j~csZi C~ QQ ~ ~ PPROVED BY ~O~ Appro THE COMMISSION Date: ,~,?r~~ ~' Form 10-401 Revised 06/2004 ~ ~ ~ ~ ~ ~ ~ ~ Submit inDuplicate ConocoPhilli s Alaska, Inc• p Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 December 7, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD3-110 Dear Sir or Madam: ~~110C0~"11~~1 S p ~~'~IVED u ~t ~: ~ 3 2005 ,,pica ;,;; ~ ~a~ ~.ons. Commission Anchorage ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injector well from the Fiord CD3 drilling pad. CD3-110 was started last year and suspended after cementing the intermediate casing. The new target for CD3-110 is 500' away from the previously permitted target (Permit to Drill number 205-041). Previous target is 17021' MD and the current target is 18954' MD. The intended date to re-enter this well is 1/15/2006, once the ice road is available. It is intended that Doyon Rig 19 be used to drill the well CD3-110 will be an horizontal open hole injector in the Nechelik reservoir. At the end of the work program, the well will be closed in awaiting completion of well work and facilities construction that will allow the well to begin injection fourth quarter 2006. It is also requested that the packer placement requirement be relaxed to place the completion packer +/- 250 ft TVD above the Nechelik formation. The packer would be behind cement with 350 ft of cement above. This places the completion at a maximum inclination less than 65° and allows access to the completion with standard wireline tools for future intervention. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program. 4. A proposed completion diagram. 5. A drilling fluids program summary. 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Liz Galiunas at 265-6247, Vern Johnson at 265-6081, or Chip Alvord at 265-6120. • • Sincerely, Liz Galiunas Drilling Engineer Attachments cc: CD3-110 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Liz Galiunas ATO 1704 Vern Johnson ATO 1702 Jack Walker ATO 1740 Jordan Wiess ATO-1782 Lanston Chin Kuukpik Corporation • • CD3-110 Drilling Hazards Summary (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 6-1 /8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 8.8 ppg. Pressure ~ Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well ~ control ractices, mud scaven ers ORIGINAL • • Fiord: CD3-110 Procedure 1. Move in and rig up with Doyon 19, dewater cellar as needed 2. Pull BPV. t c 3. Install and test 2 way check. ~~ ~~ ~~~~~~ ~~\ 4. N D tree. ~ ~ c~ ~~ ~~ `~ Rrc.Ct-`S~5~~ 5. NU and test BOPE to 5000 psi. L'~' `"i~ , ~fi~ 6. Displace diesel freeze protection to brine. 7. Pull hanger and freeze protect string. 8. Run drilling assembly. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 9. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 16. Circulate the hole clean and pull out of hole. 17. Run 4-%2, 12.6#, L-80 tubing with DB injection nipple, gas lift mandrel and packer. Land hanger. 18. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20. Circulate tubing to diesel and install freeze protection in the annulus. 21. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 22. Set BPV and secure well. Move rig off. ORIGINAL • • Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3-109 is the nearest in the pool at 2516' well to well separation at 9450' MD. CD3-108 well to well separation is 4109' at 12975' MD. ~ ' Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. ~ Lost circulation: Faulting within the Nechelik reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. 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 CD3-110 will be injected into the class 2 disposal well on CD1 pad. Upon completion of CD3-110 form 10-403, Application for Sundry Operations -Annular Disposal,will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. 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. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 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 OR161NAL • CD3-110 DRILLING FLUID PROGRAM Production Hole Section - 6 1 /8" Density 9.0-9.3 ppg PV 10 -15 YP 25 - 30 Funnel Viscosity Initial Gels 10 -15 10 minute gels 12 - 20 API Filtrate HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 9.0 - 9.5 KCL 6 Production Hole Section The horizontal production interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with ± 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. ORIGINAL • • Fiord (CD3) Colville River Field CD3-110 Injection Well Completion Plan 16" Conductor to 114' 4-1/2" Camco DB Nipple (3.812') at 2000' ND = 2192' MD 9-5l8" 36 ppf J-55 BTC Surface Casing @ 2680' MD / 2439' TVD cemented to surface 4-1/2" 12.6 ppf L-80 IBT M tubing run with Jet Lube Run'n'Seal pipe dope Completion Updated 11 /4/05 Sperry Sun Directional Plan WP06 Tubing Hanger 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DB nipple 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG2-GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing (2) Baker Premier Packer 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) HES "XN" (3.725")-61.4° inc 4-1/2", 12.6#/ft, IBT-Mod 10' pup joint WEG Camco KBG-2 GLM (3.909" DRIFT ID) w/dummy Baker Premier Packer +/-7gg7' MD/ 6767' ND < 250' ND from top of Nechelik TOC @ +!- 7409.6' MD /6420' ND (659' MD above top Kuparuk C) < Top Kuparuk C at 8069' MD / 6803' Top Nechelik at 8814' MD / 6988' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 8959' / 7001' TVD @+/- 88° MD TVD 32' 32' 2192' 2000' 7787' 6661' 7987 6767' 8037' 6790' 8049' 6795' Well TD at ', 18954' MD / 6871 ND OR161NAL • CD3-110 PRESSURE INFORMATION (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: Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling in MD/TVD ft lbs. / al si si 7" 8959 / 7001 16.0 3168 2422 N/A 18954 / 6871 16.0 3109 N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1 ]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3109 - (0.1 x 6871') = 2422 psi ` ORIGINAL • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD3 CD3-110 Plan: CD3-110 Plan: CD3-110wp06 Proposal Report 06 December, 2005 • HALLIB~JRTQN Sperry Drilling Services ORIGINAL • ~ 1,,,,,,,,,,,,,,,,,,,,,,1,,,11,,,,111,1,1„111,1111,1111111111 ConocoPhillips /~j':i•:~:1 MALLIBUG7TON sMr~N Orilllnp Snrviclp .IIIIIIIIIIIIIIIIIIIIIIIII,IIII.II.I.IIIIIIIIII.1..1111111..1.11..111.11.111 C~kulrtlon MNlnd: Mlnlmum Curvalue E,ror ey~bm: IBCW9A Boa, M~tMtl: Tnv. CYM,dw north Emor 8urfier. Eilipiktl Conk W.Nrp MMlod: Iwl.. amb OwtlNk o.wm: ruo t9n~xon conuel MepMk MoEN: 71p8 Grountl level: 14.50 RKB: Doyon t9 Q 50.898 (~y"r11911A5. 38.381) Ndlher{yASP Y: 800383374 Fa9tlnp'ASP %: 388188.40 .....I III I I I I II IIII I II I II I I I1111111111111111,1111111,1 .................................................................................................................................................... Colvilpple River Unit ACD3- 103 Plan: CD3-110 CD3-110wp06 CD3-110wp06 Target (fce);18953' MD, 6870' TVD, 1794' FNL &3596' FEL; Sec30-T13N-R05E ~ 10500 7000 ~ ------- , i ~ - CD3-11owp05 Possible Fautt € 1 C _~ O € O _~ N `. L ,,,., i€ Q N ca i€ U i€ N N € ~ E L E I- 7' Csg - 81/2" Hole 9 5J8" 0 0 3500 7000 i ft/in) 1 Tie-in Point; 8942' MD, 7000' TVD, CD3-110 (04/18/05), RKB =50.89' 2 ~ 3 ~, T' Csg Pt; 8959' MD, 7001' TVD; 466T FNL & 3126' FEL; Sec32-T13N-R05E / ~ 95/8" fGclc~ff Pant; 4° DLS, 40.6° TFO, 8971' MD, 7001' TVD - ~ ~~ Ceosteer, 90.76° INC, 9061' MD, 7002' TVD Target (Tce); 18953' MD, 6870' TVD, 1794' FNL &3596' FEL; Sec30-T13N-R05E 61 /8" Open Hole / CD3-110wp05 Possible Fautt I ~ 'IT T' Csg - 81 /2" Hole 0 2500 5000 7500 10000 12500 ', C~eosteer, 90.76° INC, 9061' MD, 7002' TVD IGclcoff Print; 4° DLS, 40.6° TFO, 8971' MD, 7001' TVD 3500 T' Csg Pt; 8959' MD, 7001' TVD; 466T FNL & 3126' FEL; Sec32-T13N-R05E ' Tie-in Pant; 8942' MD, 7000' TVD, CD3-110 (04/18/05), RKB =50.89' i 0 _ __ -10500 -7000 -3500 West(-)/East(+) (350( 0 ORIGINAL 61/8" Open Ho\\~ G~ `-' ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD3 Well: CD3-110 Wellbore: Plan: CD3-110 Design: CD3-110wp06 >Project Colville River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Wsll CD3-110 Well Position +NI-S 0.00 ft Northing: 6,003,833.74 ft Latitude: 70° 25' 09.915" N +E/-W 0.00 ft Easting: 388,188.40 ft ~ Longitude: 150° 54' 39.156" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 14.50 ft Wellbore Plan: CD3-110 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 12/31!2005 23.56 80.72 57,512 Design CD3-110wp06 Audit Notes: Version: Phase: PLAN Tfe On Depth: 8,942.67 Vertical Section: Depth From (TVD) +N/-3 +E/-W Dlraction lf~) (ftl l~) (°) 36.39 0.00 0.00 339.12 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimutli Depth +N/S +E/-W Rate Rate Rate ~O lft) (°) (°) (8) (8) l8) (°N008) (°11008) (°11008) (°) 8,942.67 88.04 322.37 7,000.97 4,540.49 367.94 0.00 0.00 0.00 0.00 8,971.35 88.04 322.37 7,001.95 4,563.19 350.44 0.00 0.00 0.00 0.00 9,O6i.03 90.76 324.70 7,002.89 4,635.29 297.16 4.00 3.04 2.60 40.60 18,953.67 90.76 324.70 6,870.89 12,708.69 -5,418.38 0.00 0.00 0.00 0.00 Sperry Drilling Services Planning Report -Geographic Local Co-ordinaM Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: • HALLIBIJRTON Speny Drilling Services Well CD3-110 Doyon 19 ~ 50.89ft (Doyon 19 (14.5 +36.39)) Doyon 19 ~ 50.89ft (Doyon 19 (14.5 +36.39)) True i Minimum Curvature i 12/6/2005 12: 24: 22PM ORIGINAL COMPASS 2003.11 Build 50 • ~ ' Sperry Drilling Services ConocoPhillips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Locai Coordinate Reference: Company: ConocoPhillips Alaska Inc. TVD Reference: Project: Colville River Unit MD Reference: Site: Alpine CD3 North Reference: WeII: CD3-110 SurveyCalculatiorrMethod: Weiibore: Plan: CD3-110 Design: CD3-110wp06 • HALLIBURTON Speny Drilling Services Well CD3-110 Doyon 19 @ 50.88ft (Doyon 19 (14.5 +36.39)) Doyon 19 ~ 50.89ft (Doyon 19 (14.5 +38.39)) True - Minimum Curvature ' Planned Survey CD3-110wp06 Map Map MD Inclination Azimuth TVD SSND +N/S +E1-W Northing Fasting. DLSEV Vert Sei:tlon (ft) (°) l°) lft) cft- (~) lff) (~) (~) i°~ooft) tn-_ 200.00 0.31 89.78 200.00 149.11 0.06 0.25 6,003,833.80 ' 388,188.65 0.00 -0.03 300.00 0.89 84.22 300.00 249.11 -0.06 1.12 6,003,833.66 388,189.52 0.59 -0.46 400.00 1.85 54.27 399.96 349.07 0.83 3.41 6,003,834.51 388,191.82 1.17 -0.45 500.00 3.60 31.13 499.86 448.97 4.21 6.28 6,003,837.86 388,194.73 2.03 1.70 600.00 6.44 23.66 599.49 548.60 11.85 10.03 6,003,845.44 388,198.60 2.90 7.50 700.00 9.71 21.65 698.46 647.57 24.99 15.46 6,003,858.49 388,204.23 3.28 17.84 800.00 13.16 23.83 796.51 745.62 43.12 22.80 6,003,876.50 388,211.84 3.48 32.16 900.00 17.52 25.18 892.95 842.06 67.00 33.93 6,003,900.22 388,223.33 4.38 50.51 1,000.00 23.48 24.65 986.68 935.79 98.46 48.57 6,003,931.46 388,238.43 5.96 74.69 1,100.00 27.48 24.85 1,076.74 1,025.85 137.93 66.70 6,003,870.65 388,257.15 4.01 105.10 1,200.00 29.85 22.83 1,164.41 1,113.52 181.86 86.26 6,004,014.27 388,277.37 2.56 139.17 1,300.00 30.62 20.48 1,250.73 1,199.64 228.77 104.89 6,004,060.90 388,296.69 1.41 176.37 1,300.18 30.62 20.48 1,250.89 1,200.00 228.86 104.92 6,004,060.98 388,296.72 1.32 176.44 Base Permafrost 1,400.00 31.63 21.16 1,336.35 1,285.46 277.09 123.17 6,004,108.93 388,315.69 1.07 215.00 1,500.00 32.01 21.54 1,421.32 1,370.43 326.21 142.37 6,004,157.75 388,335.63 0.43 254.04 1,600.00 32.40 22.22 1,505.95 1,455.06 375.61 162.28 6,004,206.85 388,356.27 0.53 293.10 1,700.00 33.24 21.07 1,589.97 1,539.08 426.05 182.19 6,004,256.98 388,376.93 1.05 333.14 1,800.00 33.55 21.44 1,673.42 1,622.53 477.35 202.29 6,004,307.96 388,397.80 0.37 373.90 1,900.00 33.51 20.12 1,756.83 1,705.94 528.83 221.83 6,004,359.24 388,418.11 0.73 415.13 2,000.00 34.03 19.26 1,839.97 1,789.08 581.26 240.51 6,004,411.28 388,437.57 0.71 457.37 2,100.00 33.97 18.18 1,922.64 1,871.75 634.50 258.76 6,004,464.23 388,456.61 0.81 500.60 2,200.00 31.87 16.52 2,006.44 1,955.55 686.63 274.79 6,004,516.12 388,473.41 2.29 543.60 2,300.00 28.96 17.52 2,092.67 2,041.78 735.12 289.31 6,004,564.38 388,488.66 2.95 583.73 2,400.00 27.02 20.48 2,181.18 2,130.29 779.12 304.44 6,004,608.15 388,504.44 2.38 619.45 2,500.00 26.50 26.62 2,270.52 2,219.63 820.53 321.83 6,004,648.28 388,522.45 2.81 651.94 2,578.71 27.04 30.02 2,340.89 2,290.00 851.22 339.14 8,004,679.71 388,540.22 2.06 674.45 C-40 2,600.00 27.40 28.51 2,359.82 2,308.93 859.68 343.98 6,004,688.09 388,545.18 1.99 680.62 2,680.09 28.10 28.53 2,430.60 2,379.71 892.53 362.03 6,004,720.67 388,563.73 1.05 704.89 9 5/8" 2,700.00 28.10 28.51 2,448.16 2,397.27 900.77 366.51 6,004,728.85 388,588.33 0.05 710.89 2,782.36 27.75 29.08 2,520.89 2,470.00 934.67 385.07 6,004,762.45 388,587.39 0.54 736.04 C-30 2,800.00 27.65 29.26 2,536.51 2,485.62 941.83 389.06 6,004,769.55 388,591.49 0.77 741.31 2,900.00 27.33 29.41 2,625.24 2,574.35 982.00 411.71 6,004,809.38 388,614.74 0.32 770.77 3,000.00 26.79 29.69 2,714.27 2,663.38 1,021.62 434.15 6,004,848.65 388,637.76 0.56 799.79 3,100.00 26.19 29.95 2,803.77 2,752.88 1,060.32 456.33 6,004,887.01 388,660.52 0.61 828.04 3,200.00 26.06 31.27 2,893.57 2,842.68 1,098.21 478.72 6,004,924.56 388,683.47 0.60 855.47 3,208.15 26.12 31.18 2,900.89 2,850.00 1,101.28 480.58 6,004,927.60 388,685.37 0.87 857.67 C-20 3,300.00 26.87 29.79 2,983.09 2,932.20 1,136.60 501.35 6,004,962.61 388,706.67 1.06 883.28 3,400.00 27.27 29.76 3,072.14 3,021.25 1,176.10 523.93 6,005,001.76 388,729.84 0.40 912.13 3,500.00 27.97 30.12 3,160.77 3,109.88 1,216.23 547.03 6,005,041.54 388,753.54 0.72 941.39 3,600.00 29.12 30.41 3,248.59 3,197.70 1,257.47 571.24 6,005,082.41 388,778.36 1.16 971.30 3,700.00 30.40 28.64 3,335.54 3,284.65 1,300.39 595.68 6,005,124.95 388,803.44 1.55 1,002.68 3,800.00 32.59 25.63 3,420.61 3,369.72 1,347.13 619.68 6,005,171.32 388,828.13 2.69 1,037.80 3,900.00 33.32 21.59 3,504.55 3,453.66 1,396.85 641.61 6,005,220.70 388,850.80 2.32 1,076.44 12/6/2005 12:24:22PM Page 3 of 8 COMPASS 2003.11 Build 50 ORIGINAL • • 1-' ConocoPhillips Alaska Sperry Drilling Services Planning Report -Geographic HALLIBURTON Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska lnc. Project: Colville River Unit Site: Alpine CD3 Well: CD3-110 Wellboro: Plan: CD3-110 Design: CD3-110wp06 Local Co-ordinate Referonce: ND Reference: MO Referonce: North Referonce: Survey Calculation Method: Sperry Drilling Services Well CD3-110 Doyon 19 (~ 50.89ft (Doyon 19 (14.5 +36.39)) Doyon 19 ~ 50.89ft (Doyon 19 (14.5 +36,39)) True Minimum Curvature Planned Survey CD3-110wp06 Map Map MD Inclination Azimuth ND SEND +N/S +Ef-W Northing Fasting DLSEV Vert Section tRl (°) (°) (Rl (Tt) lftl (R) (ft) (ff) (°t100R) tfU 4,000.00 34.73 17.43 3,587.55 3,536.66 1,449.52 659.91 6,005,273.08 388,868.89 2.72 1,119.12 4,100.00 36.17 15.61 3,668.82 3,617.93 1,505.42 676.35 6,005,328.73 388,887.18 1.78 1,165.50 4,200.00 36.28 13.46 3,749.39 3,698.50 1,562.68 691.47 6,005,385.76 388,903.14 1.27 1,213.61 4,300.00 35.76 9.89 3,830.22 3,779.33 1,620.32 703.45 6,005,443.20 388,915.98 2.16 1,263.19 4,400.00 34.99 7.86 3,911.73 3,860.84 1,677.61 711.97 6,005,500.35 388,925.35 1.40 1,313.69 4,407.51 34.93 7.83 3,917.89 3,867.00 1,681.88 712.55 6,005,504.61 388,926.00 0.88 1,317.46 K-3 4,500.00 34.56 7.45 3,993.95 3,943.06 1,734.03 719.54 6,005,556.65 388,933.76 0.46 1,363.70 4,600.00 34.52 7.48 4,076.34 4,025.45 1,790.23 726.83 6,005,612.73 388,941.89 0.05 1,413.61 4,700.00 33.42 7.49 4,159.10 4,108.21 1,845.87 734.17 6,005,668.25 388,950.07 1.10 1,462.98 4,800.00 30.81 6.75 4,243.67 4,192.78 1,888.80 740.88 6,005,721.07 388,957.57 2.63 1,510.05 4,900.00 30.58 7.32 4,329.93 4,279.04 1,949.02 746.91 6,005,771.18 388,964.35 0.37 1,554.82 5,000.00 30.96 7.79 4,415.84 4,364.95 1,999.76 753.69 6,005,821.81 388,971.89 0.45 1,599.81 5,100.00 31.56 7.63 4,501.34 4,450.45 2,051.15 760.68 6,005,873.09 388,978.65 0.60 1,645.34 5,200.00 31.70 7.81 4,586.46 4,535.57 2,103.15 767.71 6,005,924.98 388,987.46 0.16 1,691.42 5,300.00 31.58 7.79 4,671.59 4,620.70 2,155.13 774.84 6,005,976.84 388,995.36 0.12 1,737.44 5,400.00 31.44 7.52 4,756.85 4,705.96 2,206.93 781.79 6,006,028.53 389,003.08 0.20 1,783.36 5,500.00 31.10 7.88 4,842.31 4,791.42 2,258.39 788.78 6,006,079.87 389,010.84 0.39 1,828.95 5,600.00 30.54 7.50 4,928.25 4,877.36 2,309.06 795.63 6,006,130.42 389,018.45 0.59 1,873.85 ~ 5,700.00 31.04 7.36 5,014.17 4,963.28 2,359.80 802.11 6,006,181.06 389,025.69 0.50 1,918.95 5,800.00 31.58 8.63 5,099.55 5,048.66 2,411.35 809.40 6,006,232.49 389,033.76 0.85 1,964.51 5,900.00 31.42 9.91 5,184.78 5,133.89 2,462.99 817.68 6,006,284.00 389,042.81 0.89 2,009.81 6,000.00 30.89 11.35 5,270.33 5,219.44 2,513.83 827.54 6,006,334.67 389,053.42 0.91 2,053.80 6,100.00 30.36 11.99 5,356.45 5,305.56 2,563.68 837.44 6,006,384.37 389,064.07 0.62 2,096.85 6,200.00 29.91 14.11 5,442.84 5,391.95 2,612.68 849.04 6,006,433.19 389,076.40 1.16 2,138.50 6,300.00 29.53 14.51 5,529.81 5,478.92 2,660.48 861.34 6,006,480.79 389,089.41 0.44 2,178.77 6,400.00 29.98 13.68 5,616.67 5,565.78 2,708.50 873.54 6,006,528.82 389,102.33 0.61 2,219.29 6,500.00 30.56 12.31 5,703.03 5,652.14 2,757.64 884.85 6,006,577.58 389,114.38 0.91 2,261.17 6,572.00 31.00 11.78 5,764.89 5,714.00 2,793.68 892.47 6,006,613.50 389,122.53 0.71 2,292.13 Albian 97 6,600.00 31.19 11.77 5,788.87 5,737.98 2,807.83 895.42 6,006,627.61 389,125.70 0.67 2,304.30 6,700.00 33.09 11.99 5,873.74 5,822.85 2,859.59 906.26 6,006,679.19 389,137.31 1.91 2,348.79 6,800.00 35.62 10.54 5,956.28 5,905.39 2,914.89 917.53 6,006,734.31 389,149.40 2.66 2,396.44 6,824.21 36.23 10.03 5,975.89 5,925.00 2,928.87 920.07 6,006,748.25 389,152.15 2.81 2,408.60 Albian 96 6,900.00 35.62 7.37 6,037.25 5,986.36 2,972.83 926.81 6,006,792.10 389,159.55 2.21 2,447.28 7,000.00 36.49 4.69 6,118.28 6,067.39 3,031.11 932.86 6,006,850.28 389,166.47 1.81 2,499.57 7,100.00 42.86 359.38 6,195.67 6,144.78 3,094.27 935.20 6,006,913.39 389,169.76 7.21 2,557.75 7,200.00 43.25 358.93 6,268.23 6,217.34 3,163.07 933.85 6,006,982.20 389,169.44 0.50 2,622.51 7,300.00 41.94 358.57 6,341.81 6,290.92 3,230.77 932.40 6,007,049.90 389,169.00 1.34 2,686.28 7,400.00 45.54 355.45 6,414.13 6,363.24 3,299.71 928.76 6,007,118.88 389,166.39 4.20 2,751.99 7,500.00 48.37 354.12 6,482.35 6,431.46 3,372.50 922.14 6,007,191.76 389,180.86 2.99 2,822.36 7,566.49 49.82 352.60 6,525.89 6,475.00 3,422.41 916.32 6,007,241.75 389,155.79 2.79 2,871.07 Top HRZ 7,600.00 50.53 351.86 6,547.35 6,496.46 3,447.92 912.84 6,007,267.30 389,152.70 2.69 2,896.14 7,700.00 52.53 349.53 6,609.62 6,558.73 3,525.14 900.33 6,007,344.70 389,141.35 2.71 2,972.75 7,762.45 54.19 347.21 6,846.89 6,596.00 3,574.21 890.23 6,007,393.91 389,131.88 3.99 3,022.20 Base HR2 12/6/2005 12:24:22PM Page 4 of 8 COMPASS 2003.11 Build 50 ORIGINAL • ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD3 Well: CD3-110 Wellbore: Plan: CD3-110 Design: CD3-110wp06 Sperry Drilling Services Planning Report -Geographic Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculatlon Method: • HALLIBURTON Sperry Drilling Services Well CD3-110 Doyon 19 @ 50.89ft (Doyon 19 (14.5 +36.39)) Doyon 19 @ 50.89ft (Doyon 19 (14.5 +36.39)) True Minimum Curvature Planned Survey CD3-110wp06 - _ Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting p~,SEV .Vert Section: (R) (°) (°) Ift) Iftl (ff) Ift) Ift) (ff) (°MOOfti (tt) 7,800.00 55.28 346.00 6,668.58 6,617.69 3,604.03 883.11 6,007,423.83 389,125.31 3.92 3,052.60 7,836.16 56.40 344.98 6,688.89 6,638.00 3,633.00 875.61 6,007,452.90 389,118.25 3.87 3,082.34 K-1 7,900.00 58.47 343.26 6,723.28 6,672.39 3,684.72 860.88 6,007,504.83 389,104.30 3.96 3,135.91 7,914.66 58.97 342.87 6,730.89 6,680.00 3,696.71 857.23 6,007,516.87 389,100.83 4.12 3,148.41 Top Kuparuk D 8,000.00 61.84 340.61 6,772.99 6,722.10 3,767.19 834.01 6,007,587.69 389,078.66 4.08 3,222.55 8,006.17 62.04 340.44 6,775.89 6,725.00 3,772.33 832.19 6,007,592.85 389,076.92 4.02 3,227.99 Top Kuparuk C 8,016.89 62.38 340.14 6,780.89 6,730.00 3,781.26 828.99 6,007,601.83 389,073.86 4.02 3,237.48 Top Nuigsut - LCU 8,100.00 65.43 337.77 6,817.60 6,766.71 3,850.84 802.25 6,007,671.80 389,048.16 4.48 3,312.02 8,200.00 69.26 334.71 6,855.80 6,804.91 3,935.41 765.08 6,007,756.91 389,012.27 4.76 3,404.29 8,229.04 70.09 333.77 6,865.89 6,815.00 3,959.93 753.25 6,007,781.61 389,000.80 4.17 3,431.42 Base Nuiqsut 8,300.00 72.06 331.55 6,888.90 6,838.01 4,019.55 722.40 6,007,841.67 388,970.85 4.06 3,498.11 8,400.00 74.32 328.92 6,917.59 6,866.70 4,102.61 674.70 6,007,925.43 388,924.41 3.38 3,592.71 8,500.00 76.69 326.87 6,942.91 6,892.02 4,184.51 623.23 6,008,008.08 388,874.18 3.09 3,687.58 8,506.03 76.87 326.75 6,944.29 6,893.40 4,189.42 620.02 6,008,013.04 388,871.04 3.56 3,693.31 8,600.00 79.50 325.83 6,963.45 6,912.56 4,265.79 568.74 6,008,090.16 388,820.92 2.96 3,782.94 8,613.60 79.86 325.78 6,965.89 6,915.00 4,276.85 561.22 6,008,101.34 388,813.56 2.65 3,795.96 Top Nechelik 8,700.00 82.72 325.24 6,979.11 6,928.22 4,347.24 512.91 6,008,172.44 388,766.32 3.36 3,878.95 8,800.00 84.23 323.08 6,989.85 6,938.96 4,428.08 455.06 6,008,254.13 388,709.68 2.63 3,975.10 8,900.00 86.14 322.05 6,998.62 6,947.73 4,506.88 394.12 6,008,333.82 388,649.94 2.17 4,070.44 8,942.67 88.04 322.37 7,000.97 6,950.08 4,540.49 367.94 6,008,367.82 388,624.27 4.52 4,111.17 Tie-in Point; 8942' MD, 7000' TVD, CD3-110 (04118105), RKB = 50.89' 8,959.00 88.04 322.37 7,001.53 6,950.64 4,553.41 357.97 6,008,380.89 388,614.50 0.00 4,126.80 7" Csg Pt; 8959 ' MD, 7001' TVD; 4667' FNL & 3126' FEL ; Sec32-T13N -R05E - 7" Csg - 8 1/2" Hole 8,971.35 88.04 322.37 7,001.95 6,951.06 4,563.19 350.44 6,008,390.77 388,607.11 0.00 4,138.62 Kick-off Point; 4° DLS, 40 .6° TFO, 897 1' MD, 7001' TVD 9,000.00 88.91 323.11 7,002.72 6,951.83 4,585.98 333.10 6,008,413.82 388,590.12 3.99 4,166.09 9,061.03 90.76 324.70 7,002.89 6,952.00 4,635.29 297.16 6,008,463.66 388,554.92 4.00 4,224.98 Geosteer; 90.76° INC, 9061' MD, 7002' TVD 9,100.00 90.76 324.70 7,002.37 6,951.48 4,667.10 274.64 6,008,495.80 388,532.88 0.00 4,262.72 9,200.00 90.76 324.70 7,001.04 6,950.15 4,748.71 216.86 6,008,578.26 388,476.34 0.00 4,359.56 9,300.00 90.76 324.70 6,999.70 6,948.81 4,830.32 159.09 6,008,660.72 388,419.80 0.00 4,456.41 9,400.00 90.76 324.70 6,998.37 6,947.48 4,811.93 101.31 6,008,743.18 388,363.25 0.00 4,553.25 9,500.00 90.76 324.70 6,997.03 6,946.14 4,993.54 43.54 6,008,825.64 388,306.71 0.00 4,650.09 9,600.00 90.76 324.70 6,995.70 6,944.81 5,075.15 -14.24 6,008,908.10 388,250.17 0.00 4,746.93 9,700.00 90.76 324.70 6,994.36 6,943.47 5,156.76 -72.02 6,008,990.56 388,193.63 0.00 4,843.78 9,800.00 90.76 324.70 6,993.03 6,942.14 5,238.37 -129.79 6,009,073.02 388,137.09 0.00 4,940.62 9,900.00 90.76 324.70 6,991.70 6,940.81 5,319.98 -187.57 6,009,155.47 388,080.54 0.00 5,037.46 12/6/2005 12:24:22PM Page 5 of 8 COMPASS 2003.11 Build 50 o~~~~~a~ ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit $ite: Alpine CD3 Well: CD3-110 Wellbore: Plan: CD3-110 Design: CD3-110wp06 Sperry Drilling Services Planning Report -Geographic Local Coordinate Reference: TVD Reference: MD Reference: Norfh Reference: Survey Calculation Method: HALLI BURTON Sperry Drilling Services Well CD3-110 Doyon 19 @ 50.89ft (Doyon 19 (14.5 +36.39)) Doyon 19 ~ 50.89ft (Doyon 19 (14.5 +36.39)) True Minimum Curvature Planned Survey C03-110wp06 Map Map MD Inclination Azimuth TVD SSND +NlS +E/-W Northing Fasting DLSEV Vsrt SacUort (ftl (°) l°) (fti (ft) (ft) (ffl (ff) (fU (°/100ft) (R) 10,000.00 90.76 324.70 6,990.36 6,939.47 5,401.59 -245.34 6,009,237.93 388,024.00 0.00 5,134.30 10,100.00 90.76 324.70 6,989.03 6,938.14 5,483.20 -303.12 6,009,320.39 387,967.46 0.00 5,231.15 10,200.00 90.76 324.70 6,987.69 6,936.80 5,564.81 -360.89 6,009,402.85 387,910.92 0.00 5,327.99 10,300.00 90.76 324.70 6,986.36 6,935.47 5,646.42 -418.67 6,009,485.31 387,854.38 0.00 5,424.83 10,400.00 90.76 324.70 6,985.02 6,934.13 5,728.03 -476.44 6,009,567.77 387,797.84 0.00 5,521.67 10,500.00 90.76 324.70 6,983.69 6,932.80 5,809.64 -534.22 6,009,650.23 387,741.29 0.00 5,618.52 10,600.00 90.76 324.70 6,982.35 6,931.46 5,891.25 -592.00 6,009,732.69 387,684.75 0.00 5,715.36 10,700.00 90.76 324.70 6,981.02 6,930.13 5,972.86 -649.77 6,009,815.15 387,628.21 0.00 5,812.20 10,800.00 90.76 324.70 6,979.69 6,928.80 6,054.47 -707.55 6,009,897.61 387,571.67 0.00 5,909.04 10,900.00 90.76 324.70 6,978.35 6,927.46 6,136.08 -765.32 6,009,980.07 387,515.13 0.00 6,005.89 11,000.00 90.76 324.70 6,977.02 6,926.13 6,217.69 -823.10 6,010,062.53 387,458.58 0.00 6,102.73 11,100.00 90.76 324.70 6,975.68 6,924.79 6,299.30 -880.87 6,010,144.99 387,402.04 0.00 6,199.57 11,200.00 90.76 324.70 6,974.35 6,923.46 6,380.91 -938.65 6,010,227.44 387,345.50 0.00 6,296.41 11,300.00 90.76 324.70 6,973.01 6,922.12 6,462.52 -996.42 6,010,309.90 387,288.96 0.00 8,393.26 11,400.00 90.76 324.70 6,971.68 6,920.79 6,544.13 -1,054.20 6,010,392.36 387,232.42 0.00 6,490.10 11,500.00 90.76 324.70 6,970.35 6,919.46 6,625.74 -1,111.98 6,010,474.82 387,175.87 0.00 6,586.94 11,600.00 90.76 324.70 6,969.01 6,918.12 6,707.35 -1,169.75 6,010,557.28 387,119.33 0.00 6,683.79 11,700.00 90.76 324.70 6,967.68 6,916.79 6,788.96 -1,227.53 6,010,639.74 387,062.79 0.00 6,780.63 11,800.00 90.76 324.70 6,966.34 6,915.45 6,870.57 -1,285.30 6,010,722.20 387,006.25 0.00 6,877.47 11,900.00 90.76 324.70 6,965.01 6,914.12 6,952.18 -1,343.08 6,010,804.66 386,949.71 0.00 6,974.31 12,000.00 90.76 324.70 6,963.67 6,912.78 7,033.79 -1,400.85 6,010,887.12 386,893.17 0.00 7,071.16 12,100.00 90.76 324.70 6,962.34 6,911.45 7,115.40 -1,458.63 6,010,968.58 386,836.62 0.00 7,168.00 12,200.00 90.76 324.70 6,961.01 6,910.12 7,197.01 -1,516.41 6,011,052.04 386,780.08 0.00 7,264.84 12,300.00 90.76 324.70 6,959.67 6,908.78 7,278.62 -1,574.18 6,011,134.50 386,723.54 0.00 7,361.68 12,400.00 90.76 324.70 6,958.34 6,907.45 7,360.23 -1,631.86 6,011,216.95 386,667.00 0.00 7,458.53 12,500.00 90.76 324.70 6,957.00 6,906.11 7,441.84 -1,689.73 6,011,299.41 386,610.46 0.00 7,555.37 12,600.00 90.76 324.70 6,955.67 6,904.78 7,523.45 -1,747.51 6,011,381.87 386,553.91 0.00 7,652.21 12,700.00 90.76 324.70 6,954.33 6,903.44 7,605.06 -1,805.28 6,011,464.33 386,497.37 0.00 7,749.05 12,800.00 90.76 324.70 6,953.00 6,902.11 7,686.67 -1,863.06 6,011,546.79 386,440.83 0.00 7,845.90 12,900.00 90.76 324.70 6,951.67 6,900.78 7,768.28 -1,920.83 6,011,629.25 386,384.29 0.00 7,942.74 13,000.00 90.76 324.70 6,950.33 6,899.44 7,849.89 -1,978.61 6,011,711.71 386,327.75 0.00 8,039.58 13,100.00 90.76 324.70 6,949.00 6,898.11 7,931.50 -2,036.39 6,011,794.17 386,271.20 0.00 8,136.42 13,200.00 90.76 324.70 6,947.66 6,696.77 8,013.11 -2,094.16 6,011,876.63 386,214.66 0.00 8,233.27 13,300.00 90.76 324.70 6,946.33 6,895.44 8,094.72 -2,151.94 6,011,959.09 386,158.12 0.00 8,330.11 13,400.00 90.76 324.70 6,944.89 6,894.10 8,176.33 -2,209.71 6,012,041.55 386,101.58 0.00 8,426.95 13,500.00 90.76 324.70 6,943.66 6,892.77 8,257.94 -2,267.49 6,012,124.01 386,045.04 0.00 8,523.79 13,600.00 90.76 324.70 6,942.33 6,891.44 8,339.55 -2,325.26 6,012,206.47 385,988.50 0.00 8,620.84 13,700.00 90.76 324.70 6,940.99 6,890.10 8,421.16 -2,383.04 6,012,288.92 385,931.95 0.00 8,717.48 13,800.00 90.76 324.70 6,939.66 6,888.77 8,502.77 -2,440.81 6,012,371.38 385,875.41 0.00 8,814.32 13,900.00 90.76 324.70 6,938.32 6,887.43 8,584.38 -2,498.59 6,012,453.84 385,818.87 0.00 8,911.16 14,000.00 90.76 324.70 6,936.99 6,886.10 8,665.99 -2,556.37 6,012,536.30 385,762.33 0.00 9,008.01 14,100.00 90.76 324.70 6,935.65 6,884.76 8,747.60 -2,614.14 6,012,618.76 385,705.79 0.00 9,104.85 14,200.00 90.76 324.70 6,934.32 6,883.43 8,829.21 -2,671.92 6,012,701.22 385,648.24 0.00 9,201.69 14,300.00 90.76 324.70 6,932.98 6,882.09 8,910.82 -2,729.69 6,012,783.68 385,592.70 0.00 9,298.53 14,400.00 90.76 324.70 6,931.65 6,880.76 8,992.43 -2,787.47 6,012,868.14 385,536.16 0.00 9,395.38 14,500.00 90.76 324.70 6,930.32 6,879.43 9,074.04 -2,845.24 6,012,948.60 385,479.62 0.00 8,492.22 14,600.00 90.76 324.70 6,928.98 6,878.09 9,155.65 -2,903.02 6,013,031.06 385,423.08 0.00 9,589.06 14,700.00 90.76 324.70 6,927.65 6,876.76 9,237.26 -2,960.79 6,013,113.52 385,366.54 0.00 9,685.90 14,800.00 90.76 324.70 6,926.31 6,875.42 9,318.87 -3,018.57 6,013,195.98 385,309.99 0.00 9,782.75 14,900.00 90.76 324.70 6,924.98 6,874.09 9,400.48 -3,076.35 6,013,278.43 385,253.45 0.00 9,879.59 15,000.00 90.76 324.70 6,923.64 6,872.75 9,482.09 -3,134.12 6,013,360.89 385,196.91 0.00 9,976.43 12/6/2005 12.24:22PM Page 6 of 8 COMPASS 2003.11 Build 50 ORIGINAL ConocoPhillips Alaska Sperry Drilling Services Planning Report -Geographic Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Site: Alpine CD3 Well: CD3-110 Wellbore: Plan: CD3-110 Design: CD3-110wp06 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: HALLIBURTON Sperry Drilling Services Well CD3-110 Doyon 19 ~ 50.89ft (Doyon 19 (14.5 + 36.39)) Doyon 19 @ 50.89ft (Doyon 19 (14.5 + 36.39)) True Minimum Curvature Planned Survey CD3-110wp06 Map Map MD Inclination Azimuth TW SSTVD +N/-3 +E/-W Northing Easting DLSEY Vert Sectlon (ft) (°) (°) (Rl Iftl (ff) (ft) (R) (R) (°/10081 (ft) 15,100.00 90.76 324.70 6,922.31 6,871.42 9,563.70 -3,191.90 6,013,443.35 385,140.37 0.00 10,073.27 15,200.00 90.76 324.70 6,920.98 6,870.09 9,645.31 -3,249.67 6,013,525.81 385,083.83 0.00 10,170.12 15,300.00 90.76 324.70 6,919.64 6,868.75 9,726.92 -3,307.45 6,013,608.27 385,027.28 0.00 10,266.96 15,400.00 90.76 324.70 6,918.31 6,867.42 9,808.53 -3,365.22 6,013,690.73 384,970.74 0.00 10,363.80 15,500.00 90.76 324.70 6,916.97 6,866.08 9,890.14 -3,423.00 6,013,773.19 384,914.20 0.00 10,480.64 15,600.00 90.76 324.70 6,915.64 6,864.75 9,971.75 -3,480.77 6,013,855.65 384,857.66 0.00 10,557.49 15,700.00 90.76 324.70 6,914.30 6,863.41 10,053.36 -3,538.55 6,013,938.11 384,801.12 0.00 10,654.33 15,800.00 90.76 324.70 6,912.97 6,862.08 10,134.97 -3,596.33 6,014,020.57 384,744.57 0.00 10,751.17 15,900.00 90.76 324.70 6,911.64 6,860.75 10,216.58 -3,654.10 6,014,103.03 384,888.03 0.00 10,848.01 16,000.00 90.76 324.70 6,910.30 6,859.41 10,298.19 -3,711.88 6,014,185.49 384,631.49 0.00 10,944.86 16,100.00 90.76 324.70 6,908.97 6,858.08 10,379.80 -3,769.65 6,014,267.95 384,574.95 0.00 11,041.70 16,200.00 90.76 324.70 6,907.63 6,856.74 10,461.41 -3,827.43 6,014,350.40 384,518.41 0.00 11,138.54 16,300.00 90.76 324.70 6,906.30 6,855.41 10,543.02 -3,885.20 6,014,432.86 384,461.87 0.00 11,235.38 16,400.00 90.76 324.70 6,904.96 6,854.07 10,624.63 -3,942.98 6,014,515.32 384,405.32 0.00 11,332.23 16,500.00 90.76 324.70 6,903.63 6,852.74 10,706.24 -4,000.76 6,014,597.78 384,348.78 0.00 11,429.07 16,600.00 90.76 324.70 6,902.30 6,851.41 10,787.85 -4,058.53 6,014,680.24 384,292.24 0.00 11,525.91 16,700.00 90.76 324.70 6,900.96 6,850.07 10,869.46 -4,116.31 6,014,762.70 384,235.70 0.00 11,622.75 16,800.00 90.76 324.70 6,899.63 6,848.74 10,951.07 -4,174.08 6,014,845.16 384,179.16 0.00 11,719.60 16,900.00 90.76 324.70 6,898.29 6,847.40 11,032.68 -4,231.86 6,014,927.62 384,122.61 0.00 11,816.44 17,000.00 80.76 324.70 6,896.96 6,846.07 11,114.29 -4,289.63 6,015,010.08 384,066.07 0.00 11,913.28 17,100.00 90.76 324.70 6,895.62 6,844.73 11,195.90 -4,347.41 6,015,092.54 384,009.53 0.00 12,010.13 17,200.00 90.76 324.70 6,894.29 6,843.40 11,277.51 -4,405.18 6,015,175.00 383,952.99 0.00 12,106.97 17,300.00 90.76 324.70 6,892.96 6,842.07 11,359.12 -4,462.96 6,015,257.46 383,896.45 0.00 12,203.81 17,400.00 90.76 324.70 6,891.62 6,840.73 11,440.73 -4,520.74 6,015,339.92 383,839.90 0.00 12,300.65 17,500.00 90.76 324.70 6,890.29 6,839.40 11,522.34 -4,578.51 6,015,422.37 383,783.36 0.00 12,397.50 17,600.00 90.76 324.70 6,888.95 6,838.06 11,603.95 -4,636.29 6,015,504.83 383,726.82 0.00 12,494.34 17,700.00 90.76 324.70 6,887.62 6,836.73 11,685.56 -4,694.06 6,015,587.29 383,670.28 0.00 12,591.18 17,800.00 90.76 324.70 6,886.28 6,835.39 11,767.17 -4,751.84 6,015,669.75 383,613.74 0.00 12,688.02 17,900.00 90.76 324.70 6,884.95 6,834.06 11,848.78 -4,809.61 6,015,752.21 383,557.20 0.00 12,784.87 18,000.00 90.76 324.70 6,883.62 6,832.73 11,930.39 -4,867.39 6,015,834.67 383,500.65 0.00 12,881.71 18,100.00 90.76 324.70 6,882.28 6,831.39 12,012.00 -4,925.16 6,015,917.13 383,444.11 0.00 12,978.55 18,200.00 90.76 324.70 6,880.95 6,830.06 12,093.61 -4,982.94 6,015,999.59 383,387.57 0.00 13,075.39 18,300.00 90.76 324.70 6,879.61 6,828.72 12,175.22 -5,040.72 6,016,082.05 383,331.03 0.00 13,172.24 18,400.00 90.76 324.70 6,878.28 6,827.39 12,256.83 -5,098.49 6,016,164.51 383,274.48 0.00 13,269.08 18,500.00 90.76 324.70 6,876.94 6,826.05 12,338.44 -5,156.27 6,016,246.97 383,217.94 0.00 13,365.92 18,600.00 90.76 324.70 6,875.61 6,824.72 12,420.05 -5,214.04 6,016,329.43 383,161.40 0.00 13,462.76 18,700.00 90.76 324.70 6,874.27 6,823.38 12,501.66 -5,271.82 6,016,411.88 383,104.86 0.00 13,559.61 18,800.00 90.76 324.70 6,872.94 6,822.05 12,583.27 -5,329.59 6,016,494.34 383,048.32 0.00 13,656.45 18,900.00 90.78 324.70 6,871.61 6,820.72 12,664.88 -5,387.37 6,016,576.80 382,991.78 0.00 13,753.29 18,953.67 90.76 324.70 6,870.89 6,820.00 12,708.69 -5,418.38 6,016,621.06 382,961.43 0.00 13,805.27 Target (Toe); 1 8953' MD, 6870' TVD, 1794' FNL & 3596 ' FEL; Sec30-T13N-ROSE - 6 1/8" Open Hole -CD3-110wp05 Toe 12/6/2005 12:24:22PM Page 7 of 8 COMPASS 2003.11 Build 50 ORIGINAL ConocoPhillips Alaska ..Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. .Project: Colville River Unit Site: Alpine CD3 Well: CD3-110 Welltrore: Plan: CD3-110 Design: CD3-110wp06 ~~ Sperry Drilling Services HALLIBURTON Planning Report -Geographic Sperry Drilling Services Local CooMinate Reference: Well CD3-110 TVD Reference: Doyon 19 (a3 50.89ft (Doyon 19 (14.5 +36,39)) MD Reference: Doyon 19 ~ 50.89ft (Doyon 18 (14.5 +36.39)) North Reference: True Survey Calculation Metirod: Minimum Curvature Geologic Targets Plan: CD3-110 TVD Target Name +N/S +E/-W Northing Fasting (ft) -snaps ft tt (ft) {ft) 6,870.89 CD3-110wp05 Toe 12,708.69 -5,418.38 6,016,621.06 382,961.43 - Point 6,944.29 CD3-110wp05 Possible Fault 6,692.92 -1,170.61 6,010,542.86 387,118.26 - Horizontal (sides W200.00 H400.00 D0.00) Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter l~) (~t) ('1 (") 2,680.09 2,430.60 9-518 12-1/4 8,959.00 7,001.53 7 8-1/2 18,953.66 6,870.89 6-1/8 6-1/8 Prognosed Forrnatlon Intersection Points Measured Vertical ~~ Inclination Azimuth ~~ +N/-E +E/-W Iftl (") 1°l (ff) (ft) (R) 1,300.18 30.62 20.48 1,250.89 228.86 104.92 Base Permafrost 2,578.71 27.04 30.02 2,340.89 851.22 339.14 C-40 2,782.36 27.75 29.08 2,520.89 934.67 385.07 C-30 3,208.15 26.12 31.18 2,900.89 1,101.28 480.58 C-20 4,407.51 34.93 7.83 3,917.89 1,681.88 712.55 K-3 6,572.00 31.00 11.78 5,764.89 2,793.68 892.47 Albian 97 6,824.21 36.23 10.03 5,975.89 2,928.87 920.07 Albian ~ 7,566.49 49.82 352.60 6,525.89 3,422.41 916.32 Top HRZ 7,762.45 54.19 347.21 6,646.89 3,574.21 890.23 Base HRZ 7,836.16 56.40 344.98 6,688.89 3,633.00 875.61 K-1 7,814.66 58.97 342.87 6,730.89 3,696.71 857.23 Top Kuparok D 8,006.17 62.04 340.44 6,775.89 3,772.33 832.19 Top Kuparuk C 8,016.89 62.38 340.14 6,780.89 3,781.26 828.99 Top Nuigsut 8,016.89 62.38 340.14 6,780.89 3,781.26 828.99 LCU 8,229.04 70.09 333.77 6,865.89 3,959.93 753.25 Base Nuiqsut 8,613.60 79.86 325.78 6,965.89 4,276.85 561.22 Top Nechelik 12/6/2005 12:24: 22PM ORIGINAL COMPASS 2003.11 Build 50 ~ ~ ~.-' ConocoPhillips Alaska ConocoPhillips Alaska Inc. Colville River Unit Alpine CD3 CD3-110 Plan: CD3-110 CD3-110wp06 Anticollision Report 06 December, 2005 HALLIBURTON Sperry Drilling Services ORIGINAL • Q //ti/~ W O 3 °O o~ ~ ``O r~ r M ~ ~ M U ~- Y yy C D F V 4 +~ nm L ~ ~ .. C Y8$S$ Fo g`e8s8 e ~~Fa_ c c , _ ~ ~ iR3 ~~ - QaX~~ ~~88~ G p. ~ ~ u <^ ~33~ Fr $~~~ H d N N !d V U a v ~Y ~~ 3m Uy~ ~_ ~y" W~ ~ ~~:f€ ~ y~ > e4' ~ °` _ Ya w u d ~ 9 ~ ~ 8 i ~g ~ ~ g ~ ~ H s °$ ~ ~ r&G ^~ ~ ~ g~~ a a_~ s s ~ ~ ~ ma a ~~~ f ~o~ a` 7 ~ )~ Q Y ~~e ~~~~ J I' ~' p O Q ~ ai V i i r~ N ~~\~ N~~~ ~ `'\~ \.~, ~~\- ~ ~l \, 0 0 0 0 0 0 0 0 O N CO O ~ 00 N CO O O OO r- ~ N N N M M ~T O r ' i 1~ ,~ /~~,~ ~~',' ~~/ 'i , 0 `, ~ '~-i~ N ~~ O v N N ORIGINAL ~-' ConocoPhillips Alaska Company: ConocoPhillips Alaska Inc. Project: Colville River Unit Reference Site: Alpine CD3 Site. Ertor: O.OOff Reference Well: CD3-110 Well Error: O.OOff Reference Wellbore Plan: CD3-110 Reference Design: CD3-110wp06 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output ertore are at Database: Offset TVD Reference: Well CD3-110 Doyon 19 ~ 50.89ff (Doyon 19 (14.5 +38.39)) Doyon 19 ~ 50.89ff (Doyon 19 (14.5 +38.39)) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Reference CD3-110wp06 Fitter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: 8,971.35 to 18,953.67ff Scan Method: Tray. Cylinder North Rewlts Limited by: Maximum center-center distance of 1,339.44ft Error Surface: Elliptical Conic Waminp Levels evaluated at 0.00 Sigma Survey Tool Pragrem Date 12/6/2005 From To Iftj (ft) Survey (Welibore) Tool Name Description 116.29 440.99 CD3-110 Rip Gyro (Rip: CD3-110) CB-GYR0.SS Camera based gyro single shot 566.39 8,942.67 CD3-110 Rip IFR (Rig: CD3-110) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,942.67 18,953.62 CD3-110wp06 (Plan: CD3-110) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Site Name Offset Well - Wellbore -Design Alpine CD3 CD3-109 -Plan: CD3-109 - CD3.109wp06 Plan: CD3-106 -Plan: CD3-106 -Plan: CD3-106 Plan: CD3-107 -Plan: CD3-107 -Plan: CD3-107 Plan: CD3-108 -Plan: CD3-108 -CD3-108 Rig Surveys Plan: CD3-111 -Plan: CD3-111 -Plan: CD3-111 Plan: CD3-113 -Plan: CD3-113 -Plan: CD3-113 Plan: CD3-114 -Plan: CD3-114 -Plan: CD3-114 Plan: CD3-115 -Plan: CD3-115 -Plan: CD3-115 Plan: CD3-116 -Plan: CD3-116 -Plan: CD3-116 Plan: CD3-117 -Plan: CD3-117 -Plan: CD3-117 Plan: CD3-301 -Plan: CD3-301 -CD3-301 (wp Reference Offset Centre to No-Go Allowable Meawred Measured Centre Distance Deviation blaming Depth Depth Distance (ft) from Plan Ift) Ift) lftl lft) Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range CC -Min centre to center distance or coverpent point. SF -min separation factor, ES -min ellipse separation 12/6/2005 f0:26:50AM Page 2 of 2 COMPASS 2003.11 Build 50 ORDINAL Sperry Drilling Services HALLIBUFZTON Anticollision Report Sperry Drilling Services ConocoPhillips fUaska HALLIBURTON Sperry Drilling Services t C 0 z t .. 3 0 rn GIOiI1m Mlvrt MiYmmQMw ~~ B~MMIOd Tnv. Cyitlr NOrlh bm ~~ w.M9Mwwd:°I~:'~° a.~ w..R ruo t9a ~rawc«+o«~ MgMk Mob! B(30~®LLS Ground Level: 74.50 RKB: Ooym 19 ~ 50.698 (Dgon t9 (14.5 ~ ]6.39 NorNing~ASP V: 6003633.74 6asdnynsv x: 3efitfie.ao Project: Colville River Unk Site: Alpine CD3 Well: CD3-110 Wellbore: Plan: CD3-110 Plan: CD3-110wp06 ~~,,,~ rb no Mo Men. s. t ]Wm 200 95R 9dA1 z 7mta ~m r~~etrr l,d. 7 4 4fAB ts63w a 741'0pn Ka. ste -12500 -10000 -7500 -5000 -2500 0 2500 5000 7500 10000 West(-)/East(+) (25001tfn) • ~ 0 s ~ ~ ~ ~ ~ o ~ ~ ~ ~ g o o ~ ~ ~ ~ ~ ~ g eEB[bE Ez~l BEBSbE ~ = s_ ~ eeesbE '_ ezetl F BEB46£ I I 8 EL991 BEBEb£ 8EBZ6E ~ ~ - E29S1 B£BIbE B£806E w ~ ~ ~ ELBbI 3 ~5 BeebeE ; v - EL9Cl = i eeesae w j ~ ~ ~ € eee[eE fZBZI :: €~_ ~ I ~ _ ~ aee9BE aeeseE ~ rzsu aesoae eeesae ~ ELF I I eeezBE ~ ~°' ~8~ = a BEBIBE n n I j e S ~ ~ ~ I a $ ~ ~ aeeoee I 8 I ~ BbLE ~ i m ^ f~$~ R c BBCE I o o $ L~ 8C CE ~ _ ' u I-1 41^oS / I.I 4NoN ~ EZB~ $ O ui c d ~ c d ~ S g! a 3 3 : ~ do> 1 i U ~ t a I ~ ~ Ezse EzeE I I ~ ~ ~ - EL81 0 ~ - ezs ~o d a --~ LLI- 7 y I to I- ~ I 1 O 1 i~~ ~ 3 LL1£- ~_ ~ I J ~ O - LLIP I a I c I u I -a - -- I -- E I ~ I - LLIS- a ~ ~ ~ 0 4ldep lo~lya~ anal wa~s~cs o ~ p i; U 8 ORIGINAL Closest in POOL ~~rr 6.i Closest Approach: Reference We ll: CD3-110wp 06 Pla Offset Well: C D3-109 Rig IF Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dist. Depth Angle Azi. TVD E(+)/W(-) (339.12°) Comments Depth Angle Azi. TVD E(+)/W(-) (339.12°) Comments in istance in istance (2515.71 ft) in (2515.71 ft) in POOL (6915 - 7045 POOL (6915 - 7045 Subsea TVD) to Subsea TVD) to 2515.71 8613.6 79.86 325.78 6915.049 6008102 388813.8 3795.986 CD3-109 Rig IFR 9450 75.32 354.93 6918.944 6008757 391242.6 3580.199 CD3-110wp06 Plan Closes t Approach: Reference We ll: CD3-110wp 06 Pla Offset Well: C D3-108 Rig IF Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dist. Depth Angle Azi. TVD E(+)/W(-) (339.12°) Comments Depth Angle Azi. TVD E(+)/W(-) (339.12°) Comments in istance m istance (4108.99 ft) in (4108.99 ft) in POOL (6915 - 7045 POOL (6915 - 7045 Subsea TVD) to Subsea TVD) to 4108.99 10125 90.76 324.7 6937.94 6009341 387953.5 5255.367 CD3-108 Rig IFR 12975 89.7 324.75 6950.66 6011660 391345.7 6272.567 CD3-110wp06 Plan POOL Summaryl 12/6/2005 11:19 AM • • • CD3-110wp06 SHL ~: - From: - --, -.-__ -- - - i To:-.~ __ _ Datum: NAD83 Re9ron' alaska + ( Date NAD27 Region, alaska C` Latitude/Longdude Decimal Degrees • ~' Latitude/Lortgitude Decimal Degrees I (' UTM Zone: r`- 1- South: 1 C" UTM Zone: True (- South l: StateF'lane Zone:..q UnRs:;us-ft ~StatePlane' Zone; q Un~s: us~ft I C` .Legal Des«iption (NAD27 only) ~" Leggy Descriptiarr (NAD27 only) i 5 farting Co«dinatcs: E nrl~ng Co«~nates: - __ = - - - I 11528220.32 ~ X: 388188.409011494 ~ Y: 6003580.97 ~ Y: 6003833.76162486 i i. .._ . Ttansform .~.~ Quit Help CD3-110wp06 7" Csg Point ~t~:i ~.,._1_.0.1 xi From:- - - s_~._- - r To::~_ -- - - -, Dati,an: NAD27 ~ Region: alaska + ~ batum: NAD27 + Regwn alaska ~ i ~" Latitude/Lonyitude Decmal Degrees ~ LatrtudelLong4ude Decimal Degrees~~ i '' (" UFM Zone: 1'""~~ r South j f UTM Z«te; True ~ South '' fi ,State F'I~re Zane: q Winds: us•ft ~ , ~ C' State Plane ' Zone: True Units: us~ft + I !' cc~~ I C acre titan Plr;R~~ 7~ils. ~~ ( (` L` Desrxiption(NAD27 J ~ _ -- ~~_ ~ __~ ~_ ( __ .- ~ _ ~_ ~~-~ _____r.__~ _ _ _..~_~ ~ ~ ~-5tartingCoordinates:--~~~~. __..__.-_ rLegaFDescription--___._ - ___ __i 38861d.5 ~ ~ Townahip% 013 N Rye 005 E • Y; 6008380.89 ~ Meridian, U Sectioni~~ I FNL + 4667.2007 FEL ~ 3126.0451 i 1---- ----------- ---~. _ _ _ , ~ Tiansf«m ._._ Qurt Help ORIGINAL ~enii~iao dWH l!nb .;.~~..~ wm~atie~j.i OOL9 S6S0 ~ l3~ Z906'£6Ll ~ lN~ I -_~ 06:ua~aag ~ fl :uapi»4y 90'LZ99409~ :~ 3 900 :a6uQy ~ N £l0 :du{sumol I £6~L96Z8£~ ;x -_ -_ - -.~urnKpiasa0le~''1 -- xq~piooa6~~e~g~ [ZI'~ LZa'GNl urn~~sagl~~l ,'.? ~ (F~~a~ ~,?~7+;r1E ~..ai~du~~a,] ~e6~1 .,,t 11-sn :sru0 anal :auoZ aue~ a~g ~ ~ ~, 1~-sn :shun ~ V :auoZ aue~ a~1S y nog ~ anal :aaoZ W!h ..l ( 4~S J ~~ :auoZ Wlfl .1 ~ ~. saai6aa ~ewioaQl ~~!6up-V~u~.l ..,} i~ ~- saai6aQ ~ewioap~ &I~i!6uoVePl J e~sele uoi6ea ~ LZOb'N ;:wtyep ~ • e~sele :urn6ab, ~ LZOtlN ;wn~ep II _ :ol-~ _ .:__ ~ ___ _._...._..__._ .-._:waj rrr= s ~e~: - - aoy 900 i I -£Q~ • • '"'''~ ,.,.... g..i eti~o.. - 1 --~ 3/t7/ AG GD - - -- C.A. ISSUED PER K05026ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.5, T 12 N, R 5 E, U.M. WELL 'Y 'X' LAT.(N) LONG.(W) SEFSLNE 0/L GND PADN ~E 1 C D 7. 3 -107 3 -11 -1 1 1 + 1 1. 7 -1 t 1 11 1. NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L) Conoco/Phillips Alaska, Inc. ALPINE MODUIE:CD30 UNIT: CO ALPINE PROJECT CD-3 WELL CONDUCTORS AS-BUILT LOCATIONS CARD FllE N0. OS-03-03-tA-2 3-17-OS DRAWING N0: CE-CD30-111 PART: 2 of 3 REV: 1 • • 7 Y. Royalty AUL C3HH50`.i 147.08 Bld/Acre "389963 ACf_ .3859 Y. Net Profit Is35.24 Ald/Arse 1661 Y. Royalty .t 1J Blo/Acre fl?13 BIn/ 72/31/04 1667 % 4CY~liY OD % Net ProFrt .67 '/. Roy6ay `- 16.67 % kc O.OC % Net r-o-'i Exp: 12;31/04 D % het proFlt OLO % het - - -- _Exp 12/3;/04 _ p~ C6/3!/C9 Lx: :id/31 IL_IP\ A P[NE ALASKA, LC 2? 00% Pr:Lr 'I'S A 1N ALASKA r , C 2. CO% 4DARK~ PETR;LF.1M CCRPCRA':Oh 220C'. °NAJA<KI: PF R ., - -~ ----------~ _ ~CGPHrLI i=S ALASKA, VL 56002 1; . o !F.:M ^R' GiAi:Oh 220 :I r .vS A_olM1g A! A\KP, LAC 2200% AG4QKD ?ETRpLEUM CGRR!]ItAT1%N 22.fiA% AhADA4K:: Nr.'Li=41 ._1 S ALACKP, :N4. SE.OOY. 1M17G:r'h:! I :°S ALASKA. INC 56.OOY. ALPS Alt'INE ALASKA, LAC 2?.COX °Hi_ I i°S A OCDPHiiI 1PS ALASKA, ;L1C 56 0C% CUNCCOPMI: ALv G3UH5D8 Colville fiver Unit ' s3a 40 Bld/Acre 0388509 16 67 % Royalty t1 B~d/ncre I O.OC X Net r roFlt 7 % Royalty Exp 1219L/04 1 0389964 Dl 0390071 Net Proft CD3-110 {Revised) '..28 Bd/n~re 136.:33 HId/ 72/31/D4 rl!~!i?S Al P'NE A~A~SKA, ' I ! 22.GC% a+.cu 61 % k;;yatY 16.67 % Roy A'vACAkxD ?ETRUl.rl11A~ C-~kP_iRAr1G4 -'2.CD% i v ~- - 00 % Net Pr~F : C00 % Net .CNnC-" ~; ,8/31/^9 F>s ~ / IRKL PE tR,.I LJM L<p1~rLL:1~:2S A~iA,~ly;;~.GJy 1PS A PINC AI ASKA ;.! l' 22.00% ANADARKO PETROLE ' - - - _ _ y - p Ott 31/ - ~ :4A 'UN 22 OC% PHILLIPS ALPINE AL A, LLC 22,00% ~ :~ . ~6VA'Ak<fl "L'RI _E.. :CDHi_l,n$ 41AS1tn, -VC ,1600% ICONQtpPHILLIPS AL lNC. 56AOX "bii' I P !L.?IS A l'iVF ALASKA, °DARKG Pf IR]IFUM FF+2PQRA`!G 11 ;; .='.C-Z IP•Ill_1f'S A P: F A ~ ~ \, lC 22 D0% i; ..iPS ALP:NL A.A'KA. LL.". 22 N _L!1'SK4, . I C ?c 00% \ I~GNUC3Pr.L~:PS A~ASxA. INC 'o6.C~% Nr :'UF~II. ~1PS ALA a, iNC. 56: JRnIi.N .2.:J'/, gM1nOp,~K PrTR:JLrU1~$ CCKPp4A? J 1GN 22.00 tiL D364472 h . 5l,.C.Z i~U fi.•>h: L:aS ALA K4, :NC 540C% A ''t6~A70 AVA^.ARK^ F rC, SS.S2% ~__ `•• 16 Aga/Arrc °D~ 03H J f? 59 Aa:'Acre :2.50 :: R;;yatty DL 0390:68 PH:LL:PS Al ^RAI:'1W 2200' Is32.E:2 ~In~r•e 00 /, Net $rofit ~ 36.56 31d14crr. CChOC;7PhIL 1G'_7 % -oyjlty r,c... y'•3U `. ~.OC % Ne: ProF~t ,,;~~ .',,,, 667 % Royalty _ ~ { ~ 00 % Nei ProFit ~R[ r_~•_ ~r.62 ~\ rIL1R "iPF Q~ t5 (~~Inf'D~ GdBF..`cH ADr 0354x7 ti ~,Q !Acre -''S.67lXBr / ~; AL-4C Hi,YP. L. C. 0.38% 1 +~ . ti0.69 Hld/Acre ~° G~9C:12 ynlty ,`„ ~~Y Y VA ARKU o4C,Fl.M ,C!lk Rn1"?N 2200% 1?SO '!. Royalty l ,.~.~'• • ~ 2x3 Hlo/A. PrCFI NF 0 e '~crf'!• l l-:PS A~ IVC Al ASKA, _C '.'2:0% 30,60 % Nci orCS;t ~" xf% j 1 ::iIhJC'?nh:' I :oS ALASKA, 5° r •,'r ra'"-"' t,! % ko a ; ~ ~, :Nt: 6' /, Fxoi RAJ ct ~ C~ % Net YP --~~~ ~ i p 08/3:!0' JG n4 '! l r ~I nSM11 :NC. 4 0 / - _ "~ ^NL=11; rlI L'$ t.l ASKA. iNC. 56 ^pY ~C"A{L je{7~, 1?5 °! ASKA. [VC. ,6 '0% -r-- Ak( l:C ~L~ C:!R•'JRAI[' N 'i?..0% _ I : fIhJC Ph !t '1' S NC 56.00% LL:PS N t 4h Ttn4K F' TRJLEJM CCRPGRA'IL;N ^ O'p:4h I'F- ~ S ALA KA, 1 1~..ASKA l L a''.Od, ^ Il_' 1••S of r':NE ALASKA, !.L" ?2.GCY. ~ a{ r;.+ • A TR ILi:JM CGRP[iRA ILrS 2<. 0:,%~ ANAiARKG f>E'RGLLUM C7RPORATION 22.0 ~ i.pND"lFi 1='. >i ~- ~ ~ Li'.Ni" ALASKA, LL% 22.00% NMLLIPS ALr'!h'E ALASKA. L:C 22.00% 2 0% ~ AO D'fi10 ' ' n[GLIG io r feA. < 8 y A: re 16,6 % R~•• ;ty -~~ .i i_~_r ~ O.CO % Nei rcflr„ =.~:+1„ <C~• I"1 • '2.00'/. Exp N ; 5 1 _ . .' _ ~' fie,. Atx~:r J-r4 1 , ~J 1 Fif'RO _._ tv I t ~ ~ ,, < Pit. _- . - ~ n _1-~ - -+j ,~ 4NADA?KI_ PFik_IF,:M Cf[K~C4A':~h 2:Or.'r, t>-!I; 1PS A_P:'JI. 4l nSR4, _L~ 2_ OC% C[.VG"~II'•+II _ 1PS ALASKA, IhC. 56.:;D% A^;. 037y>IC' 6170.46 B.d/Acre DL 03!2104 I ADL C372:03 176.68 P.ld/Acre s6CP~ Ala/Acre 'tt ,2.~C % RCynl:y :2.50 % R::yn.ty 0.0.. 'r. Net pr~Flt C^.0 % ,.\et ~rpF;t 1?SL % Royalty a r fir. a xp 1.2U a• ~ -Bl 0.C0 % Ne: -rutlt -- ~ I Cxp hBU 1.00% NADA~KC Pr R'' LJM CRPDRATTf]h 2007. ° - - - - - - - ~ _ IIN 22 mil 1PS A P VL AI nSKA NAJA~KL Pr k=: F .M 'Okt'C4A GM1 ~2 00 'UNJF r F I :°S AL°SRA.:NC 55.00% -: - ~ - 2.DOX CLVR JP-?I 7PS A_4StA. Ihl'~ E COC • (I -+0 1PS A P.VL 41 nSKA, ^ r M C7N000PNL~LIaS 4LASK4 :NC 5600'1. LC ? OCi ~AVA;;4R<,J °F'RU~.I. C:7k.'JRAl1~N 22,OD% ANADARKG PLIRCLLl1M CCRP_.RA'ICV 22.C0' '1N LAS L a; Op,; fI.VO.- II'-II !PS ALASKA, Ih... _$.;, `% NH;I 1 :NS AL~Ih' ALASKA. 1.wC ?2.00% ri T E.:M CG' 'L'?A':OM1 2c ocx IfPH• LIoS ALPINE ALASKA. LAC ?2.C2% P nLASF?n, VC. Si, 00% A::. _0:':52: I ! `f3.87 Hldl4crr• _ _ XAA ^N4!4 ~ 0.0:?-% het nro~It ~1-~-ILLik I _xF I;HU r y.. ~,c:ci AVA=ARtU pl'RR. L.M ::UR°IIk4T:.JJN a,~,py --_-._. 'I ,,e rOko _ DDX Pr?I__!PS A.PiNF nLASKn C 22I'f07, I ~_.-.- - :Uf,'1f:_Ph:LL:PS A~ASt4, !N~ L•t•.A: •. - '- /2• ~T ' ~~ • • SHARON K. ALLSUP-DRAKE 11.23. CONOCOPHILLfPS AT0 1530 ~ E~?~fi'~ jZ se!lssi/aa1 700 G ST. DATE ANCHORAGE AK 99501 j~ Q PAY TO THE ? ~/~v~ ~L~~*~/~~ / 4`~~'~~~ $ /f~(1~' ORDER OF ,. `~ d &~ ~ `ijDOLLARS 8 a =,~ ,_~ JPMOrganCha5e1 ~ ValidltpTo5000Dollars JPMorgan Chase Bank, N.A. ~ o ° ' j ~ e j Columbus; OH f MEMO ~:044LL55LL~:528747L907927-i'LL23 /! a • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME C~2~. ~~-3 ~~~~ PTD# Z~ S ,/ cj~'C-~~-CC ~t~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI (The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of .the original API number stated are between 60-69) ,above. PILOT HOLE In accordance with 20 AAC 25.005(f}, all (per I, records, data and logs acquired for the pilot j hole must be clearly differentiated in both name (name on permit plus PIT) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACIlVG ~ The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. i (Company Name) assumes the liability of any protest to the spacing j exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE i Commission must be in no greater than 30' ~ sample intervals from below the permafrost or from where samples are first caught and j 10' sample intervals through target zones. Rev: 04/01!05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool COLVILLE RIVER, FIORD UNDFOlL-120120 __Well Name: COLVILLE RIV UNIT CD3~110 Program SER Well bore seg ^ PTD#:2050410 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType SER! 1WINJ GeoArea 890 Unit 50360 OnlOff Shore On Annular Disposal ^ Administration 1 Permit_fee attached_ _ - - - - . -- Yes - 2 Lease number appropriate_ - - - Yes Surface location in ADL 372105, well passes through.ADL-372104, top prod interval in ADL 364471,_ - - - - - - - - 3 Uni-quewell_nameandnumber___________________________- _.___-_-Yes__ ___--TD in ADL 364470.____--__-___-_,_--_ 4 Well located in-a_definedpool_ - - - , - . , - No_ Well located-in Fiord,Undefned oil_ ool, p - ~ - 5 Well located p[oper distance_ from drilling unit_boundary- - - - - - - - - - - - - - - - - - - Yes Statewide spacing rules apply. Well is more than_500' from-property boundary.wher-e-ownership 9r_landownership_ 6 Well locatedproperdistancefromotherwells_____________________ _________Yes_- -__-.changes.-.----_-_---_-----.- 7 Sufficient acreage available in_drilling unit_ _ - - - - - - - - - - - - - Yes - - --------------------------------------------------------------------- 8 If deviated,is_wellboreplat_included_______________________ Yes__ _________ - - - - 9 Operator only affected party- - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - . - _ - _ - _ - - - - _ _ _ _ -Yes - _ _ _ _ _ Well lies entirely within the Colville_ River Unit _ _ ----------------------------------- 10 Operatorhas.approPria#e-bond infQrce- ~ ------------- ----- -- - Yes-- ----- -- - - -- -- - __-... -- - - -- ----- - 11 Pe[mit_canbeisSuedwithoutconservationorder-------- --- ------ ---------Yes-- ------__-_-_-__-___.______-___--_____________ --------------------------- Appr Date 12 Pe[mitcanbeissuedwithoutadminist[ative-approval_____ ___ ______ _________Yes__ __._--__-----_____--_--__---_----_-------_--__ SFD 12!14!2005 13 Can permit be approved before 15~1ay wait Yes 14 Nlell located within area and strata authorized by Injection Order # (put_lO# in_comments).(For- No- . _ - - . - -Injection o[ Area Injection Order must be_approved prior to initiation of injection operations. 15 All wells within114_mileareaofreyiewident[Pied(Forservieewellonly)______ _________Yes__ __-__None.--___.____-..--__-___-....,.........____..-..-.-._-_.-._,.._-- 16 Pre-produced injector; duration.of pre production less than 3 months_ (For_service well_ only) No- , . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ AC_M_P_Finding of Consistency_has been issued_for_this project . .... . . . . . . . . . . . . . . . N_A- - - - - Engineering 18 Conductarst[ing_provided.--_________________________.- _-.------Yes-- _- -__._ ---------------------------------------------------------------- ` t 19 Surface casingprotects all-known USDWs _ . - - - - NA_ - _ _ _ - - - Np fresh water has been identified-in CRtI._ Casing.depth similar-as Alpine. 20 CMT_vol_adequate_tocirculate_onconductor&surf_csg_______________ __ ______Yes__ __.______-___--____--_-._-_._. - -- - .. 21 CMT_voladequate_totie-in long string to surfcsg___________________ _________ Na_,- __-_-Annulardisposalmaybeproposed.__-. _---_--.__-__.-_-__---__--_-___-__--_---- 22 CMT-willcoverallknow_nproductivehorizons______________________ _________ No___ _____Open_hol_ecompletionplanned,____________.___.__-_._,__..--_,---___-___,., 23 Casing designs adequatefo[C,T,B&_permafrost---------------- ---------Yes-- ---------------------------------------------------------------- 24 Adequate tankage-or reserve pit - - - - - - - - - - - - - - - - - - -Yes Rig is_equipped with steel_pits. No reserue_pitplanned, All waste to approved annulus or disposal well., - , , - - - 25 Ifa_re-drill,has_a1.0-403forabandonmentheen approved_____________ ___ _____ NA_._ _____________-_____,__.--__- 26 Adequafewellboreseparation-proposed________________________ _________Yes__ _.___Proximityanalysisperfom?ed;Onty1other well-in area.-_--_____-________-_._____._--_____ 27 If diverterrequired,doesitmeet_regulations-_--_.__- ___________ _______Yes__ .___,__-__---_____-_..- -,__, _ Appr Date ~ 28 Drilling fluid_ program schematic & equip list adequate- _ - . _ - - Yes - - - Maximum expected formati9n pressure 8.7 EMW.- Planned-MW up to 9.3 in pay zone. _ _ - - - - - - _ _ TEM 1211412005 29 BOPEs,_dotheymeetregulation._____-_____ Yes_- -__----_-------------------------------------------------- ------ 30 BOPE.press rating appropriate; test to.(put prig in comments)- - - - - - - - - - - - - - Yes - - MASP calculated at 2456 psi. 3500_psi_appr_opriate. CPAI normalty tests-to 5000.psi: - - _ . - _ - _ _ _ - - - - - - 31 Choke.manifold complieswlAPI_RP-53 (fulay84)_ _ _ _ _ _ _ . _ _ - - _ - _ - _ - - . - _ - - -Yes _ - - - _ - - . _ 32 Work will occur without operation shutdown_ No_ _ . - - _ - - Operations wil_I SD aftersetting7" due to end of season._ Rig will_retur_n inearl 2006._ y 33 Is presence_ of H2S gas probable- - - - - No- _ - - _ _ - . H2S was-not reported in.theexploration-wells.- Ri has sensors and alarms. - 9 1 34 Mechanical condition of wells within AOR verified jFgrservice well only) - - - - - - - - - -- - - -Yes No wells within AOR, No chap es_due to len th extension. _TE_M-12.11.4!2005. , 9 9- Geology 35 PeCmit can be issued w/o hydrogen_ sulfide measures - Yes - - . - - - H2S and-gas detectors will be utilged du[ing_drilling. _Shallow_h_azards mitigation measures - - - 36 Data_presented on_ pote_ntial overpressure zones- - - - Yes discussed in. Drillin Hazards summa 9- ry --- .. , Appr Date 37 Seismic analysis of shallow gas_zones_ NA_ - - - - - - No overpressured zones anticipated based_ on_offset d[illing_(Fiord exploratory wells). SFD 12/14/2005 38 Seabed condition survey_(if off-shore) . NA _ 39 Contact name/phone for weekly_progress reports [exploratory only] NA_ - -- - - Geologic Engineering Public Date: Date Date Re-issue of existin ermit to drill caused b bottom hole location chan a exceedin 500 feet. Drillin be an on this well last 9 p y 9 9 9 9 Commissioner: Commissioner: Commissioner / 1 j ~ k~¢~ DTS I Z/ l ~~~ ~~~~ JKN year, intermediate casing point was reached, and the well was suspended after cementing intermediate casing. This new target TD is approximately 2,200' further NW than the originally permitted TD. SFD ~~ j • STATE OF ALASKA 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submitto:~-reg~g~adr~:in.stUte.ak.~~s acgc^ prR.E~l~oe bt:v~ad:~tn.s~tate.ak.us 1301 ~ eckenstein :~3adn^in.stato.alt.i~s Contractor: Doyon Rig No.: 19 DATE: 4/15/2005 Rig Rep.: Krupa/Lupton Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Burley/Hill Field/Unit & Well No.: Colville Rv CD3-110 PTD # 2fl5-tl41 Operation: Drlg: X Workover: Explor.: Test: Initial: x Weekly: Bi-Weekly Test Pressure: Rams: 250/5000 Annular: 250/3500 Valves: 250/5000 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test R Location Gen.: P Well Sign P -Upper Kelly 1 P Housekeeping: P Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size Test Result Annular Preventer 1 13-5/8 P Pipe Rams 1 3-1/2x 6 FP Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke"Ln: Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1/8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results CHOKE MANIFOLD: Quantity Test Resu No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Resu System Pressure ..3000 P Pressure After Closure 1600 P 200 psi Attained 27 sec P Full Pressure Attained 2 min 52 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 @2325 Number of Failures: 2 Test Time: 9 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: aim reg~~~3adr~:i:~.state.ak.ur Remarks: Top rams failed in the middle of the test. Test plug failed. Both were changed and retested OK. Changed top set from variables to 4" solid bodies. 24 HOUR NOTICE GIVEN YES X NO Date 04/13/05 est start Time 7:OOam Finish Waived By Witness Not Waived Lou Gramaldi BOP Test (for rigs) BFL 11/09/04 Doyon19 04-15-05 CD3-110.x1s STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Submit to: torn_rr3,sndcrr?a~n~in.st.~ ^.~ic.;:v ai;;;c.--• Y:,:Ih~;a_-#~;~i`c;,adn~ir.sta.p.:~k.::s E;c:~i7.•_~E:;;kf;n:><tln{!,v:~~r3: ;s;~l ak..<: Date: 12-Apr-05 Operation: Development x Exploratory: Drlg Contractor: Doyon Rig No. 19 PTD # 2U5-041 Rig Ph. # 670-4300 Operator: Conoco Phillips Aiaska Inc. Oper. Rep.: Burley /Mickey Field/Unit & Well No.: CD3-110 Rig Rep.: Welsh / Lupton Location: Sec. 5 T. T12N R. R5E Merdian UM ,,, , ,, , , ~' 57 t . ~ 13~..A ........ . ....... MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: OK Well Sign: P Systems Pressure: 3000 psig Housekeeping: P (Gen.) Drlg. Rig: P Pressure After Closure: 1650 psig Reserve Pit: N/A Flare Pit: N/A 200 psi Attained After Closure: min 29 sec. Systems Pressure Attained: 2 mim 43 sec. DNERTER SYSTEM INSPECTION: Nitrogen Bottles: 4 2300 si avers e Diverter Size: 20 in. psig Divert VaNe(s) Full Opening: YES VaNe(s) Auto & Simultaneous: YES MUD SYSTEM INSPECTION: Light Alarm Vent Line(s) Size: 16 in. Trip Tank: P P Vent Line(s) Length: 85 ft. Mud Pits: P P Line(s) Bifurcated: N/A Flow Monitor: P P Line(s) Down Wind: YES Line(s) Anchored: YES GAS DETECTORS: Light Alarm Turns Targeted /Long Radius: N/A Methane ~ P Hydrogen Sulfide: P' P :: ..... :::::::::::::::::.:::::...::: ~.~F~FtT~~t..S~H.E~AT~G .......................... . RIG 19 SUB Div. Vent line Non Compliance Items 0 Repair Items Withir N/A Day (s) And contact the Inspector @ 659-3607 Remarks: Test went ood AoGCC REP.: Witnessing waived by Chuck Scheve OPERATOR REP.: Burley/ Mickey Diverter Test (for rigs) BFL 11/20/00 Diverter Test CD3-110 Doyon 19, 4-12-05.x1s ~, 3 # ~ ~ ( ~ ' di/Aa7~ O~ tuSD V[0-7 CO1~T5ERQATIO~T COl-II~II851014 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River CD3-110 ConocoPhillips Alaska, Inc. Permit No: 205-041 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7`" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Surface Location: 3941' FNL, 855' FEL, SEC. 5, T12N, RSE, UM Bottomhole Location: 3600' FNL, 2342 FEL, SEC. 30, T13N, RSE, UM Dear Mr.Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure tU cu;>~;<~piy with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to ess any required test. Contact the Commission's petroleum field inspector at (907) 659-3~ger). Chairman DATED this2 day of March, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA C ~l ALASKA OIL AND GAS CONSERVATION COMMISSION~IL.,~~~~ PERMIT TO DRILL MAC ~ ~ ?005 20 AAC 25.005 1a. Type of Work: Drill ~ Redrill Re-entry ^ 1b. Current Well Class: Exploratory Q " l+~fy3, {-„~f~~j>~~~one ^ Stratigraphic Test ^ Service ^/ Development Single Zone Q 2. Operator Name: Conoc~Phillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well ame and Number: CD3-110 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 17021' TVD: 6859' ~ 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): Surface: 3941' FNL, 855' FEL, Sec. 5, T12N, R5E, UM r 7. Property Designation: r ADL 372105, 372104, 364471. 364470 Fiord Top of Productive Horizon: 5277' FNL 3763 FEL, Sec. 32 T13N, R5E, UM 8. Land Use Permit: LAS21122 13. Approximate Spud Date: 4/14/2005 Total Depth: 3600' FNL 2342 FEL, Sec. 30 T13N, R5E, UM ~ 9. Acres in Property: 2560 14. Distance to „, ,~~~~' /'.,.~„~,~ ~JZG Nearest Property: ..348-FYI ° s.~ rr~ vs~ .z 4b. Location of Well (State Base Plane Coordinates): Surface: x- 388188 y- 6003833 ~ Zone- 4 10. KB Elevation (Height above Gt.): 36.7 feet 15. Distance to Nearest j! Well within Pool: Fiord 5 , 5223ft 16. Deviated wells: Kickoff depth: 300 ~ ft. Maximum Hole Angle: 91 ° 17. Anticipated Pressure (see 20 AAC 25.035) Max. Downhole Pressure: 3153 psig /Max. Surface Pressure: 2456 psig 18. Casing Program Setting Depth Quantity of Cement Size S ecifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Portland cement 12.25" 9.625" 36# J-55 BTC 2679' 37' 37' 2716' 2508' 459 sx AS Lite & 230 sx 15.8ppg 8.5" 7" 26# L-80 BTC-M 8482' 37' 37' 8519' ' 6970' 203 sx 15.8 ppg G 6.125" 4.5" 12.6# L-80 EUE-M 7830' 32' 32' 7862' 6804' `%-~y'~;ry.t~ J 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD ND Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): None Perforation Depth TVD (ft): None 20. Attachments: Filing Fee ^ BOP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^ 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact V. Johnson @ 265-6081 Printed Name C~Al~vo/r~d Titie Alpine Drilling Team Leader Signature /-'l!' ` Phone u"~ ~ ~Lo Date 3~ 1~,~°b~ G l Pr r V. John on Commission Use Only Permit to Drill Number: w -~ ~~ API Number` ~ ~ ,^~,[~7~,C~ 50- ~C_-L~;~ '~ G~.~,~CJ ! ' Permit Approval Date: ~a~~D S See cover letter for other requirements Conditions of approval : Samples required ^ Yes ~ No Mud log required Yes ~' No rogen sulfide measures ^ Yes ~' No Directional survey required Yes ^ No ~.~ ~~`~~~` 7~V~ ~1 ~4 4' £~ ~~~"t<5~~ ~`~ ~ L.~S.v'~1:_y\~ ~~~ \i~a.f~v ~ P~`F~C`~~~~invrcep~~~~l~. Other: ~ ` ;,~~~ ~Cc. CJ~~k.-'~t:.X. C,~ ~l G'~ '~ ~-~~ ~3 E.~ ~ t, v~ 5~.~ ~'~< <,C .. P P ~ BY ORDER OF App COMMISSIONER THE COMMISSION Date: For -401 Revised 6/2004. ~ ~ ~ ~ ~ A L Submit in duplicate oS Lv ConocoPhillips Alaska,. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 March 14, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ConocoPhilli s p R~G~e~! MAR ~ 7_G~O~ Re: Application for Permit to Drill CD3-110 Alaska Oil & Gas tc~~s. ~~~~missia~ Anchorage Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injector well from the Fiord CD3 drilling pad. The intended spud date for this well is 4/14/2005. It is intended that Doyon Rig 19 be used to drill the well. CD3-110 will be drilled to penetrate the Nechelik reservoir horizontally. After setting 7" intermediate casing, drilling operations will be temporarily shutdown, and the rig will be moved to another location (likely CD3-109) in order to get another penetration in the Nechilik while the ice road is available. Doyon 19 will return to drill the horizontal section when an ice road is available in early 2006. The well will be drilled and the well completed as an open hole injector. At the end of the work program, the well will be closed in awaiting completion of well work and facilities construction that will allow the well to begin injection fourth quarter 2006. It is also requested that the packer placement requirement be relaxed to place the completion packer 250 ft TVD above the Nechelik formation. This will place the completion at a maximum inclination less than 65° and allow access to the completion with standard wireline tools for future intervention. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1 ). 3. A proposed drilling program. 4. A proposed completion diagram. 5. A drilling fluids program summary. 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of diverter set up. • • If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. S,~,~'fely, f V'6~rf JOht~S~ Drilling Engineer Attachments cc: CD3-110 Well File /Sharon Allsup Drake Chip Alvord Vern Johnson Jack Walker Jordan W iess Lanston Chin ATO 1530 ATO 1700 ATO 1702 ATO 1740 ATO-1782 Kuukpik Corporation • • CD3-110 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casin Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) durin interval. Well Collision Low G ro sin le shots, travelin cinder dia rams Gas Hydrates Low ~ Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densit cement slurries 8-1/2" Hole / 7" Casin Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surtace Formations ~ Check for flow during connections and if needed, >2000' TVD increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-1/8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium ; BOPE drills, Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers r' .,' ~- ORIGINAL • Fiord: CD3-110 Procedure 1. Move on Doyon 19, dewater cellar as needed. 2. Nipple up and test diverter. 3. Drill 12-~/a" hole to the surface casing point as per the directional plan. 4. Run and cement 9-5/8" surface casing. 5. Install and test ROPE to 5000 psi. 6. Pressure test casing to 2500 psi. 7. Drill out 20' of new hole. Perform leak off test. 8. Pick up and run in hole with 8-1/2° drilling BHA. 9. Drill 8-~/2" hole to intermediate casing point in the Nechelik Sands. (LWD Program: GR/RES/DENS/POROSITY/PWD) 10. Run and cement 7" casing as per program. Chase cement with kill weight brine. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11. RIH with +/- 2000 ft 4-1/2" tubing as a freeze protect string. 12. Land tubing hanger, NU and test tree. 13. Displace tubing and annulus to diesel for freeze protection. 14. Test casing to 3500 psi for 30 min. 15. RD, install BPV. 16. RDMO C~~~c~.~~~o ~~ ~~ 17. Move in and rig up with Doyon 19 (Early 2006) 18. ~ `~ ~: ~~ z ~ ~ ~~~ l 19. Pull BPV. ~ "~ , 20. ND tree. ~~~ V ~°~°~°°' ~„ ~'._. 21. NU and test ROPE to 5000 psi. ~ ~ ~~-~`~ 22. Displace diesel freeze protection to brine. 23. Pull hanger and freeze protect string. 24. Run drilling assembly. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 25. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 16. Circulate the hole clean and pull out of hole. 17. Run 4-1/2, 12.6#, L-80 tubing with DB injection nipple, gas lift mandrel and packer. Land hanger. ORIGINAL • • 18. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20. Circulate tubing to diesel and install freeze protection in the annulus. 21. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 22. Set BPV and secure well. Move rig off. ORIGINAL LJ Well Proximity Risks: • Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. Fiord 5 will be the closest well.. Well separation is 5222' ~ 10875' MD. ,.~..,_......v~.--_-, Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Nechelik reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. 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 CD3-110 will be injected into the class 2 disposal `- well on CD1 pad. The CD3-110 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 1700' TVD. The only significant hydrocarbon zones are the Nechelik and Kuparuk reservoirs and there will be more than 500' of cement fill above the top of the Kuparuk as per regulations. Upon completion of CD3-110 form 10-403, Application for Sundry Operations -Annular Disposal,will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed. directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 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 ORIGINAL • • CD3-110 DRILLING FLUID PROGRAM SPUD to 9-5/8"surtace casing oint -12 '/a" Intermediate hole to 7" casing point - 8'/~" Production Hole Section - 6 1/8" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-9.3 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 API 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 - 1 0.0 9.0 - 9.5 KCL 6 Surtace Hole: A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Nechelik is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section The horizontal production interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with t 30PP6 calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. ORIGINAL • • Fiord (CD3) Colville River Field CD3-110 Injection Well Completion Plan 16" Conductor to 114' 4-1/2" Camco DB Nipple (3.812') at 2000' ND = 2149' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2716' MD / 2508' TVD cemented to surface 4-1/2" 12.6 ppf L-80 IBT M tubing run with Jet Lube Run'n'Seal pipe dope Com lep tion Updated 03/11/05 Sperry Sun Directional Plan WP02 Tubing Hanger 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DB nipple 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG2-GLM (3.909" ID) 4-1/2", 12.6#/ft, IBT-Mod Tubing (2) Baker Premier Packer 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) HES "XN" (3.725")-64.2° inc 4-1/2", 12.6#/ft, IBT-Mod 10' pup joint WEG Camco KBG-2 GLM (3.909" DRIFT ID) w/dummy Baker Premier Packer +/-7790' MD/ 6771' ND < 250' ND from top of Nechelik TOC @ +/- 7295' MD /6472' ND (500' MD above top Kuparuk C) Top Kuparuk C at 7795' MD / 6774' Top Nechelik at 8439' MD / 6934' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ 8519' / 6970' ND @+/- 87.1° ~ ~ 32' 32' 2149' 2000' 7700' 6725' 7790' 6771' 7850' 6799' 7862' 6804' Well TD at! 17021' MD ~ 6859' TVD ORIGINAL • • CD3-110 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MDlTVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 2716 / 2508 14.5 1135 1640 T' 8519 / 6970 16.0 3154 2457 N/A 17021 / 6859 16.0 3104 N/A NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1 ]D Where: ASP =Anticipated Surtace pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1]x 114=53 psi OR ASP =FPP - (0.1 x D) = 1135 - (0.1 x 2508') = 884 psi 2. Drillin g below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1 ] D _ [(14.5 x 0.052) - 0.1] x 2508 = 1640 psi OR ASP =FPP - (0.1 x D) = 3154 - (0.1 x 6970') = 2457 psi 3. Drillin g below intermediate casing (T') ASP =FPP - (0.1 x D) = 3104 - (0.1 x 6859') = 2418 psi ORIGINAL • • Cementing Program: 9 5/8" Surface Casing run to 2716' MD / 2508' TVD. Cement from 2716' NID to 2216' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2216' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1795' N1D). Lead slurry: (2216'-1293') X 0.3132 ft3/ft X 1.5 (50% excess) = 433.6 ft3 below permafrost 1293' X 0.3132 ft3/ft X 4 (300% excess) = 1619.9 ft3 above permafrost Total volume = 433.6 + 1619.9 = 2053.5 ft3 => 459 Sx @ 4.48 ft3/sk System: 459 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW' D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 8519' MD / 6970' TVD Cement from 8519' MD to +/- 7295' MD (50% more cement above the Nechelik as there is between the packer and the Nechelik) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (8519' - 7295') X 0.1268 ft3/ft X 1.4 (40% excess) = 217.3 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 217.3 + 17.2 = 234.5 ft3 => 203 Sx @ 1.16 ft3/sk System: 203 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk ' By Weight Of mix Water, all other additives are BWOCement ORIGINAL ~ _ CASNC" DETAI.S IJUgTNTIDNe ~•. ' ~ConocoPhilli s cor,oeovRln ~wk, lne NAD 67 ¢ Project: Colville River Unit TVD ~ Mmu6on C w 1 ~n~ ]6.100 16.100 SHL - ]94th FNL 8 85811 FEL SacST12NR5E 5l0oOt011MD,100otonrvD site: apnecD3 ~ ~~ ~'/$~ ~ ,~ 300.010]00.010 e.glnDo-t~a.00DL p ~,~~, Mk1Y1MIn ~,~• Error5lrsearn: 1561'9311 ~ 121].1012%.800 End Dir, Start Sall 28.696: 1256.600fi MD, 121 ].tOtk TVD Well; Plan: CD3-11U 2 M592 ffi19780 T 7 2508.000]28.288 AS/8' Csg Vt _. Drill out 8112' Hdc : 2]16.041fl MD, 2508.000h rvD t2lh TVD 1~ten FiDle 6-V8 5989 OOi696 800 es in Dlr(d 4 00 OL5: 6696 BOOh MD S%9 _ = Scan McYro~ Tnv 61'rRltlarNMN Error Surfaxw: Elliptlral Genie . . g 5 . . , . WellbOfe: Plan: CD3-110 6969.591518.800 Target (]- 6L`` 9 PI) GeoSteer, 8818.800R MD, 6%9.801R rvD, (BZ]M FNL, TI63R FED Bfi20h MD, 6984.6h rvD, 6984.601819.]60 Tar99~e (DSepp Pl) GeoSteer _ Wamkrg klserOQ Rules eaee4 1°3 , 6856.604019 600 TD l9Hll~1]019.600 fi MD. 6859.604 h TVD; 360011 FNL 8 2302fi FEL, Sec10-T13NR8 e HALLIBURTON _ _- __ _ eM.preBC M: Plan: CD3-110 (wp02) Sperry Ddiling Services € SURFACE DETAILS. Plan CD3-110 SECTION DETALS '= c~..ra en aril ~erN. or.: Ground Level: 0.000 Sec MD ktc AIi TVD +NIS +EI-W DLep TFa® VSec Target = Northing/ASP Y: 6003580.9618 1 OOfID QOOD 00000 OD(10 OL00 09(10 0.00 OOIgO 0.000 EastinglASP X: 1528220.2769 2 300.000 GOOD 00000 300000 0000 ODIp 0.00 ODODD 0000 is 3 12569'6 29699 23,3636 1217.126 215379 93000 3.00 233636 168A57 = H l 61/8" O a 6®fi975 28.699 23x636 saes i57 2613661 1129D59 Om om9o 2039398 pen e o s ~i9936 87.139 3349691 eswsOD 3941.681 72297 ao9 stoo4a 3426933 cm-1locagPt s 6 8542817 0918M1 324.8461 @770.99'1 3961176 708$74 400.17&7961 3450D39 Plan: CD3-1 0 (wp02)N0.0 7 8792D89 89184 3249461 f891.!B2 4091109 61737.1 0.00 0.0000 3604055 - = 8 8819535 90980 3249448 984900 4181134 548974 400 12D48 3717935 CDittO Deep vt 413 CDJ-t,oTce 8 4 9944 0 00 00000 11Bfi8 9 17020.547 90880 3249408 6ffi8600 109019 4 15 . . FoamATtaN rov DEra~s = no tVGV.dh MDPath Forrna8on TD (BHL)-17019.600 ft MD, 6858.604 ft ND; 3600ft FNL 8 2342ft FEL, Sec30-T13N-R5E , ,zae.coo ,z92s„ Base Partrta6ost z z3396oo zs15163 cro = 3 2s,969D r7493rz coo 4 299&970 317191 0,20 = 5 3915600 4333020 K-3 'il 6 5762600 6439690 Abian 97 7 9'73.600 6679240 Ahian 96 6 9521600 7369144 Tap HRZ _ 9 6644600 7557.316 Sass HRZ __.__._.._.__. _-_.... _. -._.~_ 10 6689600 7629.111 K-1 = ' 11 6729600 7709175 Top Kuparuk D ~ , 12 6711600 7795478 Top Kuparuk C ~•~ = 13 6779600 7805949 LCU p 14 6861600 8008.931 Base Nuigsut 15 6963600 8439.006 Top Nechalik = r0 i6 Base Nechel4c Target (Deep Pt) GeoSteer, 8820ft MD, 6984.6ft ND, r _ _ o - __ _ - -: - = ? i Target (7" Csg Pt) GeoSteer, 8518.800ft MD, 6969.601ft TVD, (5277ft FNL, 2763ft FEL, Sec32-T13Na25E I-"" c t , N Begin Dir @ 4.00 DLS: 6696.800ft MD,5989.123ft ND = - -- 95/8" Csg Pt ... Drill out 8-1/2" Hole : 2716.041ft MD, 2508.000ft ND _____ ___ r End Dir, Start Sail @ 28.696: 1256.600ft MD, 1217.101ft ND ~ ~ ~ Begin Dir @ 4.00 DLS: 300.010ft MD,300.010ft ND ------- g -~- SHL --3941ft FNL & 855ft FEL, Secs-T12N-R5E _ E ~ "~ 0 2~ `.IbO 7~ 1~ 12~D 1J~ West(-)IEast(+) (2500 ftfin) HALLIBURTON Sperry Drilling Services o.w.e M aril name De: O _ [/.w V / z C _ ~ ~'~ __ O N ' c ~ - _ O ~++ = ~C € m ;• > ~~ _~ - H Base Permafrost CEO 030 C-20 K-3 Corr°mPRlllips AWka Inc. NAD tl Calodstlm MetloA: MlMrrean Cwahaa Ertar Syabm: ISCWSA Son Ma4nd: Tm. Cylbgx NaM Ea°r Surface: EllipBeal Danic Wamip McOrod: Rube Based Ga°deac DaNm: NorM American DaWm 7917 Magretic Model: aG[a6a99d Project: Colville River Unk site: opine CD3 Well: Plan: CD3-110 Wellbore: Plan: CD3.110 Plan: CD3-110 (wp02) ANNOTATIONS CAgMG OEfAIS Tw 6o Mrab9m ]6.100 ]6.100 SNL-19d1tt FNL6855h FEL, SeciT1INR5E T71D MD Name $~ JOO.OtOl00.010 Begin Dir~0.00 DL5: 300.0108 MD,300.OtOR TVD ~~ 2728258 995' g~B 121].101256.600 End Dir, Stan Sall ~ 18.696: 1266.60mt MO, 121 ].tO1R TVp ~,~ ~g~g 7~ ~ ISOfi.000)28.288 g-LB-CSg M... Orlll out 8-112-NOle:2]16.Od1R MD, 2508.0008 TVD 6858581 1g619~7xI F1D19 6•L8 6969.991i696.69a Begin Dir ~ 0.00 DLS: 6696.800h MD,5989.12]8 TVD 6969.591518.800 Target )-Csg PII Geo Steer,8518.600R MD. 6969.fi01R TVD, (52]M FNl.2]WR FEL,! 6980.60)819.360 TargetDeep Pt) eo9teer, 8820h MD, 696d.fiR TVp, 6858.600019.600 TD (RNLI-1]019.600 R MD, 6858.604 R TVD; ]6008 FNL d 2]428 FEL, Sec30-T17NitSE SURFACE DETAILS: Plan: CD3-110 ~T^~ Ground Level: 0.000 Sec ~ 14tD Ad TVD H47S +EI-W CN.eg TFace VSec Tetget NoNlinglASP Y: 6003580.9618 1 OAOD 0000 0.0000 0000 0.000 0000 0.00 00000 0000 EastingiASP K: 15282202769 2 300.ODD 0'000 0'0000 300000 0'000 0'000 QAO O'000D Q000 3 1256529 29,699 233636 1217.126 215319 9:1.040 300 233636 166.06/ 4 6686975 ffi688 233636 X157 2613661 1129f199 000 00000 81C93~ 5 8518936 67.139 3245863 6884600 39Gi~1 T12.aB7 400 430044 342G.4i3 CD3110 CagR 6 8502817 861&4 3248461 fi570.991 3961176 708574 400-178.7961 365DR6 7 8702088 86194 3448061 6961.2 4093109 617373 000 00000 3601OS CD3-110 Deep Pt 8 8819.535 90980 324.9446 6884600 6169.134 549$74 4,OD 12fM8 31'17535 CD3-110 Tae SH L - 3941 ft F N I K R 5 5ff F F I S r~ 5- 717 9 17028547 90860 3249448 6858800 10801.684 4159.944 000 00000 11666413 Begin Dir @ 4.00 DLS: 300.010ft MD,300.010ft ND FORMATION TOP DEfAO.S End Dir, Start Sail @ 28.696: 1256.6008 MD, 1217.101ft ND 95/8" Csg Pt ... Drill out 8-1/2" Hole : 2716.0418 MD, 2508.0008 ND No. TVDPath MDPath Formation 1 1246600 1292511 Base Perrrehod 2 z33e.6oo 2535163 Coo 3 zsls.fioo 274037z coo a za9e.6DO 3173.591 caD 5 3915600 4311020 K-3 6 5762600 6438800 A6ia197 7 5973.600 6679240 A6ia196 a 6523800 7389.144 Top HRZ 9 66446W 7557316 Base NRZ 10 6686.600 7Q9..'i31 K-1 17 6728.600 7706.175 Top Kuparuk D 12 6773600 7795478 Top Kuparuk C 13 6778600 7805948 LCU td 6863600 8008.931 Base Nuiqsul 75 6BG3600 8439.006 Top NectlL4ik i6 Etase NerlbBc Albion 97 Albion 96 Top HRZ Begin Dir @ 4.00 DLS: 6696.8008 MD,5989.123ft ND Base HRZ - -- - _ K-1 Top Kuparuk D Plan: CD3-110/Plan: CD3-110 (wp02)N0.0 Top Kuparuk C LCU Base Nuiqsut To Nechelik Target (Deep Pt) GeoSteer, 8820ft MD, 6984.68 ND, p I I 61/8" Open Hole Target (7" Csg Pt) GeoSteer, 8518.800ft MD, 6969.6018 ND, (52778 FNL, 2763ft FEL, Sec32-T13N425E TD (BHL)-17019.600 ft MD, 6858.604 8 ND; 3600ft FNL & 2342ft FEL, Sec30-T13N ~ooo ,zooo 0 2000 4aoo sooo 6006 ~aooo 12oao Vertical Section at 339.11° (2000 8!n) • • Conoco`Phillips ConocoPhillips Alaska Inc. NAD 83 Colville River Unit Alpine CD3 Plan: CD3-110 Plan: CD3-110 Plan: CD3-110 (wp02) Travelling Cylinder Report 21 February, 2005 Sperry-sun DRLLiNG SERVICES ~ r~a~,~~xu~r ~~ ORIGINAL ~' 1"~C1C11~1 Company:. ConocoPhiilips Alaska Inc. NAD 83 Project: Colville River Unit Reference Site: Alpine CD3 Site Error: O.000ft Reference Well: Plan: CD3-110 Well Error: O.000ft Reference Wellbore Plan: CD3-110 Reference Design: Plan: CD3-110 (wp02) Sperry-Sun HES Anticollisian Report Local. Co-ordinate Referenced TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: • r~r~y-gun QPlIt_t_IIVG S NtVICS?i A FIAL1.19lIRl(YV GOP1Na ~' W ell Plan: CD3-110 - Siot 10 RKB ~ 48.600ft (RKB 48.6 ft above MSL) RKB ~ 48.600ft (RKB 48.6 ft above MSL) True Minimum Curvature 1.OO sigma EDM 2003.11 Single User Db :.Offset Datum Reference Plan: CD3-110 (wp02) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 100.OOOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,898.356ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tooi Program Date 2/9/2005 From To Off) (ff) ' Survey (Welibore) Tool Name Description 36.100 300.000 Plan: CD3-110 (wp02) (Plan: CD3-110) CB-GYRO-SS Camera based gyro single shot 800.000 17,019.665 Plan: CD3-110 (wp02) (Plan: CD3-110) MW D MW D -Standard Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Weii - Wellbore -Design (ft) (ft) (ft) (ft) Alpine CD3 Plan: CD3-106 -Plan CD3-106 -Plan: CD3-106 (wp 200.000 200.000 80.008 4.10 75.913 Pass -Major Risk Plan: CD3-107 -Plan: CD3-107 -Plan: CD3-107 ( 200.000 200.000 60.006 4.10 55.911 Pass -Major Risk Plan: CD3-108 -CD3-108 -Plan: CD3-108 (wp06) 502.503 499.998 42.290 9.38 32.908 Pass -Major Risk Plan: CD3-109 -Plan: CD3-109 -Plan: CD3-109 ( 500.534 500.000 15.997 9.35 6.646 Pass -Major Risk Plan: CD3-111 -Plan: CD3-111 -Plan: CD3-111 ( 399.279 399.998 21.674 7.45 14.225 Pass -Major Risk Plan: CD3-112 -Plan: CD3-112 -Plan: CD3-112 ( 398.659 399.998 41.618 7.44 34.179 Pass -Major Risk Plan: CD3-113 -Plan: CD3-113 -Plan: CD3-113 ( 398.047 399.998 61.603 7.43 54.174 Pass -Major Risk Plan: CD3-114 -Plan: CD3-114 -Plan: CD3-114 ( 397.442 399.998 81.577 7.42 74.158 Pass -Major Risk Plan: CD3-115 -Plan: CD3-115 -Plan: CD3-115 ( 396.847 400.000 101.562 7.41 94.152 Pass -Major Risk Plan: CD3-116 -Plan: CD3-116 -Plan: CD3-116 ( 200.000 200.000 120.010 3.71 116.304 Pass -Major Risk Plan: CD3-117 -Plan: CD3-117 -Plan: CD3-117 ( 200.000 200.000 140.021 3.71 136.316 Pass -Major Risk Plan: CD3-301 -Plan: CD3-301 -Plan: CD3-301 ( 1,443.719 1,399.994 94.779 27.16 67.623 Pass -Major Risk Plan: CD3-302 -Plan: CD3-302 -Plan: CD3-302 ( 916.141 899.996 137.609 19.13 118.478 Pass -Major Risk Plan: CD3-303 -Plan: CD3-303 -Plan: CD3-303 ( 200.000 200.000 140.014 4.10 135.919 Pass -Major Risk Plan: CD3-304 -Plan: CD3-304 -Plan: CD3-304 ( 403.816 399.998 120.660 8.50 112.164 Pass -Major Risk Plan: CD3-305 -Plan: CD3-305 -Plan: CD3-305 ( 236.097 199.999 100.252 4.77 95.479 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 2/21/2005 7:12:30PM Page 2 of 25 COMPASS 2003.11 Build 48 ORIGINAL WELL DETAILS: Plan: CD3-110 +WS +FJ-W Northing Fasting Letittude Longitude 0,000 0.000 6003580.957 1528220.251 70"25'8.7d9N 150°54'S0.535W ~ ConocoPhillips Alaska Inc. ~ Engineering Calculation Method: Minimum Curvature Ercor System: ISCW SA Scan Method: Trav. Cylinder North E rcor Surface: Elliptical Conic blaming Method: Rules Based ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 25 Ft Stations Reference: Plan: C03-110 (wp02) Depth Range From: 36.100 To 17019.665 Maximum Range: 1898.36 0 r--- From Cobur To MD 36 300 500 600 750 1000 1250 1500 1750 _- 2000 2500 3000 - 4000 6000 6000 7000 8000 0 • 90 ~~ D, ~~-~r.n~,~l-~ \a) Irc "ILII ~V~ti ~4%-\1' nleA 'll~m~ \~ea~ T~vAei _ _ 0.000 O.OgI 0.UIp U.000 0X.000 1)S4V1 LY !.L-MM1 1 SIS.Lb v.t~t~ 0.000 AOn N.v6)0] LA L.„µp < !b I.A3!! Ilw.n.Tl O.On 04 i' NI 1WLn'1v2 A6 .wi .nb2~ ]OAA29 4 141 j nv 4M6 I lltl la ('rO IY 40n .1]4X0 ,WV.)4t I x]OI.Aw xn. AlI~ ~ Mw2,.2 61 ]_b0 400 ~ .16aL]I] .CIE 1161141><.yA v 1)nlv.M w.AW~ t24W! µMnnn IPAx~.].. -JI.M_ME 400 Oro IIMl.1a1 IIAiIIOTu CD3-110 (wp-02) Approved Pla~z $URVE7' PROGRAM Dntr 2005-02-21 T00:00:00 Vnfideled' Yea Version: Depth Fmnr Drp01 To 5urvry/Plwr Taxil ?6.1(10 500.000 Plan: CD?-I IO fw1r021 C&G YRO-$S 300.000 I70 9. S Irvn Di-110 w M1iN'D • • ConocoPhillips ConocoPhillips Alaska Inc. NAD 27 Colville River Unit Alpine CD3 Plan: CD3-110 -Slot 10 Plan: CD3-110 Plan: CD3-110 (wp02) Standard Planning Report 01 March, 2005 HALl.~1~3URTQN ~rili~~g '~erv~c+~~ yi Databasez EDM 2003.11 Single User Db Company: `ConocoPhillips Alaska Inc. (Alpine) Project: Colville River Unit Site: Alpine CD3 Weil; Plan: CD3-110 Wellbore: Plan: CD3.110 Design: CD3-110 (wp02) Halliburton Company HALL.IBURTON Planning Report ,. __ _ ._ _ r ._..._._____ ~_...__~~. ~~~ sa~rvf+ces Local Coordinate Reference: Well Plan: CD3-110 -Slot 10 TVD` Reference: Doyon 19 Q 48.600ft (RKB 48.6 ft above MSL) MD Reference: Doyon 19 Q 48.600ft (RKB 48.6 ft above MSL) North<Reference: True Survey Calculation Metiwd: Minimum Curvature Project Colville River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Alpine CD3 Site Position: Northing: 6,003,886.7790 f} Latitude: 70° 25' 10.480" N From: MaP Easting: 388,488.0891 ft Longitude: 150° 54' 30.391" W Position Uncertainty: 0.000 ft Slot Radius: 0 " Grid Convergence: -0.8559 ° Well Plan: CD3.110 -Slot 10 Well Position +N/S 0.000 ft Northing: 6,003,833.7520 ft Latitude: 70° 25' 09.915" N +ElalV 0.000 ft Easting: 388,188.3581 ft Longitude: 150° 54' 39.157" W Position Uncertainty 0.000 ft Wellhead Elevation: ft Ground Level: 0.000 ft Wellbore Plan: CD3-110 Magnetics Mtidei Name Sample Date Declination Dip Angie Field Strength {~ (°) (n~ BGGM2004 3/1/2005 23.7620 80.6757 57,537 Design CD3-110 (wp02) Audit Notes: Version: Phase: PLAN Tie On Depth: 36.100 Vertical Section: Depth From (TVD) +N/S +E/-W Direction {ft? {~ (ft) {°) 0.000 0.000 0.000 340.4295 Plan Sections Measured Vertical Dogleg Build Tum Depth. inclination Azimuth Depth +N/S +E/ W Rate Rate Rate TFO (ft) (°) {~, {ft) {ft) {ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 36.100 0.000 0.0000 36.100 0.000 0.000 0.00 0.00 0.00 0.0000 300.000 0.000 0.0000 300.000 0.000 0.000 0.00 0.00 0.00 0.0000 1,256.630 28.699 23.3679 1,217.127 215.372 93.057 3.00 3.00 0.00 23.3679 6,696.980 28.699 23.3679 5,989.159 2,613.580 1,129.259 0.00 0.00 0.00 0.0000 8,518.942 87.139 324.8708 6,969.600 3,943.636 722.901 4.00 3.21 -3.21 -03.0042 CD3-110 wp02 7" 8,542.831 86.183 324.8506 6,970.991 3,963.138 709.175 4.00 x.00 -0.08 -178.7905 8,702.089 86.183 324.8506 6,981.592 4,093.066 617.692 0.00 0.00 0.00 0.0000 8,819.536 90.880 324.9498 6,984.600 4,189.098 550.201 4.00 4.00 0.08 1.2107 CD3-110 wp02 17,020.624 90.880 324.9498 6,858.600 10,902.116 -4,159.083 0.00 0.00 0.00 0.0000 CD3-110 wp02 Toe 3/1/2005 2:33:37PM Page 2 of 8 COMPASS 2003.11 Build 48 ~~ Conoco/Phillips Datatsase: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska Inc. (Alpine) Project: Colville River Unit Site: Alpine CD3 Well: Plan: CD3-110 Wellbore: Plan: CD3.110 Design: CD3-110 (wp02) Halliburton Company r-+n~~iBUATOr~ Planning Report ___.w __ __:_W ~.__.____.__~m~ ~n1~ltnpg Local Co-onfinate Reference: Well Plan: CD3-110 -Slot 10 ND'Refen3nce: Doyon 19 Q 48.600ft (RKB 48.6 ft above MSL) MD Reference: Doyon 19 @ 48.600ft (RK8 48.6 ft above MSL) North Reference: True Survey Calculation Method:- Minimum Curvature Planned Survey Measured Vertical Vertical` - Dogleg D@P~ inclination Azimuth Depth +N/S *E/alY Section Rate (~1 4°) (°J (>~ (~U (~? tttj (°~laoft) 36.100 0.000 0.0000 36.100 0.000 0.000 0.000 0.00 Build Turn Rate Rate (°/100ft) (°/100ft) 0.00 0.00 SHL - 3941ft FNL & 855ft FEL, Secs T12Nat5E 100.000 0.000 0.0000 100.000 0.000 0.000 0.000 0.00 0.00 0.00 199.999 0.000 0.0000 199.999 0.000 0.000 0.000 0.00 0.00 0.00 300.000 0.000 0.0000 300.000 0.000 0.000 0.000 0.00 0.00 0.00 300.100 0.000 23.3679 300.100 0.000 0.000 0.000 0.00 0.00 0.00 Begin Dir Q 3.00 DLS: 300.100ft MD,300. 100ft TVD 400.000 3.000 23.3679 399.954 2.403 1.038 1.916 3.00 3.00 0.00 500.000 6.000 23.3679 499.635 9.604 4.150 7.659 3.00 3.00 0.00 600.000 9.000 23.3679 598.768 21.585 9.326 17.214 3.00 3.00 0.00 700.000 12.000 23.3679 697.082 38.312 16.554 30.554 3.00 3.00 0.00 800.000 15.000 23.3679 794.308 59.739 25.812 47.642 3.00 3.00 0.00 900.000 18.000 23.3679 890.179 85.808 37.075 68.432 3.00 3.00 0.00 1,000.000 21.000 23.3679 984.432 116.447 50.314 92.867 3.00 3.00 0.00 1,100.000 24.000 23.3679 1,076.810 151.573 65.491 120.879 3.00 3.00 0.00 1,200.000 27.000 23.3679 1,167.058 191.088 82.564 152.393 3.00 3.00 0.00 1,256.630 28.699 23.3679 1,217.127 215.372 93.057 171.759 3.00 3.00 0.00 End DirStart Sail-28.698° ,1256.830 ft MD, 1217.127 ft ND 1,292.511 28.699 23.3679 1,248.600 231.189 99.891 184.373 0.00 0.00 0.00 Base Permafrost 1,300.000 28.699 23.3679 1,255.169 234.490 101.317 187.006 0.00 0.00 0.00 1,400.000 28.699 23.3679 1,342.885 278.572 120.364 222.161 0.00 0.00 0.00 1,500.000 28.699 23.3679 1,430.600 322.654 139.410 257.317 0.00 0.00 0.00 1,600.000 28.699 23.3679 1,518.316 366.736 158.457 292.472 0.00 0.00 0.00 1,700.000 28.699 23.3679 1,606.032 410.818 177.504 327.627 0.00 0.00 0.00 1,800.000 28.699 23.3679 1,693.747 454.900 196.550 362.783 0.00 0.00 0.00 1,900.000 28.699 23.3679 1,781.463 498.982 215.597 397.938 0.00 0.00 0.00 2,000.000 28.699 23.3679 1,869.178 543.063 234.643 433.093 0.00 0.00 0.00 2,100.000 28.699 23.3679 1,956.894 587.145 253.690 468.248 0.00 0.00 0.00 2,200.000 28.699 23.3679 2,044.609 631.227 272.737 503.404 0.00 0.00 0.00 2,300.000 28.699 23.3679 2,132.325 675.309 291.783 538.559 0.00 0.00 0.00 2,400.000 28.699 23.3679 2,220.040 719.391 310.830 573.714 0.00 0.00 0.00 2,500.000 28.699 23.3679 2,307.756 763.473 329.876 608.870 0.00 0.00 0.00 2,535.164 28.699 23.3679 2,338.600 778.974 336.574 621.232 0.00 0.00 0.00 G40 2,600.000 28.699 23.3679 2,395.471 807.555 348.923 644.025 0.00 0.00 0.00 2,700.000 28.699 23.3679 2,483.187 851.636 367.970 679.180 0.00 0.00 0.00 2,728.288 28.699 23.3679 2,508.000 864.106 373.358 689.125 0.00 0.00 0.00 9.618" Csg Pt ... Drill out 8-1/2" Hole : 2716.077ft MD, 2508.OOOft ND - 9 5/8" 2,740.373 28.699 23.3679 2,518.600 869.434 375.659 693.373 0.00 0.00 0.00 C30 2,800.000 28.699 23.3679 2,570.902 895.718 387.016 714.335 0.00 0.00 0.00 2,900.000 28.699 23.3679 2,658.618 939.800 406.063 749.491 0.00 0.00 0.00 3,000.000 28.699 23.3679 2,746.334 983.882 425.110 784.646 0.00 0.00 0.00 3,100.000 28.699 23.3679 2,834.049 1,027.964 444.156 819.801 0.00 0.00 0.00 3,173.591 28.699 23.3679 2,898.600 1,060.404 458.173 845.673 0.00 0.00 0.00 C~20 3,200.000 28.699 23.3679 2,921.765 1,072.046 463.203 854.957 0.00 0.00 0.00 3,300.000 28.699 23.3679 3,009.480 1,116.128 482.249 890.112 0.00 0.00 0.00 3,400.000 28.699 23.3679 3,097.196 1,160.210 501.296 925.267 0.00 0.00 0.00 3,500.000 28.699 23.3679 3,184.911 1,204.291 520.343 960.422 0.00 0.00 0.00 3,600.000 28.699 23.3679 3,272.627 1,248.373 539.389 995.578 0.00 0.00 0.00 3,700.000 28.699 23.3679 3,360.342 1,292.455 558.436 1,030.733 0.00 0.00 0.00 3/1/2005 2:33:37PM Page 3 of 8 COMPASS 2003.11 Build 48 ORIGINAL ~ y-' Halliburton Company • ~~~~~~1~~ Planning Report HALLIBUAT4N __... ___w._...~.w S+l~rlric~as ~iN4e~ g Database: EDM 2003.11 Single User Db Lociti Coordinate Reference: Well Plan: CD3-110 -Slot 10 Company: ConocoPhillips Alaska Inc. (Alpine) TVD Reference: Doyon 19 @ 48.600ft (RKB 48.6 ft above MSL) Project:. Colville River Unit MD Reference: Doyon 19 @ 48.600ft (RKB 48.6 ft above MSL) Site: Alpine CD3 North Reference: True Well: Plan: CD3-110 Survey Calculation Method: Minimum Curvature Weilbore; Plan: CD3-110 Design• CD3-110 (wp02) Planned Survey Measured Vertical VerticaF Dogleg Build Tum Depftt tnclination Azimuth Depth +N/.,S +EialY Section. Rate Rate Rate (~ (°}' (°) (~ (~) (~. (ft) (°/100ft) (°/100ft) (°/100ft) 3,800.000 28.699 23.3679 3,448.058 1,336.537 577.483 1,065.888 0.00 0.00 0.00 3,900.000 28.699 23.3679 3,535.773 1,380.619 596.529 1,101.044 0.00 0.00 0.00 4,000.000 28.699 23.3679 3,623.489 1,424.701 615.576 1,136.199 0.00 0.00 0.00 4,100.000 28.699 23.3679 3,711.204 1,468.783 634.622 1,171.354 0.00 0.00 0.00 4,200.000 28.699 23.3679 3,798.920 1,512.865 653.669 1,206.510 0.00 0.00 0.00 4,300.000 28.699 23.3679 3,886.635 1,556.946 672.716 1,241.665 0.00 0.00 0.00 4,333.021 28.699 23.3679 3,915.600 1,571.503 679.005 1,253.273 0.00 0.00 0.00 K3 4,400.000 28.699 23.3679 3,974.351 1,601.028 691.762 1,276.820 0.00 0.00 0.00 4,500.000 28.699 23.3679 4,062.067 1,645.110 710.809 1,311.975 0.00 0.00 0.00 4,600.000 28.699 23.3679 4,149.782 1,689.192 729.855 1,347.131 0.00 0.00 0.00 4,700.000 28.699 23.3679 4,237.498 1,733.274 748.902 1,382.286 0.00 0.00 0.00 4,800.000 28.699 23.3679 4,325.213 1,777.356 767.949 1,417.441 0.00 0.00 0.00 4,900.000 28.699 23.3679 4,412.929 1,821.438 786.995 1,452.597 0.00 0.00 0.00 5,000.000 28.699 23.3679 4,500.644 1,865.519 806.042 1,487.752 0.00 0.00 0.00 5,100.000 28.699 23.3679 4,588.360 1,909.601 825.089 1,522.907 0.00 0.00 0.00 5,200.000 28.699 23.3679 4,676.075 1,953.683 844.135 1,558.062 0.00 0.00 0.00 5,300.000 28.699 23.3679 4,763.791 1,997.765 863.182 1,593.218 0.00 0.00 0.00 5,400.000 28.699 23.3679 4,851.506 2,041.847 882.228 1,628.373 0.00 0.00 0.00 5,500.000 28.699 23.3679 4,939.222 2,085.929 901.275 1,663.528 0.00 0.00 0.00 5,600.000 28.699 23.3679 5,026.937 2,130.011 920.322 1,698.684 0.00 0.00 0.00 5,700.000 28.699 23.3679 5,114.653 2,174.093 939.368 1,733.839 0.00 0.00 0.00 5,800.000 28.699 23.3679 5,202.369 2,218.174 958.415 1,768.994 0.00 0.00 0.00 5,900.000 28.699 23.3679 5,290.084 2,262.256 977.461 1,804.149 0.00 0.00 0.00 6,000.000 28.699 23.3679 5,377.800 2,306.338 996.508 1,839.305 0.00 0.00 0.00 6,100.000 28.699 23.3679 5,465.515 2,350.420 1,015.555 1,874.460 0.00 0.00 0.00 6,200.000 28.699 23.3679 5,553.231 2,394.502 1,034.601 1,909.615 0.00 0.00 0.00 6,300.000 28.699 23.3679 5,640.946 2,438.584 1,053.648 1,944.771 0.00 0.00 0.00 6,400.000 28.699 23.3679 5,728.662 2,482.666 1,072.695 1,979.926 0.00 0.00 0.00 6,438.691 28.699 23.3679 5,762.600 2,499.721 1,080.064 1,993.528 0.00 0.00 0.00 Albian 97 6,500.000 28.699 23.3679 5,816.377 2,526.747 1,091.741 2,015.081 0.00 0.00 0.00 6,600.000 28.699 23.3679 5,904.093 2,570.829 1,110.788 2,050.237 0.00 0.00 0.00 6,679.242 28.699 23.3679 5,973.600 2,605.761 1,125.881 2,078.094 0.00 0.00 0.00 Albian 96 6,696.980 28.699 23.3679 5,989.159 2,613.580 1,129.259 2,084.330 0.00 0.00 0.00 Begin Dir - 4.00°DLS, 6696.990 ft MD, 5989.168 ft TVD 6,700.000 28.753 23.1461 5,991.808 2,614.913 1,129.832 2,085.395 3.96 1.81 -7.34 6,800.000 30.770 16.1799 6,078.639 2,661.616 1,146.420 2,123.843 4.00 2.02 -6.97 6,900.000 33.115 10.0496 6,163.513 2,713.102 1,158.318 2,168.369 4.00 2.35 -6.13 7,000.000 35.724 4.6806 6,246.016 2,769.120 1,165.468 2,218.755 4.00 2.61 -5.37 7,100.000 38.542 359.9747 6,325.747 2,829.396 1,167.837 2,274.757 4.00 2.82 -4.71 7,200.000 41.527 355.8312 6,402.317 2,893.639 1,165.411 2,336.101 4.00 2.98 -4.14 7,300.000 44.643 352.1578 6,475.353 2,961.534 1,158.203 2,402.488 4.00 3.12 -3.67 7,369.145 46.862 349.8490 6,523.600 3,010.443 1,150.440 2,451.172 4.00 3.21 -3.34 Top HRZ 7,400.000 47.865 348.8741 6,544.499 3,032.751 1,146.248 2,473.595 4.00 3.25 3.16 7,500.000 51.171 345.9125 6,609.419 3,106.942 1,129.604 2,549.076 4.00 3.31 -2.96 7,557.317 53.098 344.3371 6,644.600 3,150.669 1,117.981 2,594.170 4.00 3.36 -2.75 Base HRZ 7,600.000 54.545 343.2165 6,669.795 3,183.747 1,108.353 2,628.562 4.00 3.39 -2.63 7,629.332 55.547 342.4683 6,686.600 3,206.718 1,101.260 2,652.582 4.00 3.42 -2.55 3/1/2005 2:33:37PM Page 4 of 8 COMPASS 2003.11 Build 48 ORIGINAL ~ ~ Halliburton Company /'` * ~ 1~Q~~~'~t Planning Report MALLIBUI4TGN _.._._._ It#hrifltl n(~ Database: EDM 2003.11 Single User Db Local Cootdtnate Reference:. Well Plan: CD3-110 -Slot 10 Company: ConocoPhillips Alaska Inc. (Alpine) TVD :Reference: Doyon 19 Q 48.600ft (RKB 48.6 ft above MSL) Project: Colville River Unit MD Reference: Doyon 19 Q 48.600ft (RKB 48.6 ft above MSL) Site: Alpine CD3 North Referenc®: True Well: Plan: CD3.110 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3.110 Design: CD3-110 (wp02) Planned Survey Measured Vertical Nattiest- Dogleg Build Tum Dsp~ lnciination Azimuth Depth +N/S +E/alll Section Rate Rate Rate (~} (°} (°} (~ (it) (~ (~ (°/100ft) (°/100ft) (°/100ft) K-1 7,700.000 57.974 340.7394 6,725.334 3,262.792 1,082.597 2,711.667 4.00 3.44 -2.45 7,706.177 58.189 340.5920 6,728.600 3,267.739 1,080.861 2,716.910 4.02 3.47 -2.39 Top Kuparuk D 7,795.480 61.291 338.5422 6,773.600 3,339.999 1,053.917 2,794.021 4.00 3.47 -2.30 Top Kuparuk C 7,800.000 61.448 338.4424 6,775.766 3,343.690 1,052.463 2,797.986 3.97 3.47 -2.21 7,805.950 61.657 338.3100 6,778.600 3,348.553 1,050.535 2,803.214 4.02 3.51 -2.23 LCU 7,900.000 64.958 336.2930 6,820.844 3,426.048 1,018.097 2,887.098 4.00 3.51 -2.14 8,000.000 68.498 334.2638 6,860.349 3,509.465 979.666 2,978.569 4.00 3.54 -2.03 8,008.933 68.816 334.0870 6,863.600 3,516.954 976.042 2,986.839 4.01 3.57 -1.98 Base Nuigsut 8,100.000 72.060 332.3315 6,894.089 3,593.534 937.359 3,071.953 4.00 3.56 -1.93 8,200.000 75.641 330.4757 6,921.898 3,677.846 891.380 3,166.795 4.00 3.58 -1.86 8,300.000 79.236 328.6785 6,943.643 3,761.990 841.954 3,262.634 4.00 3.59 -1.80 8,400.000 82.841 326.9238 6,959.216 3,845.556 789.322 3,359.003 4.00 3.61 -1.75 8,439.010 84.251 326.2469 6,963.600 3,877.911 767.976 3,396.638 4.00 3.61 -1.74 Top Nechelik 8,500.000 86.453 325.1966 6,968.541 3,928.137 733.740 3,455.431 4.00 3.61 -1.72 8,518.942 87.139 324.8708 6,969.600 3,943.636 722.901 3,473.665 4.01 3.62 -1.72 Target (7" Csg Pt) GeoSteer, 8819ft MD, 6970ft TVD, 5277ft FNL, 2763ft FEL, Sec32-T73N~R5E - 7" -CD3-110 wp02 7° Csg Pt 8,542.831 86.183 324.8506 6,970.991 3,963.138 709.175 3,496.638 4.00 x.00 -0.08 8,600.000 86.183 324.8506 6,974.797 4,009.778 676.335 3,551.584 0.00 0.00 0.00 8,700.000 86.183 324.8506 6,981.453 4,091.362 618.892 3,647.697 0.00 0.00 0.00 8,702.089 86.183 324.8506 6,981.592 4,093.066 617.692 3,649.704 0.00 0.00 0.00 8,800.000 90.098 324.9333 6,984.767 4,173.107 561.422 3,743.970 4.00 4.00 0.08 8,819.536 90.880 324.9498 6,984.600 4,189.098 550.201 3,762.795 4.01 4.01 0.08 Target (Deep Pt) GeoSteer, 8820ft MD, 6985ft TVD -CD3-110 wp02 Deep Pt 8,900.000 90.880 324.9498 6,983.364 4,254.962 503.996 3,840.331 0.00 0.00 0.00 9,000.000 90.880 324.9498 6,981.827 4,336.817 446.573 3,936.692 0.00 0.00 0.00 9,100.000 90.880 324.9498 6,980.291 4,418.672 389.151 4,033.054 0.00 0.00 0.00 9,200.000 90.880 324.9498 6,978.755 4,500.527 331.728 4,129.415 0.00 0.00 0.00 9,300.000 90.880 324.9498 6,977.218 4,582.382 274.305 4,225.776 0.00 0.00 0.00 9,400.000 90.880 324.9498 6,975.682 4,664.238 216.883 4,322.137 0.00 0.00 0.00 9,500.000 90.880 324.9498 6,974.145 4,746.093 159.460 4,418.498 0.00 0.00 0.00 9,600.000 90.880 324.9498 6,972.609 4,827.948 102.037 4,514.859 0.00 0.00 0.00 9,700.000 90.880 324.9498 6,971.073 4,909.803 44.615 4,611.220 0.00 0.00 0.00 9,800.000 90.880 324.9498 6,969.536 4,991.659 -12.808 4,707.581 0.00 0.00 0.00 9,900.000 90.880 324.9498 6,968.000 5,073.514 -70.231 4,803.942 0.00 0.00 0.00 10,000.000 90.880 324.9498 6,966.464 5,155.369 -127.653 4,900.304 0.00 0.00 0.00 10,100.000 90.880 324.9498 6,964.927 5,237.224 -185.076 4,996.665 0.00 0.00 0.00 10,200.000 90.880 324.9498 6,963.391 5,319.079 -242.499 5,093.026 0.00 0.00 0.00 10,300.000 90.880 324.9498 6,961.854 5,400.935 -299.921 5,189.387 0.00 0.00 0.00 10,400.000 90.880 324.9498 6,960.318 5,482.790 -357.344 5,285.748 0.00 0.00 0.00 10,500.000 90.880 324.9498 6,958.782 5,564.645 -414.767 5,382.109 0.00 0.00 0.00 10,600.000 90.880 324.9498 6,957.245 5,646.500 X72.189 5,478.470 0.00 0.00 0.00 10,700.000 90.880 324.9498 6,955.709 5,728.356 -529.612 5,574.831 0.00 0.00 0.00 10,800.000 90.880 324.9498 6,954.173 5,810.211 -587.035 5,671.192 0.00 0.00 0.00 10,900.000 90.880 324.9498 6,952.636 5,892.066 -644.457 5,767.554 0.00 0.00 0.00 11,000.000 90.880 324.9498 6,951.100 5,973.921 -701.880 5,863.915 0.00 0.00 0.00 11,100.000 90.880 324.9498 6,949.563 6,055.776 -759.303 5,960.276 0.00 0.00 0.00 3/1/2005 2:33:37PM Page 5 of 8 COMPASS 2003.11 Build 48 ORIGINAL ~ ~ Halliburton Company ~ LIB T~ ~~~~~~~!~ Planning Report HAL UR N rv D+ri~lo~ Database: EDM 2003.11 Single User Db Locai Coordinate Reference: Well Plan: CD3-110 -Slot 10 Company;.': ConocoPhillips Alaska Inc. (Alpine) T1/D Reference: Doyon 19 @ 48.600ft (RKB 48.fi ft above MSL) Project: Colville River Unit MD Reference: Doyon 19 @ 48.600ft (RKB 48.6 ft above MSL) Site: Alpine CD3 North`Reference: True Well: Plan: CD3.110 Survey Ga~ulation Method: Minimum Curvature Wellbore: Plan: CD3.110 Design: CD3-110 (wp02) Planned Survey Measured - VerticaF Vertica{ Dogleg Build Tum Depth Inciination Azimuth ~i~ +N/S +E/.W Section Rate Rate Rate (ft) (') {°) (~) (~ (g) (~ (°/100ft) (°/100ft) (°/100ft) 11,200.000 90.880 324.9498 6,948.027 6,137.632 -816.725 6,056.637 0.00 0.00 0.00 11,300.000 90.880 324.9498 6,946.491 6,219.487 -874.148 6,152.998 0.00 0.00 0.00 11,400.000 90.880 324.9498 6,944.954 6,301.342 -931.571 6,249.359 0.00 0.00 0.00 11,500.000 90.880 324.9498 6,943.418 6,383.197 -988.993 6,345.720 0.00 0.00 0.00 11,600.000 90.880 324.9498 6,941.881 6,465.052 -1,046.416 6,442.081 0.00 0.00 0.00 11,700.000 90.880 324.9498 6,940.345 6,546.908 -1,103.839 6,538.442 0.00 0.00 0.00 11,800.000 90.880 324.9498 6,938.809 6,628.763 -1,161.261 6,634.803 0.00 0.00 0.00 11,900.000 90.880 324.9498 6,937.272 6,710.618 -1,218.684 6,731.165 0.00 0.00 0.00 12,000.000 90.880 324.9498 6,935.736 6,792.473 -1,276.107 6,827.526 0.00 0.00 0.00 12,100.000 90.880 324.9498 6,934.200 6,874.329 -1,333.529 6,923.887 0.00 0.00 0.00 12,200.000 90.880 324.9498 6,932.663 6,956.184 -1,390.952 7,020.248 0.00 0.00 0.00 12,300.000 90.880 324.9498 6,931.127 7,038.039 -1,448.375 7,116.609 0.00 0.00 0.00 12,400.000 90.880 324.9498 6,929.590 7,119.894 -1,505.797 7,212.970 0.00 0.00 0.00 12,500.000 90.880 324.9498 6,928.054 7,201.749 -1,563.220 7,309.331 0.00 0.00 0.00 12,600.000 90.880 324.9498 6,926.518 7,283.605 -1,620.643 7,405.692 0.00 0.00 0.00 12,700.000 90.880 324.9498 6,924.981 7,365.460 -1,678.065 7,502.053 0.00 0.00 0.00 12,800.000 90.880 324.9498 6,923.445 7,447.315 -1,735.488 7,598.415 0.00 0.00 0.00 12,900.000 90.880 324.9498 6,921.909 7,529.170 -1,792.911 7,694.776 0.00 0.00 0.00 13,000.000 90.880 324.9498 6,920.372 7,611.026 -1,850.333 7,791.137 0.00 0.00 0.00 13,100.000 90.880 324.9498 6,918.836 7,692.881 -1,907.756 7,887.498 0.00 0.00 0.00 13,200.000 90.880 324.9498 6,917.299 7,774.736 -1,965.179 7,983.859 0.00 0.00 0.00 13,300.000 90.880 324.9498 6,915.763 7,856.591 -2,022.601 8,080.220 0.00 0.00 0.00 13,400.000 90.880 324.9498 6,914.227 7,938.446 -2,080.024 8,176.581 0.00 0.00 0.00 13,500.000 90.880 324.9498 6,912.690 8,020.302 -2,137.447 8,272.942 0.00 0.00 0.00 13,600.000 90.880 324.9498 6,911.154 8,102.157 -2,194.869 8,369.303 0.00 0.00 0.00 13,700.000 90.880 324.9498 6,909.617 8,184.012 -2,252.292 8,465.665 0.00 0.00 0.00 13,800.000 90.880 324.9498 6,908.081 8,265.867 -2,309.715 8,562.026 0.00 0.00 0.00 13,900.000 90.880 324.9498 6,906.545 8,347.722 -2,367.137 8,658.387 0.00 0.00 0.00 14,000.000 90.880 324.9498 6,905.008 8,429.578 -2,424.560 8,754.748 0.00 0.00 0.00 14,100.000 90.880 324.9498 6,903.472 8,511.433 -2,481.983 8,851.109 0.00 0.00 0.00 14,200.000 90.880 324.9498 6,901.936 8,593.288 -2,539.405 8,947.470 0.00 0.00 0.00 14,300.000 90.880 324.9498 6,900.399 8,675.143 -2,596.828 9,043.831 0.00 0.00 0.00 14,400.000 90.880 324.9498 6,898.863 8,756.999 -2,654.251 9,140.192 0.00 0.00 0.00 14,500.000 90.880 324.9498 6,897.326 8,838.854 -2,711.673 9,236.553 0.00 0.00 0.00 14,600.000 90.880 324.9498 6,895.790 8,920.709 -2,769.096 9,332.914 0.00 0.00 0.00 14,700.000 90.880 324.9498 6,894.254 9,002.564 -2,826.519 9,429.276 0.00 0.00 0.00 14,800.000 90.880 324.9498 6,892.717 9,084.419 -2,883.941 9,525.637 0.00 0.00 0.00 14,900.000 90.880 324.9498 6,891.181 9,166.275 -2,941.364 9,621.998 0.00 0.00 0.00 15,000.000 90.880 324.9498 6,889.644 9,248.130 -2,998.787 9,718.359 0.00 0.00 0.00 15,100.000 90.880 324.9498 6,888.108 9,329.985 -3,056.209 9,814.720 0.00 0.00 0.00 15,200.000 90.880 324.9498 6,886.572 9,411.840 -3,113.632 9,911.081 0.00 0.00 0.00 15,300.000 90.880 324.9498 6,885.035 9,493.696 -3,171.055 10,007.442 0.00 0.00 0.00 15,400.000 90.880 324.9498 6,883.499 9,575.551 -3,228.477 10,103.803 0.00 0.00 0.00 15,500.000 90.880 324.9498 6,881.963 9,657.406 -3,285.900 10,200.164 0.00 0.00 0.00 15,600.000 90.880 324.9498 6,880.426 9,739.261 -3,343.323 10,296.526 0.00 0.00 0.00 15,700.000 90.880 324.9498 6,878.890 9,821.116 -3,400.745 10,392.887 0.00 0.00 0.00 15,800.000 90.880 324.9498 6,877.353 9,902.972 -3,458.168 10,489.248 0.00 0.00 0.00 15,900.000 90.880 324.9498 6,875.817 9,984.827 -3,515.591 10,585.609 0.00 0.00 0.00 16,000.000 90.880 324.9498 6,874.281 10,066.682 -3,573.013 10,681.970 0.00 0.00 0.00 16,100.000 90.880 324.9498 6,872.744 10,148.537 -3,630.436 10,778.331 0.00 0.00 0.00 16,200.000 90.880 324.9498 6,871.208 10,230.392 -3,687.859 10,874.692 0.00 0.00 0.00 16,300.000 90.880 324.9498 6,869.672 10,312.248 -3,745.281 10,971.053 0.00 0.00 0.00 16,400.000 90.880 324.9498 6,868.135 10,394.103 -3,802.704 11,067.414 0.00 0.00 0.00 16,500.000 90.880 324.9498 6,866.599 10,475.958 -3,860.127 11,163.776 0.00 0.00 0.00 3/1/2005 2:33:37PM Page 6 of 8 COMPASS 2003.11 Build 48 ORIGINAL y/ '~t31'1~?C!~I-"1 ~ I ~ 1 ~3-5 Database: EDM 2003.11 Single User Db Companys ConocoPhillips Alaska lnc. (Alpine) Project: Colville River Unit Site: Alpine CD3 Well: Plan: CD3-110 Wellbore: Plan: CD3.110 Design: CD3-110 (wp02) Halliburton Company NALtrfBUATDfV Planning Repoli r .~~,._~ ~____._ LocatCo•ordinate Reference: Well Plan: CD3-110 -Slot 10 TVD Reference: Doyon 19 @ 48.600ft (RKB 48.6 ft above MSL) MD Reference: Doyon 19 @ 48.600ft (RKB 48.6 ft above MSL) North Reference: True Survey Calculation Method• Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth inclination Azimuth Depth +N/S +EtdM Section Rate Rate Rate C) (°) ~~} (~I (ftp (ft} (°nooft> (°nooft} (°/laoft) 16,600.000 90.880 324.9498 6,865.062 10,557.813 3,917.549 11,260.137 0.00 0.00 0.00 16,700.000 90.880 324.9498 6,863.526 10,639.669 -3,974.972 11,356.498 0.00 0.00 0.00 16,800.000 90.880 324.9498 6,861.990 10,721.524 -4,032.395 11,452.859 0.00 0.00 0.00 16,900.000 90.880 324.9498 6,860.453 10,803.379 x,089.817 11,549.220 0.00 0.00 0.00 17,000.000 90.880 324.9498 6,858.917 10,885.234 x,147.240 11,645.581 0.00 0.00 0.00 17,020.624 90.880 324.9498 6,858.600 10,902.116 x,159.083 11,665.454 0.00 0.00 0.00 Target (Toe) :17020ft MD, 6858ft TVD, (3600ft FNL, 2342ft FEL, Sec30-T73N•R5E - 6 1!8" Open Hole -CD3-110 wp02 Toe Targets __ Target Nettw - hiUmiss target Dip Angle Dip Dir. TVD +W-S +E/ W Northing ; Fasting -Shape (% (~ (tt) ft ft (ft) (ft) Latitude Longitude CD3-110 wp02 Deep 0.00 0.00 6,984.600 4,189.098 550.201 6,008,013.7800 388,801.1900 70° 25' 51.114" N 150° 54' 23.014" W -plan hits target - Point CD3-110 wp02 Toe 0.00 0.00 6,858.600 10,902.116 x,159.083 6,014,796.0000 384,193.3800 70° 26' 57.123" N 150° 56' 41.295" W -) - Point CD3-110 wp02 7" 0.00 0.00 6,969.600 3,943.636 722.901 6,007,765.7800 388,970.1800 70° 25' 48.699" N 150° 54' 17.948" W -plan hits target -Point Casing Poir-ts :Measured: Vertical Casing Hole pepth ~~ Name Diameter Diameter 2,728.288 2,508.000 9 5/8" 9-5/8 12-1/4 8,518.942 6,969.600 7" 7 8-1 /2 17,020.600 6,858.600 61/8"Open Hole 6-1 /8 6-1 /8 3/1/2005 2:33:37PM Page 7 of 8 COMPASS 2003.11 Build 48 ORIGINAL '~t~1"`1QCCMI~f1~S Database: EDM 2003.11 Single User Db Company: ConocoPhiliips Alaska Inc. (Alpine) Project: Colville River Unit Site: Alpine CD3 Well: Plan: CD3.110 Wellbore: Plan: CD3.110 Design: CD3-110 (wp02) Halliburton Company HALLf BURTDN Planning Report _. _. _ m-.._._ ._.._v._. __~._____~... t~ri~i~g Lot:ai Go•ordinate Reference: Well Plan: CD3-110 -Slot 10 ND Reference: Doyon 19 @ 48.600ft (RKB 48.6 ft above MSL) MD Reference: Doyon 19 Q 48.600ft (RKB 48.6 ft above MSL) North Reference: True Survey Calculation Method: Minimum Curvature Formations - _ -~._ ._ Measured Yerticat Dip Depth Depth Name Lithology Dip Direction (ft) (~) (°) (°) 1,292.511 1,248.600 Base Permafrost 0.0000 2,535.164 2,338.600 C~0 0.0000 2,740.373 2,518.600 C-30 0.0000 3,173.591 2,898.600 C-20 0.0000 4,333.021 3,915.600 K-3 0.0000 6,438.691 5,762.600 Albian 97 0.0000 6,679.242 5,973.600 Albian 96 0.0000 7,369.145 6,523.600 Top HRZ 0.0000 7,557.317 6,644.600 Base HRZ 0.0000 7,629.332 6,686.600 K-1 0.0000 7,706.177 6,728.600 Top Kuparuk D 0.0000 7,795.480 6,773.600 Top Kuparuk C 0.0000 7,805.950 6,778.600 LCU 0.0000 8,008.933 6,863.600 Base Nuiqsut 0.0000 8,439.010 6,963.600 Top Nechelik 0.0000 7,093.600 Base Nechelik 0.0000 ...Plan Annotations Measured Vertical Locat Goordinatas Depth Depth +N/S +E/•W Comment (~? (~) (~) (~j 36.100 36.100 0.000 0.000 SHL - 3941ft FNL & 855ft FEL, Secs-T12N-R5E 300.100 300.100 0.000 0.000 Begin Dir Q 3.00 DLS: 300.100ft MD,300.100ft TVD 1,256.630 1,217.127 215.372 93.057 End DirStart Sail-28.699° , 1256.630 ft MD, 1217.127 ft TVD 2,728.288 2,508.000 864.106 373.358 9-5/8" Csg Pt ... Drill out 8-1 /2" Hole : 2716.077ft MD, 2508.OOOft TVD 6,696.990 5,989.168 2,613.584 1,129.261 Begin Dir -4.00°DLS, 6696.990 ft MD, 5989.168 ft TVD 8,518.942 6,969.600 3,943.636 722.901 Target (7" Csg Pt) GeoSteer, 8819ft MD, 6970ft TVD, 5277ft FNL, 2763ft 8,819.540 6,984.600 4,189.101 550.198 Target (Deep Pt) GeoSteer, 8820ft MD, 6985ft TVD 17,020.600 6,858.600 10,902.096 -4,159.069 Target (Toe) : 17020ft MD, 6858ft TVD, (3600ft FNL, 2342ft FEL, Sec30- 3/1/2005 2:33:37PM Page 8 of 8 COMPASS 2003.11 Build 48 u u ConocoPhillips Alaska Inc. Colville River Unit Alpine CD3 Plan: CD3-110 -Slot 10 Plan: CD3-110 Plan: CD3-110 (wp02) NAD27 Geo Report 01 March, 2005 Local Coordinate Origin: Centered on Well Plan: CD3-110 -Slot 10 Viewing Datum: Doyon 19 @ 48.600ft (RKB 48.6 ft above MSL) TVDs to System: N North Reference: True Unit System: API - US Survey Feet HALLIBIJRTON ORIGINAL • HA[_L~BUi~TON ConocoPhillips Alaska Inc. (Alpine) Colville River Unit Plan Report for Plan: CD3-110 -Plan: CD3-110 -CD3-110 (wp02) Measured Subsystem Vertical Local Coordinates Depth Inclination Azimuth Depth Depth +N/s +E/-W (ft) (°) (°) (ft) (ft) (ft) (ft) 36.100 0.000 0.0000 -12.500 36.100 0.000 0.000 SHG-3941ft FNL 8; 855ftFEL, Secs T12Na25E 100.000 0.000 0.0000 51.400 100.000 0.000 0.000 199.999 0.000 0.0000 151.399 199.999 0.000 0.000 300.000 0.000 0.0000 251.400 300.000 0.000 0.000 300.100 0.000 23.3679 251.500 300.100 0.000 0.000 ~ Begin Dir ~ 3.00 DLSt 300.100ft MD,300.100ft ND 400.000 3.000 23.3679 351.354 399.954 2.403 1.038 500.000 6.000 23.3679 451.035 499.635 9.604 4.150 600.000 9.000 23.3679 550.168 598.768 21.585 9.326 700.000 12.000 23.3679 648.482 697.082 38.312 16.554 800.000 15.000 23.3679 745.708 794.308 59.739 25.812 900.000 18.000 23.3679 841.579 890.179 85.808 37.075 1,000.000 21.000 23.3679 935.832 984.432 116.447 50.314 1,100.000 24.000 23.3679 1,028.210 1,076.810 151.573 65.491 1,200.000 27.000 23.3679 1,118.458 1,167.058 191.088 82.564 1,256.630 28.699 23.3679 1,168.527 1,217.127 215.372 93.057 End Dirstart Sail-28.699° ,1256.630 ft MD,1217.127 ft ND 1,292.511 28.699 23.3679 1,200.000 1,248.600 231.189 99.891 $ase Permafrost 1,300.000 28.699 23.3679 1,206.569 1,255.169 234.490 101.317 1,400.000 28.699 23.3679 1,294.285 1,342.885 278.572 120.364 1,500.000 28.699 23.3679 1,382.000 1,430.600 322.654 139.410 1,600.000 28.699 23.3679 1,469.716 1,518.316 366.736 158.457 1,700.000 28.699 23.3679 1,557.432 1,606.032 410.818 177.504 1,800.000 28.699 23.3679 1,645.147 1,693.747 454.900 196.550 1,900.000 28.699 23.3679 1,732.863 1,781.463 498.982 215.597 2,000.000 28.699 23.3679 1,820.578 1,869.178 543.063 234.643 2,100.000 28.699 23.3679 1,908.294 1,956.894 587.145 253.690 2,200.000 28.699 23.3679 1,996.009 2,044.609 631.227 272.737 2,300.000 28,699 23.3679 2,083.725 2,132.325 675.309 291.783 2,400.000 28.699 23.3679 2,171.440 2,220.040 719.391 310.830 2,500.000 28.699 23.3679 2,259.156 2,307.756 763.473 329.876 2,535.164 28.699 23.3679 2,290.000 2,338.600 778.974 336.574 C-40 2,600.000 28.699 23.3679 2,346.871 2,395.471 807.555 348.923 2,700.000 28.699 23.3679 2,434.587 2,483.187 851.636 367.970 2,728.288 28.699 23.3679 2,459.400 2,508.000 864.106 373.358 95/8" Csg Pt ... Drill out 8-1/2" Hole : 2718.077ft MD, 2508.000ft ND - 9 5/8" 2,740.373 28.699 23.3679 2,470.000 2,518.600 869.434 375.659 C~30 2,800.000 28.699 23.3679 2,522.302 2,570.902 895.718 387.016 2,900.000 28.699 23.3679 2,610.018 2,658.618 939.800 406.063 3,000.000 28.699 23.3679 2,697.734 2,746.334 983.882 425.110 3,100.000 28.699 23.3679 2,785.449 2,834.049 1,027.964 444.156 3,173.591 28.699 23.3679 2,850.000 2,898.600 1,060.404 458.173 G-20 3,200.000 28.699 23.3679 2,873.165 2,921.765 1,072.046 463.203 3,300.000 28.699 23.3679 2,960.880 3,009.480 1,116.128 482.249 3,400.000 28.699 23.3679 3,048.596 3,097.196 1,160.210 501.296 3,500.000 28.699 23.3679 3,136.311 3,184.911 1,204.291 520.343 3,600.000 28.699 23.3679 3,224.027 3,272.627 1,248.373 539.389 3,700.000 28.699 23.3679 3,311.742 3,360.342 1,292.455 558.436 3,800.000 28.699 23.3679 3,399.458 3,448.058 1,336.537 577.483 3,900.000 28.699 23.3679 3,487.173 3,535.773 1,380.619 596.529 4,000.000 28.699 23.3679 3,574.889 3,623.489 1,424.701 615.576 4,100.000 28.699 23.3679 3,662.604 3,711.204 1,468.783 634.622 4,200.000 28.699 23.3679 3,750.320 3,798.920 1,512.865 653.669 Map Coordinates Northing Easting 1ft) (ft) 6,003,833.7520 ~ 388,188.3581 6,003,833.7520 388,188.3581 6,003,833.7520 388,188.3581 6,003,833.7520 388,188.3581 6,003,833.7520 388,188.3581 6,003,836.1387 6,003,843.2922 6,003,855.1929 6,003,871.8083 6,003,893.0927 6,003,918.9878 6,003,949.4226 6,003,984.3138 6,004,023.5657 6,004,047.6877 388,189.4320 388,192.6509 388,198.0058 388,205.4821 388,215.0594 388,226.7113 388,240.4060 388,256.1058 388,273.7678 388,284.6219 Dogleg Vertical Rate Section (°/100ft) (ft) 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 0.00 0.000 3.00 1.916 .3.00 7.659 3.00 17.214 3.00 30.554 3.00 47.642 3.00 68.432 3.00 92.867 3.00 120.879 3.00 152.393 3.00 171.759 6,004,063. 3990 388,291.6915 0.00 184.373 6,004,066. 6785 388,293.1671 0.00 187.006 6,004,110. 4664 388,312.8702 0.00 222.161 6,004,154. 2542 388,332.5732 0.00 257.317 6,004,198. 0421 388,352.2763 0.00 292.472 6,004,241. 8300 388,371.9793 0.00 327.627 6,004,285. 6179 388,391.6824 0.00 362.783 6,004,329. 4058 388,411.3855 0.00 397.938 6,004,373. 1936 388,431.0885 0.00 433.093 6,004,416. 9815 388,450.7916 0.00 468.248 6,004,460. 7694 388,470.4946 0.00 503.404 6,004,504. 5573 388,490.1977 0.00 538.559 6,004,548. 3452 388,509.9008 0.00 573.714 6,004,592. 1330 388,529.6038 0.00 608.870 6,004,607. 5305 388,536.5322 0.00 621.232 6,004,635. 9209 388,549.3069 0.00 644.025 6,004,679. 7088 388,569.0099 0.00 679.180 6,004,692. 0956 388,574.5836 0.00 689.125 6,004,697. 3871 388,576.9646 0.00 693.373 6,004,723. 4967 388,588.7130 0.00 714.335 6,004,767. 2845 388,608.4161 0.00 749.491 6,004,811. 0724 388,628.1191 0.00 784.646 6,004,854. 8603 388,647.8222 0.00 819.801 6,004,887. 0844 388,662.3219 0.00 845.673 6,004,898. 6482 388,667.5252 0.00 854.957 6,004,942. 4361 388,687.2283 0.00 890.112 6,004,986. 2239 388,706.9314 0.00 925.267 6,005,030. 0118 388,726.6344 0.00 960.422 6,005,073. 7997 388,746.3375 0.00 995.578 6,005,117. 5876 388,766.0405 0.00 1,030.733 6,005,161. 3755 388,785.7436 0.00 1,065.888 6,005,205. 1633 388,805.4467 0.00 1,101.044 6,005,248. 9512 388,825.1497 0.00 1,136.199 6,005,292. 7391 388,844.8528 0.00 1,171.354 6,005,336. 5270 388,864.5558 0.00 1,206.510 01 March, 2005 - 14:41 Page 2 of 7 COMPASS ORIGINAL • HAL_LIBURTON ConocoPhillips Alaska Inc. (Alpine) Colville River Unit Plan Report for Plan: CD~110 -Plan: CD3-110 -CD3-110 (wp02) Measured Subsystem Vertical Local Coordinates Depth Inclination Azimuth Depth Depth +N/s +E/-W (ft) ~°) ~°) (ft) (ft> (ft) (ft) 4,300.000 28.699 23.3679 3,838.035 3,886.635 1,556.946 672.716 4,333.021 28.699 23.3679 3,867.000 3,915.600 1,571.503 679.005 K~3 4,400.000 28.699 23.3679 3,925.751 3,974.351 1,601.028 4,500.000 28.699 23.3679 4,013.467 4,062.067 1,645.110 4,600.000 28.699 23.3679 4,101.182 4,149.782 1,689.192 4,700.000 28.699 23.3679 4,188.898 4,237.498 1,733.274 4,800.000 28.699 23.3679 4,276.613 4,325.213 1,777.356 4,900.000 28.699 23.3679 4,364.329 4,412.929 1,821.438 5,000.000 28.699 23.3679 4,452.044 4,500.644 1,865.519 5,100.000 28.699 23.3679 4,539.760 4,588.360 1,909.601 5,200.000 28.699 23.3679 4,627.475 4,676.075 1,953.683 5,300.000 28.699 23.3679 4,715.191 4,763.791 1,997.765 5,400.000 28.699 23.3679 4,802.906 4,851.506 2,041.847 5,500.000 28.699 23.3679 4,890.622 4,939.222 2,085.929 5,600.000 28.699 23.3679 4,978.337 5,026.937 2,130.011 5,700.000 28.699 23.3679 5,066.053 5,114.653 2,174.093 5,800.000 28.699 23.3679 5,153.769 5,202.369 2,218.174 5,900.000 28.699 23.3679 5,241.484 5,290.084 2,262.256 6,000.000 28.699 23.3679 5,329.200 5,377.800 2,306.338 6,100.000 28.699 23.3679 5,416.915 5,465.515 2,350.420 6,200.000 28.699 23.3679 5,504.631 5,553.231 2,394.502 6,300.000 28.699 23.3679 5,592.346 5,640.946 2,438.584 6,400.000 28.699 23.3679 5,680.062 5,728.662 2,482.666 6,438.691 28.699 23.3679 5,714.000 5,762.600 2,499.721 `Albian 97 6,500.000 28.699 23.3679 5,767.777 5,816.377 2,526.747 6,600.000 28.699 23.3679 5,855.493 5,904.093 2,570.829 6,679.242 28.699 23.3679 5,925.000 5,973.600 2,605.761 Albian 96 6,696.980 28.699 23.3679 5,940.559 5,989.159 2,613.580 Begin Dir -4.00°DLS, 6696.990 ft MD, 5989.168 ft TVD 6,700.000 28.753 23.1461 5,943.208 5,991.808 2,614.913 6,800.000 30.770 16.1799 6,030.039 6,078.639 2,661.616 6,900.000 33.115 10.0496 6,114.913 6,163.513 2,713.102 7,000.000 35.724 4.6806 6,197.416 6,246.016 2,769.120 7,100.000 38.542 359.9747 6,277.147 6,325.747 2,829.396 7,200.000 41.527 355.8312 6,353.717 6,402.317 2,893.639 7,300.000 44.643 352.1578 6,426.753 6,475.353 2,961.534 7,369.145 46.862 349.8490 6,475.000 6,523.600 3,010.443 Tope HRZ 7,400.000 47.865 348.8741 6,495.899 6,544.499 3,032.751 7,500.000 51.171 345.9125 6,560.819 6,609.419 3,106.942 7,557.317 53.098 344.3371 6,596.000 6,644.600 3,150.669 Base HRZ 7,600.000 54.545 343.2165 6,621.195 6,669.795 3,183.747 7,629.332 55.547 342.4683 6,638.000 6,686.600 3,206.718 K-1 7,700.000 57.974 340.7394 6,676.734 6,725.334 3,262.792 7,706.177 58.189 340.5920 6,680.000 6,728.600 3,267.739 Top KuparukD 7,795.480 61.291 338.5422 6,725.000 6,773.600 3,339.999 Top Kuparuk G 7,800.000 61.448 338.4424 6,727.166 6,775.766 3,343.690 7,805.950 61.657 338.3100 6,730.000 6,778.600 3,348.553 LCU 7,900.000 64.958 336.2930 6,772.244 6,820.844 3,426.048 8,000.000 68.498 334.2638 6,811.749 6,860.349 3,509.465 8,008.933 68.816 334.0870 6,815.000 6,863.600 3,516.954 691.762 710.809 729.855 748.902 767.949 786.995 806.042 825.089 844.135 863.182 882.228 901.275 920.322 939.368 958.415 977.461 996.508 1,015.555 1,034.601 1,053.648 1,072.695 1,080.064 1,091.741 1,110.788 1,125.881 1,129.259 1,129.832 1,146.420 1,158.318 1,165.468 1,167.837 1,165.411 1,158.203 1,150.440 1,146.248 1,129.604 1,117.981 1,108.353 1,101.260 1,082.597 1,080.861 1,053.917 1,052.463 1,050.535 1,018.097 979.666 976.042 Map Coordinates Dogleg Vertical Northing Easting Rate Section eft) eft) ~°NOOft) (ft) 6,005,380.3149 388,884.2589 0.00 1,241.665 6,005,394.7740 388,890.7650 0.00 1,253.273 6,005,424.1027 388,903.9620 0.00 1,276.820 6,005,467.8906 388,923.6650 0.00 1,311.975 6,005,511.6785 388,943.3681 0.00 1,347.131 6,005,555.4664 388,963.0711 0.00 1,382.286 6,005,599.2543 388,982.7742 0.00 1,417.441 6,005,643.0421 389,002.4773 0.00 1,452.597 6,005,686.8300 389,022.1803 0.00 1,487.752 6,005,730.6179 389,041.8834 0.00 1,522.907 6,005,774.4058 389,061.5864 0.00 1,558.062 6,005,818.1937 389,081.2895 0.00 1,593.218 6,005,861.9815 389,100.9926 0.00 1,628.373 6,005,905.7694 389,120.6956 0.00 1,663.528 6,005,949.5573 389,140.3987 0.00 1,698.684 6,005,993.3452 389,160.1017 0.00 1,733.839 6,006,037.1331 389,179.8048 0.00 1,768.994 6,006,080.9209 389,199.5079 0.00 1,804.149 6,006,124.7088 389,219.2109 0.00 1,839.305 6,006,168.4967 389,238.9140 0.00 1,874.460 6,006,212.2846 389,258.6170 0.00 1,909.615 6,006,256.0724 389,278.3201 0.00 1,944.771 6,006,299.8603 389,298.0232 0.00 1,979.926 6,006,316.8024 389,305.6465 0.00 1,993.528 6,006,343.6482 389,317.7262 0.00 2,015.081 6,006,387.4361 389,337.4293 0.00 2,050.237 6,006,422.1343 389,353.0423 0.00 2,078.094 6,006,429.9016 389,356.5373 0.00 2,084.330 6,006,431.2263 389,357.1303 3.96 2,085.395 6,006,477.6713 389,374.4141 4.00 2,123.843 6,006,528.9685 389,387.0809 4.00 2,168.369 6,006,584.8680 389,395.0690 4.00 2,218.755 6,006,645.0976 389,398.3394 4.00 2,274.757 6,006,709.3637 389,396.8762 4.00 2,336.101 6,006,777.3532 389,390.6865 4.00 2,402.488 6,006,826.3690 389,383.6576 4.00 2,451.172 6,006,848.7350 389,379.8005 4.00 2,473.595 6,006,923.1612 389,364.2712 4.00 2,549.076 6,006,967.0533 389,353.3051 4.00 2,594.170 6,007,000.2693 389,344.1743 4.00 2,628.562 6,007,023.3415 389,337.4266 4.00 2,652.582 6,007,079.6835 389,319.6077 4.00 2,711.667 6,007,084.6557 389,317.9463 4.02 2,716.910 6,007,157.3047 389,292.0901 4.00 2,794.021 6,007,161.0171 389,290.6911 3.97 2,797.986 6,007,165.9083 389,288.8364 4.02 2,803.214 6,007,243.8737 389,257.5653 4.00 2,887.098 6,007,327.8497 389,220.3917 4.00 2,978.569 6,007,335.3916 389,216.8802 4.01 2,986.839 O1 March, 2005 - 14:41 Page 3 of 7 COMPASS ORIGINAL • HA_L~BURT©N Plan Report for Plan: CD~110 -Plan: CD3-110 -CD3-110 (wp02) ConocoPhillips Alaska Inc. (Alpine) Colville River Unit Measured Subsystem Vertical Local Coordinates Map Coordinates Dogleg Vertical DeP~ Inc lination Azimuth Depth Depth +N/S +E/-W Northing Easting Rate Section eft) ~°) ~°) eft) eft) eft) eft) eft) eft) (°/100ft) (ft) Base Nuigsut 8,100.000 72.060 332.3315 6,845.489 6,894.089 3,593.534 937.359 6,007,412.5360 389,179.3515 4.00 3,071.953 8,200.000 75.641 330.4757 6,873.298 6,921.898 3,677.846 891.380 6,007,497.5199 389,134.6446 4.00 3,166.795 8,300.000 79.236 328.6785 6,895.043 6,943.643 3,761.990 841.954 6,007,582.3875 389,086.4887 4.00 3,262.634 8,400.000 82.841 326.9238 6,910.616 6,959.216 3,845.556 789.322 6,007,666.7252 389,035.1186 4.00 3,359.003 8,439.010 84.251 326.2469 6,915.000 6,963.600 3,877.911 767.976 6,007,699.3928 389,014.2612 4.00 3,396.638 Top Nechelik 8,500.000 86.453 325.1966 6,919.941 6,968.541 3,928.137 733.740 6,007,750.1223 388,980.7844 4.00 3,455.431 8,518.942 87.139 324.8708 6,921.000 6,969.600 3,943.636 722.901 6,007,765.7800 388,970.1800 4.01 3,473.665 Target {7" Csg Pt) GeoSteer, 8879ft MD, 6970ft TVD, 5277ft FNL, 2783ft FEL, 8,542.831 86.183 324.8506 6,922.391 6,970.991 3,963.138 709.175 6,007,785.4838 388,956.7485 4.00 3,496.638 8,600.000 86.183 324.8506 6,926.197 6,974.797 4,009.778 676.335 6,007,832.6069 388,924.6139 0.00 3,551.584 8,700.000 86.183 324.8506 6,932.853 6,981.453 4,091.362 618.892 6,007,915.0351 388,868.4038 0.00 3,647.697 8,702.089 86.183 324.8506 6,932.992 6,981.592 4,093.066 617.692 6,007,916.7568 388,867.2298 0.00 3,649.704 8,800.000 90.098 324.9333 6,936.167 6,984.767 4,173.107 561.422 6,007,997.6242 388,812.1696 4.00 3,743.970 8,819.536 90.880 324.9498 6,936.000 6,984.600 4,189.098 550.201 6,008,013.7800 388,801.1900 4.01 3,762.795 Target {Deep Pt) GeoSteer, 8820ft MD, 6985ft TVD -CD3-110 wp02 Deep Pt 8,900.000 90.880 324.9498 6,934.764 6,983.364 4,254.962 503.996 6,008,080.3229 388,755.9811 0.00 3,840.331 9,000.000 90.880 324.9498 6,933.227 6,981.827 4,336.817 446.573 6,008,163.0219 388,699.7957 0.00 3,936.692 9,100.000 90.880 324.9498 6,931.691 6,980.291 4,418.672 389.151 6,008,245.7209 388,643.6104 0.00 4,033.054 9,200.000 90.880 324.9498 6,930.155 6,978.755 4,500.527 331.728 6,008,328.4200 388,587.4250 0.00 4,129.415 9,300.000 90.880 324.9498 6,928.618 6,977.218 4,582.382 274.305 6,008,411.1190 388,531.2397 0.00 4,225.776 9,400.000 90.880 324.9498 6,927.082 6,975.682 4,664.238 216.883 6,008,493.8180 388,475.0543 0.00 4,322.137 9,500.000 90.880 324.9498 6,925.545 6,974.145 4,746.093 159.460 6,008,576.5170 388,418.8690 0.00 4,418.498 9,600.000 90.880 324.9498 6,924.009 6,972.609 4,827.948 102.037 6,008,659.2161 388,362.6836 0.00 4,514.859 9,700.000 90.880 324.9498 6,922.473 6,971.073 4,909.803 44.615 6,008,741.9151 388,306.4983 0.00 4,611.220 9,800.000 90.880 324.9498 6,920.936 6,969.536 4,991.659 -12.808 6,008,824.6141 388,250.3129 0.00 4,707.581 9,900.000 90.880 324.9498 6,919.400 6,968.000 5,073.514 -70.231 6,008,907.3132 388,194.1275 0.00 4,803.942 10,000.000 90.880 324.9498 6,917.864 6,966.464 5,155.369 -127.653 6,008,990.0122 388,137.9422 0.00 4,900.304 10,100.000 90.880 324.9498 6,916.327 6,964.927 5,237.224 -185.076 6,009,072.7112 388,081.7568 0.00 4,996.665 10,200.000 90.880 324.9498 6,914.791 6,963.391 5,319.079 -242.499 6,009,155.4103 388,025.5715 0.00 5,093.026 10,300.000 90.880 324.9498 6,913.254 6,961.854 5,400.935 -299.921 6,009,238.1093 387,969.3861 0.00 5,189.387 10,400.000 90.880 324.9498 6,911.718 6,960.318 5,482.790 -357.344 6,009,320.8083 387,913.2008 0.00 5,285.748 10,500.000 90.880 324.9498 6,910.182 6,958.782 5,564.645 -414.767 6,009,403.5074 387,857.0154 0.00 5,382.109 10,600.000 90.880 324.9498 6,908.645 6,957.245 5,646.500 -472.189 6,009,486.2064 387,800.8301 0.00 5,478.470 10,700.000 90.880 324.9498 6,907.109 6,955.709 5,728.356 -529.612 6,009,568.9054 387,744.6447 0.00 5,574.831 10,800.000 90.880 324.9498 6,905.573 6,954.173 5,810.211 -587.035 6,009,651.6045 387,688.4594 0.00 5,671.192 10,900.000 90.880 324.9498 6,904.036 6,952.636 5,892.066 544.457 6,009,734.3035 387,632.2740 0.00 5,767.554 11,000.000 90.880 324.9498 6,902.500 6,951.100 5,973.921 -701.880 6,009,817.0025 387,576.0887 0.00 5,863.915 11,100.000 90.880 324.9498 6,900.963 6,949.563 6,055.776 -759.303 6,009,899.7016 387,519.9033 0.00 5,960.276 11,200.000 90.880 324.9498 6,899.427 6,948.027 6,137.632 516.725 6,009,982.4006 387,463.7180 0.00 6,056.637 11,300.000 90.880 324.9498 6,897.891 6,946.491 6,219.487 574.148 6,010,065.0996 387,407.5326 0.00 6,152.998 11,400.000 90.880 324.9498 6,896.354 6,944.954 6,301.342 -931.571 6,010,147.7987 387,351.3472 0.00 6,249.359 11,500.000 90.880 324.9498 6,894.818 6,943.418 6,383.197 -988.993 6,010,230.4977 387,295.1619 0.00 6,345.720 11,600.000 90.880 324.9498 6,893.281 6,941.881 6,465.052 -1,046.416 6,010,313.1967 387,238.9765 0.00 6,442.081 11,700.000 90.880 324.9498 6,891.745 6,940.345 6,546.908 -1,103.839 6,010,395.8958 387,182.7912 0.00 6,538.442 11,800.000 90.880 324.9498 6,890.209 6,938.809 6,628.763 -1,161.261 6,010,478.5948 387,126.6058 0.00 6,634.803 11,900.000 90.880 324.9498 6,888.672 6,937.272 6,710.618 -1,218.684 6,010,561.2938 387,070.4205 0.00 6,731.165 12,000.000 90.880 324.9498 6,887.136 6,935.736 6,792.473 -1,276.107 6,010,643.9929 387,014.2351 0.00 6,827.526 12,100.000 90.880 324.9498 6,885.600 6,934.200 6,874.329 -1,333.529 6,010,726.6919 386,958.0498 0.00 6,923.887 12,200.000 90.880 324.9498 6,884.063 6,932.663 6,956.184 -1,390.952 6,010,809.3909 386,901.8644 0.00 7,020.248 12,300.000 90.880 324.9498 6,882.527 6,931.127 7,038.039 -1,448.375 6,010,892.0900 386,845.6791 0.00 7,116.609 12,400.000 90.880 324.9498 6,880.990 6,929.590 7,119.894 -1,505.797 6,010,974.7890 386,789.4937 0.00 7,212.970 12,500.000 90.880 324.9498 6,879.454 6,928.054 7,201.749 -1,563.220 6,011,057.4880 386,733.3084 0.00 7,309.331 12,600.000 90.880 324.9498 6,877.918 6,926.518 7,283.605 -1,620.643 6,011,140.1870 386,677.1230 0.00 7,405.692 12,700.000 90.880 324.9498 6,876.381 6,924.981 7,365.460 -1,678.065 6,011,222.8861 386,620.9377 0.00 7,502.053 12,800.000 90.880 324.9498 6,874.845 6,923.445 7,447.315 -1,735.488 6,011,305.5851 386,564.7523 0.00 7,598.415 12,900.000 90.880 324.9498 6,873.309 6,921.909 7,529.170 -1,792.911 6,011,388.2841 386,508.5669 0.00 7,694.776 13,000.000 90.880 324.9498 6,871.772 6,920.372 7,611.026 -1,850.333 6,011,470.9832 386,452.3816 0.00 7,791.137 01 March, 2005 - 14:41 Page 4 of 7 COMPASS ~~~~i~. ConocoPhillips Alaska Inc. (Alpine) HA1.~1 B U RTO N Colville River Unit Plan Report for Plan: CD3-110 -Plan: CD3-110 -CD3-110 (wpO2) Measured Sub-System Vertical Local Coordinates Map Coordinates Dogleg Vertical Depth Inclination Azimuth Depth Depth +N/S +E/ W Northing Easting Rate Section (ft) C°) (°) (ft) 1ft) (ft) eft) eft) lft) ~°NOOft) (ft) 13,100.000 90.880 324.9498 6,870.236 6,918.836 7,692.881 -1,907.756 6,011,553.6822 386,396.1962 0.00 7,887.498 13,200.000 90.880 324.9498 6,868.699 6,917.299 7,774.736 -1,965.179 6,011,636.3812 386,340.0109 0.00 7,983.859 13,300.000 90.880 324.9498 6,867.163 6,915.763 7,856.591 -2,022.601 6,011,719.0803 386,283.8255 0.00 8,080.220 13,400.000 90.880 324.9498 6,865.627 6,914.227 7,938.446 -2,080.024 6,011,801.7793 386,227.6402 0.00 8,176.581 13,500.000 90.880 324.9498 6,864.090 6,912.690 8,020.302 -2,137.447 6,011,884.4783 386,171.4548 0.00 8,272.942 13,600.000 90.880 324.9498 6,862.554 6,911.154 8,102.157 -2,194.869 6,011,967.1774 386,115.2695 0.00 8,369.303 13,700.000 90.880 324.9498 6,861.017 6,909.617 8,184.012 -2,252.292 6,012,049.8764 386,059.0841 0.00 8,465.665 13,800.000 90.880 324.9498 6,859.481 6,908.081 8,265.867 -2,309.715 6,012,132.5754 386,002.8988 0.00 8,562.026 13,900.000 90.880 324.9498 6,857.945 6,906.545 8,347.722 -2,367.137 6,012,215.2745 385,946.7134 0.00 8,658.387 14,000.000 90.880 324.9498 6,856.408 6,905.008 8,429.578 -2,424.560 6,012,297.9735 385,890.5281 0.00 8,754.748 14,100.000 90.880 324.9498 6,854.872 6,903.472 8,511.433 -2,481.983 6,012,380.6725 385,834.3427 0.00 8,851.109 14,200.000 90.880 324.9498 6,853.336 6,901.936 8,593.288 -2,539.405 6,012,463.3716 385,778.1573 0.00 8,947.470 14,300.000 90.880 324.9498 6,851.799 6,900.399 8,675.143 -2,596.828 6,012,546.0706 385,721.9720 0.00 9,043.831 14,400.000 90.880 324.9498 6,850.263 6,898.863 8,756.999 -2,654.251 6,012,628.7696 385,665.7866 0.00 9,140.192 14,500.000 90.880 324.9498 6,848.726 6,897.326 8,838.854 -2,711.673 6,012,711.4687 385,609.6013 0.00 9,236.553 14,600.000 90.880 324.9498 6,847.190 6,895.790 8,920.709 -2,769.096 6,012,794.1677 385,553.4159 0.00 9,332.914 14,700.000 90.880 324.9498 6,845.654 6,894.254 9,002.564 -2,826.519 6,012,876.8667 385,497.2306 0.00 9,429.276 14,800.000 90.880 324.9498 6,844.117 6,892.717 9,084.419 -2,883.941 6,012,959.5658 385,441.0452 0.00 9,525.637 14,900.000 90.880 324.9498 6,842.581 6,891.181 9,166.275 -2,941.364 6,013,042.2648 385,384.8599 0.00 9,621.998 15,000.000 90.880 324.9498 6,841.044 6,889.644 9,248.130 -2,998.787 6,013,124.9638 385,328.6745 0.00 9,718.359 15,100.000 90.880 324.9498 6,839.508 6,888.108 9,329.985 -3,056.209 6,013,207.6629 385,272.4892 0.00 9,814.720 15,200.000 90.880 324.9498 6,837.972 6,886.572 9,411.840 -3,113.632 6,013,290.3619 385,216.3038 0.00 9,911.081 15,300.000 .90.880 324.9498 6,836.435 6,885.035 9,493.696 -3,171.055 6,013,373.0609 385,160.1185 0.00 10,007.442 15,400.000 90.880 324.9498 6,834.899 6,883.499 9,575.551 -3,228.477 6,013,455.7600 385,103.9331 0.00 10,103.803 15,500.000 90.880 324.9498 6,833.363 6,881.963 9,657.406 -3,285.900 6,013,538.4590 385,047.7478 0.00 10,200.164 15,600.000 90.880 324.9498 6,831.826 6,880.426 9,739.261 -3,343.323 6,013,621.1580 384,991.5624 0.00 10,296.526 15,700.000 90.880 324.9498 6,830.290 6,878.890 9,821.116 -3,400.745 6,013,703.8570 384,935.3770 0.00 10,392.887 15,800.000 90.880 324.9498 6,828.753 6,877.353 9,902.972 -3,458.168 6,013,786.5561 384,879.1917 0.00 10,489.248 15,900.000 90.880 324.9498 6,827.217 6,875.817 9,984.827 -3,515.591 6,013,869.2551 384,823.0063 0.00 10,585.609 16,000.000 90.880 324.9498 6,825.681 6,874.281 10,066.682 -3,573.013 6,013,951.9541 384,766.8210 0.00 10,681.970 16,100.000 90.880 324.9498 6,824.144 6,872.744 10,148.537 -3,630.436 6,014,034.6532 384,710.6356 0.00 10,778.331 16,200.000 90.880 324.9498 6,822.608 6,871.208 10,230.392 -3,687.859 6,014,117.3522 384,654.4503 0.00 10,874.692 16,300.000 90.880 324.9498 6,821.072 6,869.672 10,312.248 -3,745.281 6,014,200.0512 384,598.2649 0.00 10,971.053 16,400.000 90.880 324.9498 6,819.535 6,868.135 10,394.103 -3,802.704 6,014,282.7503 384,542.0796 0.00 11,067.414 16,500.000 90.880 324.9498 6,817.999 6,866.599 10,475.958 -3,860.127 6,014,365.4493 384,485.8942 0.00 11,163.776 16,600.000 90.880 324.9498 6,816.462 6,865.062 10,557.813 -3,917.549 6,014,448.1483 384,429.7089 0.00 11,260.137 16,700.000 90.880 324.9498 6,814.926 6,863.526 10,639.669 -3,974.972 6,014,530.8474 384,373.5235 0.00 11,356.498 16,800.000 90.880 324.9498 6,813.390 6,861.990 10,721.524 <1,032.395 6,014,613.5464 384,317.3382 0.00 11,452.859 16,900.000 90.880 324.9498 6,811.853 6,860.453 10,803.379 x,089.817 6,014,696.2454 384,261.1528 0.00 11,549.220 17,000.000 90.880 324.9498 6,810.317 6,858.917 10,885.234 -4,147.240 6,014,778.9445 384,204.9675 0.00 11,645.581 / 17,020.624 90.880 324.9498 6,810.000 6,858.600 10,902.116 -4,159.083 6,014,796.0000 384,193.3800 0.00 11,665.454 Target (Toe) : 17020ft MD, 6858ft TVD, (3600ft FNL, 2342ft FEL, Sec30•T13N- Based upon Minimum Curvature type calculations, at a Measured Depth of 17,020.62ft the Bottom Hole Displacement is 11,668.51ft in the Direction of 339.12° (Grid). 01 March, 2005 - 14:41 ^ ~ ~ay~ 5~of~ ` ~ COMPASS • HALL~B V RTON' ConocoPhillips Alaska Inc. (Alpine) Colville River Unit Plan Report for Plan: CD3-110 -Plan: CD3-110 -CD3-110 (wp02) Plan Annotations Measured Vertical Depth Depth (ft) (ft) 36.100 36.100 300.100 300.100 1,256.630 1,217.127 2,728.288 2,508.000 6,696.990 5,989.168 8,518.942 6,969.600 8,819.540 6,984.600 17,020.600 6,858.600 Vertical Section Information Angle Type User Local Coordinates +N/-S +E/-W Comment (ft) (ft) 0.000 0.000 SHL - 3941ft FNL & 855ft FEL, Secs-T12N-R5E 0.000 0.000 Begin Dir @ 3.00 DLS: 300.100ft MD,300.100ft TVD 215.372 93.057 End Dir-Start Sail-28.699° , 1256.630 ft MD, 1217.127 ft TVD 864.106 373.358 9-5/8" Csg Pt ... Drill out 8-1/2" Hole : 2716.077ft MD, 2508.000ft TVD 2,613.584 1,129.261 Begin Dir - 4.00°DLS, 6696.990 ft MD, 5989.168 ft TVD 3,943.636 722.901 Target (7" Csg Pt) GeoSteer, 8819ft MD, 6970ft TVD, 5277ft FNL, 2763ft 4,189.101 550.198 Target (Deep Pf) GeoSteer, 8820ft MD, 6985ft TVD 10,902.096 x,159.069 Target (Toe) : 17020ft MD, 6858ft TVD, (3600ft FNL, 2342ft FEL, Sec30- Target No Target(Freehandj Origin Azimuth Type (°) 340.4295 Slot Origin Start +N/ S +E/.W TVD 0.000 0.000 0.000 01 March, 2005 - 14:41 Page 6 of 7 COMPASS • ConocoPhillips Alaska Inc. (Alpine) H'ALLI B U RT0 QV Colville xiver Unit North Reference Sheet for Alpine CD3 -Plan: CD3-110 -Plan: CD3-110 Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04 using datum NAD 1927 (NADCON CONUS), ellipsoid Clarke 1866 Projection method is Transverse Mercator (Gauss-Kruger) Central Meridian is -150.00 °, Longitude Origin:0.00 °, Latitude Origin:0.00 ° False Easting: 500,OOO.OOOOft, False Northing: O.000Oft, Scale Reduction: 0.99991419 Grid Coordinates of Well: 6,003,833.7520, 388,188.3581 Geographical Coordinates of Well: 70° 25' 09.91" N, 150° 54' 39.16" W Grid Convergence at Surface is: -0.8582° Magnetic Convergence at surface is: -24.6200° (1 March 2005, , BGGM2004) T Magnetic Nadel B4OM2O04 M Date: 01-PA ar-0 5 D eC Fnatran. 23.7620° 1 nc ~ atiorr-D ip: 80.6757° F ie~l Strength: 57 537 Grid North ~ 0.8582° West of True North (Gr~l Ganvergence) Magnetic North is 23.7820' East of True North (MagneticDed~rat~ M agnetuc North is 24.8202' E ast of Gr~J North 4M agnetic Convergen To convert a True Direction to a Grid D~~ction, Add 0.8582° T a convert a M agnetjc Djredion to a True Direction, Rdd 23.7820 To convert a M agnet~ Dired~n to a Grid D~edian, ~4dd 24.6202° O1 March, 2005 - 14:41 Page 7 of 7 COMPASS ORIGINAL ~~ ~ ~ ConocoPhillips Alaska Inc. C~na~t~#~h ~ I I ~ ps Engineering Alpine Calculation MethodMinimum Curvature - HALLIBURTON ErrorSys~hem: ~~ IN '~ Scan Method: Trav. Cylinder North Spent' Drilling Services Error Surface: Elliptical Conic Warning Method Rules Based 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 CD3-110 I I ~ I/ , ' k -t ~I I I - -, - _ ~ _ ~ I, I I~ ~ I I I I~ I I I~ _ I_ _I I I J-- I ~ I I I I I I -Plan: co3-cos, rte,: cD~-~o9, rte,: cDS-sae tom) w - I / I I I, ~I I ~ I I ~ -I _I I I ~ - I I ~ - I I I - _ I -I' I ~ I ~ ~ I I I Plan: cD3106, Plan: co3108, Plan: co3-cos ~) w ~~ ~~ I I I ~ I l i I Plan: coca-~ ~o ~ I _ I I ~ ~ - J~ I - _ I Plan: cD~111, Plan: cD3.111, Plan: cD~-~ ~ ~ ~m> w I ~ I ~ I ~~ I~ I ~ I I I I eY" ~ I I , I I / - / - Plan: CD3301, Plan: 003301, CD3301 (wp01) w I ~ I 1' - ~ - ~ I I ~ I / _ _ ~-- I _ I ~ I ~ I / _ ~' _ r r ~ 6`S~O / / I / / I _ /_ _ - / _ / Fjord 5, Fjord 5 P61~ Jad 5 PB1 V1 / SO ~ I _ _ _ ~ I ~ I I / - / ~ _ ~ / ~ / /- _ /350 j I ~ ~ / ~ ~ / ` / FJord 5, Fjord 5, Fjord 5 V1 / 2000 / ' ~ / /~ Op I ~ ~ ~ - _ ~ / / / ~ 90 00 / ~ ~ _ / ~ - ~, ~ - i Spy /~ / ~ ~ ~ ~ _ / \ South(-)/North(+) ~._ .~~' ~~ ° 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 n I ~ I- I I- I -t- I - t- I -I t- -i h- I -t I -t I- I I - I -t-~ ~ t- I -1 t-- -i F- I - I t I - I 3 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 n _ _ - - - , ~ I -t I- I - I- I t I - -t- I -I t- -1 r I 1 - I -f' I- I - I - I t I -7 -1 f- _rt rt ! - I I I I I I I I I I I I I I I i l I I I I I I - _ _ - ~ _ ~ - - _ _ _ ~ ~ - _. fT' I~ I I I I I i TTI I L I I L T J -T-- L 1 I T I I J ~"- 1 T I I I I I L I - L L I L L I 1 I I L I I ~ - _ _ ~ _ _ _ - _ _ _ - - ~ - - - ~_ _ _ - I -1 I- I- N n I- T I -I T ~ f I ~ I I T I I I T I i ~ 1 T I T I I - ~ I.---~- I I ~ I ~--~-I I ~-- -~- J -~ ---~- ~ I -~--~--1- I I-1-1- I I ~~- ~D I I I I _ ! 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APPLIES (OPTION MULTI The permit is for a new wellbore segment of LATERAI. existing well ~ . Permit No, API No. (lf API number Production. should continue to be reported as . last two. (2) digits a funciion'oi the original API number. stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (PIS records, data and logs acquired for the pilot . bole must be c}early differentiated ~in both name (name on permit plus P]tI) and API number (SO - 70/SO) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject •to full EXCEPTION compliance with 20 AAC 25.055. Approva] to perforate and produce is contingent upoa issuance of a conservation order approving a spacing ~ eaception. (Company Name) assumes ibe liability of any protest to the spacing ,eaception that may occur. . DRY DITCH ~ All dry ditch sample sets submitted to ibe SAMPLE Commission must be in no greater than 30' . sample intervals from below the permafrost or from where samples are first caught and . ] 0' sample intervals through target zones. • • ^^ y ~ ~ ; ~ o : O ~ ~ ul ~ L N ~ ~ ~ ~ ~ C' ~ ~ ~ ~ f0 ~ ~ p. ~ N ~ p. ?i , ~ O ~ O, ~ ~ ~ y. O Or .C, ~ O. ~ O uJ ~ ~ : ~ ~ ~ o ~ m O . _ ~: _, m N: r' v, M :c, E 3, ~ oc, rn N 3, ji, m ~ ~ ~ ~ ~ ~ ~ ~ of ~ ~ c gyp: 4., ~~ ~' ~ a~i'~ a o °c' ~, ~'~ , _ . c ur' ~ 'c. ~ a ~ U. ~°- 3 W' ~ n c. ~ vi o U o. o ~ ~, U. N, ~, ~ '~ o: a ~, Zr ~: ~ ~ ~ ~ p. ~ ~ ~ _~ , ~ ~ N. N. ~ ~ Z: c N. ~ ~, ~ ~~ O. _, ~~ O, ~ ~ p. y ~ .p, O, C• a a N• ~ ~~ "O, ~ C, o' ~ ., c' N' " N' 4 • N' .a. ~ 'UO, .~ 'C W J M, y ~ 'O. ~ ~: ~ c. ~ a, C, O, c. ~ Or ay~ ~, f0 ~ r ~ O: ~~ ~ ~3~ N' N i O °D ~ ~ ~ f ~: N' : C, O. O. 3. ~ y E. ~ y ~ 6 p ~ p. ~ E N ~ O. J N ~ N. ~ ~ O. ~ 3~ W O '> ~ O, ~ N. _U C c 3 O? 'O N~ Z O ~ y. Q: ~: ~ ~ ~ ~ ~ ~ G ~ ~ N~ ~ , t ~ ~ ~ T ~ , cp~ c ~ U. 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O: L, ~ m m U ~; ~'; ~; ~ a ~ o at: cn m. tn U' p !v U c , , , , , , , , , , , , , , , , _, , , , , , , , `° w a O N M ~ M (O I~ O O O N M I ifY O ~ dD O O N M 'cI to CO O ° M O ~ N M I ~ (p f~ OD m r ~ N N N N N N N N N N M M M M M M M M J U _ _ U C 6 O C "' N ~" N "' © U O C !Y _ V ~ w ~ O ~ _ M Of D ^ M D ~' ~ °~ u1 ~ !n 0. ~ J W O N ~ y a a N • a w ~ a ~ C7 E ~ a ¢ ~ ~ ¢ ~ ~' -~ °' c9 ¢ a w ...~ • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. Sperry-Sun Dri~ng Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Apr 25 16:07:23 2006 ~ 3 ~s`6~ Reel Header Service name .............LISTPE Date .....................06/04/25 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/04/25 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................ST5 LIS Writing Library Physical EOF Comment Record TAPE HEADER Colville River (Fiord) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003649155 M. HANIK D. BURLEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Scientific Technical Services Scientific Technical Services CD3-110 501032050900 ConocoPhillips Alaska, Inc. Sperry Drilling Services 25-APR-06 MWD RUN 3 MWD RUN 4 MW0003649155 MW0003649155 M. HANIK R. KRELL D. BURLEY D. LUTRICK 5 12N 5E 1339 855 50.92 14.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 2680.0 2ND STRING 6.125 7.000 8959.0 3RD STRING PRODUCTION STRING aos =oV/ ~3 ~s( REMARKS: ~ • 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. RUNS 1-3 WERE DRILLED IN 2005 AND THE WELL WAS SUSPENDED. THE WELL WAS RE-ENTERED IN JANUARY 2006 AND DRILLED TO TD (MWD RUN 4). 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEOPILOT ROTARY-STEERABLE BHA (GP) MWD RUNS 2 & 3 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND ACOUSTIC CALIPER (ACAL) ONLY 20' OF PROGRESS WAS MADE ON RUN 2 - THE SENSORS DID NOT EXIT THE CASING. THEREFORE ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 7. MWD RUNS 1-4 REPRESENT WELL CD3-110 WITH API#: 50-103-20509-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17991'MD/6884'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, ACAL-DERIVED). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: AC~DERIVED (8.5" BIT) • MUD WEIGHT: 9.7 - 10.1 PPG MUD SALINITY: 600 - 1800 PPM CHLORIDES FORMATION WATER SALINITY: 25000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPX 2668.5 17940.5 RPS 2668.5 17940.5 FET 2668.5 17940.5 RPD 2668.5 17940.5 RPM 2668.5 17940.5 GR 2677.0 17933.5 NPHI 2680.5 8882.0 NCNT 2680.5 8882.0 PEF 2680.5 8896.0 RHOB 2680.5 8896.0 DRHO 2680.5 8896.0 FONT 2680.5 8882.0 ROP 2690.5 17991.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 MWD 4 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2690.5 2710.0 2668.5 8969.0 8934.5 17991.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 • Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2668.5 17991 10329.8 30646 2668.5 17991 FCNT MWD CNTS 537.1 2582.3 1186.35 12404 2680.5 8882 NCNT MWD CNTS 112540 189815 149100 12404 2680.5 8882 RHOB MWD G/CM 1.856 2.874 2.40466 12432 2680.5 8896 DRHO MWD G/CM -0.095 0.21 0.0396236 12432 2680.5 8896 RPD MWD OHMM 0.1 2000 39.3028 30525 2668.5 17940.5 RPM MWD OHMM 0.1 2000 13.1467 30525 2668.5 17940.5 RPS MWD OHMM 0.06 1644.95 12.3381 30525 2668.5 17940.5 RPX MWD OHMM 0.14 2000 11.7358 30525 2668.5 17940.5 FET MWD HOUR 0.16 6763.02 15.254 30525 2668.5 17940.5 GR MWD API 29.4 372.37 77.819 30514 2677 17933.5 PEF MWD BARN 1.26 8.35 3.16467 12432 2680.5 8896 ROP MWD FT/H 0.47 340.92 147.762 30602 2690.5 17991 NPHI MWD PU-S 16.93 65.42 33.1022 12404 2680.5 8882 First Reading For Entire File..........2668.5 Last Reading For Entire File...........17991 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. • • BI T RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 2690.5 2710.0 LOG HEADER DATA DATE LOGGED: 15-APR-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 2710.0 TOP LOG INTERVAL (FT) 2690.0 BOTTOM LOG INTERVAL (FT) 2710.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 34.5 MAXIMUM ANGLE: 34.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 105242 CTN COMP THERMAL NEUTRON 185457 ALD Azimuth. Litho-Den 10507555 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 2680.0 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S) 52.0 MUD PH: 10.9 MUD CHLORIDES (PPM): 1800 FLUID LOSS (C3) • 0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 82.4 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block~b-type...0 r Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2690.5 2710 2700.25 40 2690.5 2710 ROP MWD020 FT/H 4.92 195.9 121.909 40 2690.5 2710 First Reading For Entire File..........2690.5 Last Reading For Entire File...........2710 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 2668.5 8927.0 RPX 2668.5 8927.0 RPS 2668.5 8927.0 RPM 2668.5 8927.0 RPD 2668.5 8927.0 GR 2677.0 8934.0 PEF 2680.5 _8896.0 NPHI 2680.5 8882.0 RHOB 2680.5 8896.0 FCNT 2680.5 8882.0 DRHO 2680.5 8896.0 NCNT 2680.5 8882.0 ROP 2710.5 8969.0 LOG HEADER DATA DATE LOGGED: SOFTWARE 18-APR-05 ~ SURFACE SOFTWARE VERSI Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8969.0 TOP LOG INTERVAL (FT) 2710.0 BOTTOM LOG INTERVAL (FT) 8969.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 26.1 MAXIMUM ANGLE: 88.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 105242 ALD Azimuth. Litho-Den 728188 CTN COMP THERMAL NEUTRON 181190 ACAL Acoustic Caliper 728188 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 2680.0 BOREHOLE CONDITIONS MUD TYPE: LSND/Glydril MUD DENSITY (LB/G) 10.10 MUD VISCOSITY (S) 41.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 1000 FLUID LOSS (C3) 8.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.400 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.570 163.4 MUD FILTRATE AT MT: 3.500 72.0 MUD CAKE AT MT: 3.900 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD030 CNTS 4 1 68 4 2 NCNT MWD030 CNTS 4 1 68 8 3 RHOB MWD030 G/CM 4 1 68 12 4 DRHO MWD030 G/CM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 ~ • RPS MWD030 OHMM 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HOUR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 BARN 4 1 68 44 12 ROP MWD030 FT/H 4 1 68 48 13 NPHI MWD030 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2668.5 8969 5818.75 12602 2668.5 8969 FCNT MWD030 CNTS 537.1 2582.3 1186.35 12404 2680.5 8882 NCNT MWD030 CNTS 112540 189815 149100 12404 2680.5 8882 RHOB MWD030 G/CM 1.856 2.874 2.40466 12432 2680.5 8896 DRHO MWD030 G/CM -0.095 0.21 0.0396236 12432 2680.5 8896 RPD MWD030 OHMM 0.1 2000 7.11828 12518 2668.5 8927 RPM MWD030 OHMM 0.1 2000 4.99233 12518 2668.5 8927 RPS MWD030 OHMM 0.06 76.04 4.56276 12518 2668.5 8927 RPX MWD030 OHMM 0.17 2000 4.78044 12518 2668.5 8927 FET MWD030 HOUR 0.16 112.41 0.810172 12518 2668.5 8927 GR MWD030 API 38.85 372.37 115.28 12515 2677 8934 PEF MWD030 BARN 1.26 8.35 3.16467 12432 2680.5 8896 ROP MWD030 FT/H 14.68 340.92 205.71 12518 2710.5 8969 NPHI MWD030 PU-S 16.93 65.42 33.1022 12404 2680.5 8882 First Reading For Entire File..........2668.5 Last Reading For Entire File...........8969 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8934.5 17933.5 RPS 8937.5 17940.5 FET 8937.5 17940.5 RPX 8937.5 17940.5 RPD 8937. 17940.5 RPM 8937.5 17940.5 ROP 8969.5 17991.0 LOG HEADER DATA DATE LOGGED: 30-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 17991.0 TOP LOG INTERVAL (FT) 8969.0 BOTTOM LOG INTERVAL (FT) 17991.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.0 MAXIMUM ANGLE: 93.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 50020 EWR4 ELECTROMAG. RESIS. 4 130887 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 ,~ 6.125 8959.0 Polymer 9.30 51.0 9.3 37000 3.0 • 1.000 68.0 .420 172.4 1.200 68.0 1.400 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 ~ • RPM MWD040 OHMM 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8934.5 17991 13462.8 18114 8934.5 17991 RPD MWD040 OHMM 6.17 2000 61.6767 18007 8937.5 17940.5 RPM MWD040 OHMM 0.51 1733.12 18.8153 18007 8937.5 17940.5 RPS MWD040 OHMM 0.15 1644.95 17.7432 18007 8937.5 17940.5 RPX MWD040 OHMM 0.14 799.33 16.5709 18007 8937.5 17940.5 FET MWD040 HOUR 0.33 6763.02 25.295 18007 8937.5 17940.5 GR MWD040 API 29.4 123.73 51.7714 17999 8934.5 17933.5 ROP MWD040 FT/H 0.47 312.09 107.618 18044 8969.5 17991 First Reading For Entire File..........8934.5 Last Reading For Entire File...........17991 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/04/25 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/04/25 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File • cd3-110.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Oct 04 08:26:03 2007 Reel Header service name .............LISTPE Date . ...................07/10/04 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................07/10/04 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EoF Comment Record TAPE HEADER Colville River (Fiord) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: scientific Technical services scientific Technical services CD3-110 REDO 501032050900 ConocoPhillips Alaska, Inc. Sperry Drilling Services 25-APR-06 MWD RUN 3 MWD RUN 4 Mw0003649155 Mw0003649155 M. HANIK R. KRELL D. BURLEY D. LUTRICK MWD RUN 2 Mw0003649155 M. HANIK D. BURLEY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 5 12N 5E 1339 855 49.72 13.30 Page 1 vac- X05--0~1 / ~~~1 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: DATASET. OPEN HOLE BIT SIZE (IN) 8.500 6.125 cd3-110.tapx CASING DRILLERS SIZE (IN) DEPTH (FT) 9.625 2680.0 7.000 8959.0 THIS CD3-110 DATASET SUPERSEDES THE ONE PREVIOUSLY DISTRIBUTED. AN ERRONEOUS KBE VALUE WAS FOUND IN THE IN THE ORIGINAL DATASET. THE CORRECT VALUE HAS BEEN INCORPORATED INTO THIS 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. RUNS 1-3 WERE DRILLED IN 2005 AND THE WELL WAS SUSPENDED. THE WELL WAS RE-ENTERED IN JANUARY 2006 AND DRILLED TO TD (MWD RUN 4) . 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEOPILOT ROTARY-STEERABLE BHA (GP). MWD RUNS 2 & 3 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND ACOUSTIC CALIPER (ACAL). ONLY 20' OF PROGRESS WAS MADE ON RUN 2 - THE SENSORS DID NOT EXIT THE CASING. THEREFORE, ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 7. MWD RUNS 1-4 REPRESENT WELL CD3-110 WITH API#: 50-103-20509-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17991'MD/6884'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW Page 2 cd3-110.tapx SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, ACAL-DERIVED). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.5" BIT) MUD WEIGHT: 9.7 - 10.1 PPG MUD SALINITY: 600 - 1800 PPM CHLORIDES FORMATION WATER SALINITY: 25000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 Service sub Level Name... Version Number. ........1.0.0 Date of Generation.......07/10/04 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......sTSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE RPX RPS FET RPD RPM GR NPHI NCNT PEF RHOB DRHO FCNT ROP 1 and clipped curves; all bit runs merged. .5000 START DEPTH 2668.5 2668.5 2668.5 2668.5 2668.5 2677.0 2680.5 2680.5 2680.5 2680.5 2680.5 2680.5 2690.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 17940.5 17940.5 17940.5 17940.5 17940.5 17933.5 8882.0 8882.0 8896.0 8896.0 8896.0 8882.0 17991.0 Page 3 :~ cd3-110.tapx --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2690.5 2710.0 MwD 3 2668.5 8969.0 wD 4 8934.5 17991.0 $ REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... .. .......0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 2668.5 17991 10329.8 30646 2668.5 17991 FONT MWD CNTS 537.1 2582.3 1186.35 12404 2680.5 8882 NCNT MWD CNTS 112540 189815 149100 12404 2680.5 8882 RHOB MWD G/CM 1.856 2.874 2.40466 12432 2680.5 8896 DRHO MWD G/CM -0.095 0.21 0.0396236 12432 2680.5 8896 RPD MWD OHMM 0.1 2000 39.3028 30525 2668.5 17940.5 RPM MWD OHMM 0.1 2000 13.1467 30525 2668.5 17940.5 RPS MWD OHMM 0.06 1644.95 12.3381 30525 2668.5 17940.5 RPX MWD OHMM 0.14 2000 11.7358 30525 2668.5 17940.5 FET MWD HOUR 0.16 6763.02 15.254 30525 2668.5 17940.5 GR MWD API 29.4 372.37 77.819 30514 2677 17933.5 PEF MWD BARN 1.26 8.35 3.16467 12432 2680.5 8896 ROP MWD FT/H 0.47 340.92 147.762 30602 2690.5 17991 NPHI MWD PU-S 16.93 65.42 33.1022 12404 2680.5 8882 First Reading For Entire File..........2668.5 Page 4 cd3-110.tapx Last Reading For Entire File...........17991 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/04 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EoF File Header Service name... .......STSLI6.002 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......07/10/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH $OP 2690.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 2710.0 15-APR-05 Insite 68.18 Memory 2710.0 2690.0 2710.0 34.5 34.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 105242 CTN COMP THERMAL NEUTRON 185457 ALD Azimuth. Litho-Den 10507555 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 2680.0 Page 5 cd3-110.tapx BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (5): 52.0 MUD PH: 10.9 MUD CHLORIDES (PPM): 1800 FLUID LOSS (c3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 82.4 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 2690.5 2710 2700.25 40 2690.5 2710 ROP MWD020 FT/H 4.92 195.9 121.909 40 2690.5 2710 First Reading For Entire File..........2690.5 Last Reading For Entire Fi1e...........2710 File Trailer Service name... .......STSLIB.002 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......07/10/04 Maximum Physical Record..65535 File TyE~e ................L0 Next File Name...........STSLIB.003 Page 6 cd3-110.tapx Physical EOF File Header Service name... .......STSLI6.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 2668.5 8927.0 RPx 2668.5 8927.0 RPS 2668.5 8927.0 RPM 2668.5 8927.0 RPD 2668.5 8927.0 GR 2677.0 8934.0 PEF 2680.5 8896.0 NPHI 2680.5 8882.0 RHOB 2680.5 8896.0 FONT 2680.5 8882.0 DRHO 2680.5 8896.0 NCNT 2680.5 8882.0 ROP 2710.5 8969.0 LOG HEADER DATA DATE LOGGED: 18-APR-05 SOFTWARE SURFACE SOFTWA RE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8969.0 TOP LOG INTERVAL (FT): 2710.0 BOTTOM LOG INTERVAL (FT): 8969.0 BIT ROTATING SPEE D (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 26.1 MAXIMUM ANGLE: 88.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CO DE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 105242 ALD Azimuth. Li tho-Den 728188 CTN COMP THERMAL NEUTRON 181190 ACAL Acoustic Caliper 728188 BOREHOLE AND CASI NG DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASI NG DEPTH (FT): 2680.0 Page 7 cd3-110.tapx BOREHOLE CONDITIONS MUD TYPE: LSND/Glydril MUD DENSITY (LB/G): 10.10 MUD VISCOSITY (S): 41.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 1000 FLUID LO55 (C3): 8.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 3.400 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.570 163.4 MUD FILTRATE AT MT: 3.500 72.0 MUD CAKE AT MT: 3.900 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 Name service Order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD030 CNTS 4 1 68 4 2 NCNT MWD030 CNTS 4 1 68 8 3 RHOB MWD030 G/CM 4 1 68 12 4 DRHO MWD030 G/CM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HOUR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 BARN 4 1 68 44 12 ROP MwD030 FT/H 4 1 68 48 13 NPHI MWD030 Pu-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2668.5 8969 5818.75 12602 2668.5 8969 FONT MWD030 CNTS 537.1 2 582.3 1186.35 12404 2680.5 8882 NCNT MWD030 CNTS 112540 189815 149100 12404 2680.5 8882 RHOB MWD030 G/CM 1.856 2.874 2.40466 12432 2680.5 8896 DRHO MWD030 G/CM -0.095 0.21 0.0396236 12432 2680.5 8896 RPD MWD030 OHMM 0.1 2000 7.11828 12518 2668.5 8927 Page 8 cd3-110.tapx RPM MwD030 OHMM 0.1 2000 4.99233 12518 2668.5 8927 RPS MWD030 OHMM 0.06 76.04 4.56276 12518 2668.5 8927 RPX MWD030 OHMM 0.17 2000 4.78044 12518 2668.5 8927 FET MwD030 HOUR 0.16 112.41 0.810172 12518 2668.5 8927 GR MwD030 API 38.85 372.37 115.28 12515 2677 8934 PEF MwD030 BARN 1.26 8.35 3.16467 12432 2680.5 8896 ROP MWD030 FT/H 14.68 340.92 205.71 12518 2710.5 8969 NPHI MwD030 PU-s 16.93 65.42 33.1022 12404 2680.5 8882 First Reading For Entire File..........2668.5 Last Reading For Entire File...........8969 File Trailer Service name... .......STSL26.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/04 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8934.5 17933.5 RPS 8937.5 17940.5 FET 8937.5 17940.5 RPx 8937.5 17940.5 RPD 8937.5 17940.5 RPM 8937.5 17940.5 ROP 8969.5 17991.0 LOG HEADER DATA DATE LOGGED: 30-7AN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 17991.0 TOP LOG INTERVAL (FT): 8969.0 Page 9 a BOTTOM LOG INTERVAL (FT): SIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 cd3-110.tapx 17991.0 88.0 93.8 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing ........ ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units .. .. ..... Datum Specification Block sub-type...0 TOOL NUMBER 50020 130887 6.125 8959.0 Polymer 9.30 51.0 9.3 37000 3.0 1.000 68.0 .420 172.4 1.200 68.0 1.400 68.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 Page 10 cd3-110.tapx First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 8934.5 17991 13462.8 18114 8934.5 17991 RPD MWD040 OHMM 6.17 2000 61.6767 18007 8937.5 17940.5 RPM MWD040 OHMM 0.51 1733.12 18.8153 18007 8937.5 17940.5 RPS MWD040 OHMM 0.15 1644.95 17.7432 18007 8937.5 17940.5 RPX MWD040 OHMM 0.14 799.33 16.5709 18007 8937.5 17940.5 FET MWD040 HOUR 0.33 6763.02 25.295 18007 8937.5 17940.5 GR MWD040 API 29.4 123.73 51.7714 17999 8934.5 17933.5 ROP MWD040 FT/H 0.47 312.09 107.618 18044 8969.5 17991 First Reading For Entire File..........8934.5 Last Reading For Entire File...........17991 File Trailer Service name... .......STSLIB.004 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/04 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/10/04 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date . ...................07/10/04 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Physical EOF Physical EoF End Of LIS File Library. 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